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__________________________________________________________________________________________

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)
☑	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2019

OR

☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.		Commission File Number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number, and IRS Employer Identification No.
1-11299	ENTERGY CORPORATION		1-35747	ENTERGY NEW ORLEANS, LLC
	(a Delaware corporation) 639 Loyola Avenue New Orleans, Louisiana 70113 Telephone (504) 576-4000			(a Texas limited liability company) 1600 Perdido Street New Orleans, Louisiana 70112 Telephone (504) 670-3700
	72-1229752			82-2212934
1-10764	ENTERGY ARKANSAS, LLC		1-34360	ENTERGY TEXAS, INC.
	(a Texas limited liability company) 425 West Capitol Avenue Little Rock, Arkansas 72201 Telephone (501) 377-4000			(a Texas corporation) 10055 Grogans Mill Road The Woodlands, Texas 77380 Telephone (409) 981-2000
	83-1918668			61-1435798
1-32718	ENTERGY LOUISIANA, LLC		1-09067	SYSTEM ENERGY RESOURCES, INC.
	(a Texas limited liability company) 4809 Jefferson Highway Jefferson, Louisiana 70121 Telephone (504) 576-4000			(an Arkansas corporation) 1340 Echelon Parkway Jackson, Mississippi 39213 Telephone (601) 368-5000
	47-4469646			72-0752777
1-31508	ENTERGY MISSISSIPPI, LLC
	(a Texas limited liability company) 308 East Pearl Street Jackson, Mississippi 39201 Telephone (601) 368-5000
	83-1950019

__________________________________________________________________________________________

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Securities registered pursuant to Section 12(b) of the Act:

Registrant	Title of Class	Trading Symbol	Name of Each Exchange on Which Registered
Entergy Corporation	Common Stock, $0.01 Par Value	ETR	New York Stock Exchange
	Common Stock, $0.01 Par Value	ETR	NYSE Chicago, Inc.
Entergy Arkansas, LLC	Mortgage Bonds, 4.90% Series due December 2052	EAB	New York Stock Exchange
	Mortgage Bonds, 4.75% Series due June 2063	EAE	New York Stock Exchange
	Mortgage Bonds, 4.875% Series due September 2066	EAI	New York Stock Exchange
Entergy Louisiana, LLC	Mortgage Bonds, 5.25% Series due July 2052	ELJ	New York Stock Exchange
	Mortgage Bonds, 4.70% Series due June 2063	ELU	New York Stock Exchange
	Mortgage Bonds, 4.875% Series due September 2066	ELC	New York Stock Exchange
Entergy Mississippi, LLC	Mortgage Bonds, 4.90% Series due October 2066	EMP	New York Stock Exchange
Entergy New Orleans, LLC	Mortgage Bonds, 5.0% Series due December 2052	ENJ	New York Stock Exchange
	Mortgage Bonds, 5.50% Series due April 2066	ENO	New York Stock Exchange
Entergy Texas, Inc.	Mortgage Bonds, 5.625% Series due June 2064	EZT	New York Stock Exchange
	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)	ETI/PR	New York Stock Exchange

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Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

Yes ☑ No ☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).  Yes ☑ No ☐

Indicate by check mark whether each registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.

	Large accelerated filer		Accelerated filer		Non-accelerated filer		Smaller reporting company		Emerging growth company
Entergy Corporation	ü
Entergy Arkansas, LLC					ü
Entergy Louisiana, LLC					ü
Entergy Mississippi, LLC					ü
Entergy New Orleans, LLC					ü
Entergy Texas, Inc.					ü
System Energy Resources, Inc.					ü

If an emerging growth company, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑

Common Stock Outstanding		Outstanding at October 31, 2019
Entergy Corporation	($0.01 par value)	199,102,083

Entergy Corporation, Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. separately file this combined Quarterly Report on Form 10-Q.  Information contained herein relating to any individual company is filed by such company on its own behalf.  Each company reports herein only as to itself and makes no other representations whatsoever as to any other company.  This combined Quarterly Report on Form 10-Q supplements and updates the Annual Report on Form 10‑K for the calendar year ended December 31, 2018 and the Quarterly Reports on Form 10-Q for the quarters ended March 31, 2019 and June 30, 2019, filed by the individual registrants with the SEC, and should be read in conjunction therewith.

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TABLE OF CONTENTS

	Page Number
Forward-looking information	iii
Definitions	vi
Part I. Financial Information
Entergy Corporation and Subsidiaries
Management’s Financial Discussion and Analysis	1
Consolidated Income Statements	22
Consolidated Statements of Comprehensive Income	23
Consolidated Statements of Cash Flows	24
Consolidated Balance Sheets	26
Consolidated Statements of Changes in Equity	28
Selected Operating Results	30
Notes to Financial Statements
Note 1. Commitments and Contingencies	31
Note 2. Rate and Regulatory Matters	32
Note 3. Equity	42
Note 4. Revolving Credit Facilities, Lines of Credit, Short-term Borrowings, and Long-term Debt	50
Note 5. Stock-based Compensation	54
Note 6. Retirement and Other Postretirement Benefits	56
Note 7. Business Segment Information	63
Note 8. Risk Management and Fair Values	65
Note 9. Decommissioning Trust Funds	86
Note 10. Income Taxes	93
Note 11. Property, Plant, and Equipment	95
Note 12. Variable Interest Entities	95
Note 13. Revenue Recognition	96
Note 14. Asset Retirement Obligations	99
Note 15. Leases	100
Note 16. Dispositions	108
Item 3. Quantitative and Qualitative Disclosures About Market Risk	109
Item 4. Controls and Procedures	109
Entergy Arkansas, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	110
Consolidated Income Statements	119
Consolidated Statements of Cash Flows	121
Consolidated Balance Sheets	122
Consolidated Statements of Changes in Member’s Equity	124
Selected Operating Results	125
Entergy Louisiana, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	126
Consolidated Income Statements	136

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TABLE OF CONTENTS

	Page Number
Consolidated Statements of Comprehensive Income	137
Consolidated Statements of Cash Flows	139
Consolidated Balance Sheets	140
Consolidated Statements of Changes in Equity	142
Selected Operating Results	143
Entergy Mississippi, LLC
Management’s Financial Discussion and Analysis	144
Income Statements	153
Statements of Cash Flows	155
Balance Sheets	156
Statements of Changes in Member’s Equity	158
Selected Operating Results	159
Entergy New Orleans, LLC and Subsidiaries
Management’s Financial Discussion and Analysis	160
Consolidated Income Statements	168
Consolidated Statements of Cash Flows	169
Consolidated Balance Sheets	170
Consolidated Statements of Changes in Member’s Equity	172
Selected Operating Results	173
Entergy Texas, Inc. and Subsidiaries
Management’s Financial Discussion and Analysis	174
Consolidated Income Statements	182
Consolidated Statements of Cash Flows	183
Consolidated Balance Sheets	184
Consolidated Statements of Changes in Equity	186
Selected Operating Results	187
System Energy Resources, Inc.
Management’s Financial Discussion and Analysis	188
Income Statements	194
Statements of Cash Flows	195
Balance Sheets	196
Statements of Changes in Common Equity	198
Part II. Other Information
Item 1. Legal Proceedings	199
Item 1A. Risk Factors	199
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	199
Item 5. Other Information	200
Item 6. Exhibits	201
Signature	204

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FORWARD-LOOKING INFORMATION

In this combined report and from time to time, Entergy Corporation and the Registrant Subsidiaries each makes statements as a registrant concerning its expectations, beliefs, plans, objectives, goals, strategies, and future events or performance.  Such statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995.  Words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “intend,” “expect,” “estimate,” “continue,” “potential,” “plan,” “predict,” “forecast,” and other similar words or expressions are intended to identify forward-looking statements but are not the only means to identify these statements.  Although each of these registrants believes that these forward-looking statements and the underlying assumptions are reasonable, it cannot provide assurance that they will prove correct.  Any forward-looking statement is based on information current as of the date of this combined report and speaks only as of the date on which such statement is made.  Except to the extent required by the federal securities laws, these registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

 

Forward-looking statements involve a number of risks and uncertainties.  There are factors that could cause actual results to differ materially from those expressed or implied in the forward-looking statements, including those factors discussed or incorporated by reference in (a) Item 1A. Risk Factors in the Form 10-K, (b) Management’s Financial Discussion and Analysis in the Form 10-K and in this report, and (c) the following factors (in addition to others described elsewhere in this combined report and in subsequent securities filings):

•	resolution of pending and future rate cases, formula rate proceedings and related negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs;

•	long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;

•

regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the benefits of continued MISO participation, the effect of current or projected MISO market rules and market and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;

•	changes in utility regulation, including with respect to retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent transmission reliability requirements or market power criteria by the FERC or the U.S. Department of Justice;

•	changes in the regulation or regulatory oversight of Entergy’s nuclear generating facilities and nuclear materials and fuel, including with respect to the planned, potential, or actual shutdown of nuclear generating facilities owned or operated by Entergy Wholesale Commodities, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and nuclear fuel;

•	resolution of pending or future applications, and related regulatory proceedings and litigation, for license modifications or other authorizations required of nuclear generating facilities and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;

•	the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at Entergy’s nuclear generating facilities;

•	increases in costs and capital expenditures that could result from changing regulatory requirements, emerging operating and industry issues, and the commitment of substantial human and capital resources required for the safe and reliable operation and maintenance of Entergy’s nuclear generating facilities;

•	Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;

•	prices for power generated by Entergy’s merchant generating facilities and the ability to hedge, meet credit support requirements for hedges, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants, especially in light of the planned shutdown and sale of each of these nuclear plants;

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FORWARD-LOOKING INFORMATION (Continued)

•	the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts;

•	volatility and changes in markets for electricity, natural gas, uranium, emissions allowances, and other energy-related commodities, and the effect of those changes on Entergy and its customers;

•	changes in law resulting from federal or state energy legislation or legislation subjecting energy derivatives used in hedging and risk management transactions to governmental regulation;

•

changes in environmental laws and regulations, agency positions or associated litigation, including requirements for reduced emissions of sulfur dioxide, nitrogen oxide, greenhouse gases, mercury, particulate matter and other regulated air emissions, heat and other regulated discharges to water, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with environmental laws and regulations;

•	changes in laws and regulations, agency positions, or associated litigation related to protected species and associated critical habitat designations;

•	the effects of changes in federal, state, or local laws and regulations, and other governmental actions or policies, including changes in monetary, fiscal, tax, environmental, trade/tariff, or energy policies;

•	the effects of full or partial shutdowns of the federal government or delays in obtaining government or regulatory actions or decisions;

•	uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal and the level of spent fuel and nuclear waste disposal fees charged by the U.S. government or other providers related to such sites;

•	variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance;

•	effects of climate change, including the potential for increases in extreme weather events and sea levels or coastal land and wetland loss;

•	changes in the quality and availability of water supplies and the related regulation of water use and diversion;

•	Entergy’s ability to manage its capital projects and operation and maintenance costs;

•	Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms;

•	the economic climate, and particularly economic conditions in Entergy’s Utility service area and the northern United States and events and circumstances that could influence economic conditions in those areas, including power prices, and the risk that anticipated load growth may not materialize;

•	federal income tax reform, including the enactment of the Tax Cuts and Jobs Act, and its intended and unintended consequences on financial results and future cash flows;

•	the effects of Entergy’s strategies to reduce tax payments, especially in light of federal income tax reform;

•	changes in the financial markets and regulatory requirements for the issuance of securities, particularly as they affect access to capital and Entergy’s ability to refinance existing securities, execute share repurchase programs, and fund investments and acquisitions;

•	actions of rating agencies, including changes in the ratings of debt, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;

•	changes in inflation and interest rates;

•	the effect of litigation and government investigations or proceedings;

•

changes in technology, including (i) Entergy’s ability to implement new or emerging technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, renewable energy, energy efficiency, demand side management, and other measures that reduce load, and (iii) competition from other companies offering products and services to Entergy’s customers based on new or emerging technologies or alternative sources of generation;

•	the effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

•	Entergy’s ability to attract and retain talented management, directors, and employees with specialized skills;

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FORWARD-LOOKING INFORMATION (Concluded)

•	changes in accounting standards and corporate governance;

•	declines in the market prices of marketable securities and resulting funding requirements and the effects on benefits costs for Entergy’s defined benefit pension and other postretirement benefit plans;

•	future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets;

•	changes in decommissioning trust fund values or earnings or in the timing of, requirements for, or cost to decommission Entergy’s nuclear plant sites and the implementation of decommissioning of such sites following shutdown;

•	the decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by mid-2022, including the implementation of the planned shutdowns of Indian Point 2, Indian Point 3, and Palisades;

•	the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments;

•	factors that could lead to impairment of long-lived assets; and

•	the ability to successfully complete strategic transactions Entergy may undertake, including mergers, acquisitions, divestitures, or restructurings, regulatory or other limitations imposed as a result of any such strategic transaction, and the success of the business following any such strategic transaction.

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DEFINITIONS

Certain abbreviations or acronyms used in the text and notes are defined below:

Abbreviation or Acronym	Term
ALJ	Administrative Law Judge
ANO 1 and 2	Units 1 and 2 of Arkansas Nuclear One (nuclear), owned by Entergy Arkansas
APSC	Arkansas Public Service Commission
ASU	Accounting Standards Update issued by the FASB
Board	Board of Directors of Entergy Corporation
Cajun	Cajun Electric Power Cooperative, Inc.
capacity factor	Actual plant output divided by maximum potential plant output for the period
City Council	Council of the City of New Orleans, Louisiana
D.C. Circuit	U.S. Court of Appeals for the District of Columbia Circuit
DOE	United States Department of Energy
Entergy	Entergy Corporation and its direct and indirect subsidiaries
Entergy Corporation	Entergy Corporation, a Delaware corporation
Entergy Gulf States, Inc.	Predecessor company for financial reporting purposes to Entergy Gulf States Louisiana that included the assets and business operations of both Entergy Gulf States Louisiana and Entergy Texas
Entergy Gulf States Louisiana	Entergy Gulf States Louisiana, L.L.C., a Louisiana limited liability company formally created as part of the jurisdictional separation of Entergy Gulf States, Inc. and the successor company to Entergy Gulf States, Inc. for financial reporting purposes.  The term is also used to refer to the Louisiana jurisdictional business of Entergy Gulf States, Inc., as the context requires. Effective October 1, 2015, the business of Entergy Gulf States Louisiana was combined with Entergy Louisiana.
Entergy Louisiana	Entergy Louisiana, LLC, a Texas limited liability company formally created as part of the combination of Entergy Gulf States Louisiana and the company formerly known as Entergy Louisiana, LLC (Old Entergy Louisiana) into a single public utility company and the successor to Old Entergy Louisiana for financial reporting purposes.
Entergy Texas	Entergy Texas, Inc., a Texas corporation formally created as part of the jurisdictional separation of Entergy Gulf States, Inc.  The term is also used to refer to the Texas jurisdictional business of Entergy Gulf States, Inc., as the context requires.
Entergy Wholesale Commodities	Entergy’s non-utility business segment primarily comprised of the ownership, operation, and decommissioning of nuclear power plants, the ownership of interests in non-nuclear power plants, and the sale of the electric power produced by its operating power plants to wholesale customers
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FitzPatrick	James A. FitzPatrick Nuclear Power Plant (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which was sold in March 2017
Form 10-K	Annual Report on Form 10-K for the calendar year ended December 31, 2018 filed with the SEC by Entergy Corporation and its Registrant Subsidiaries
Grand Gulf	Unit No. 1 of Grand Gulf Nuclear Station (nuclear), 90% owned or leased by System Energy
GWh	Gigawatt-hour(s), which equals one million kilowatt-hours
Independence	Independence Steam Electric Station (coal), owned 16% by Entergy Arkansas, 25% by Entergy Mississippi, and 7% by Entergy Power, LLC

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DEFINITIONS (Continued)

Abbreviation or Acronym	Term
Indian Point 2	Unit 2 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Indian Point 3	Unit 3 of Indian Point Energy Center (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
IRS	Internal Revenue Service
ISO	Independent System Operator
kW	Kilowatt, which equals one thousand watts
kWh	Kilowatt-hour(s)
LPSC	Louisiana Public Service Commission
MISO	Midcontinent Independent System Operator, Inc., a regional transmission organization
MMBtu	One million British Thermal Units
MPSC	Mississippi Public Service Commission
MW	Megawatt(s), which equals one thousand kilowatts
MWh	Megawatt-hour(s)
Net debt to net capital ratio	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents
Net MW in operation	Installed capacity owned and operated
NRC	Nuclear Regulatory Commission
NYPA	New York Power Authority
Palisades	Palisades Nuclear Plant (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment
Parent & Other	The portions of Entergy not included in the Utility or Entergy Wholesale Commodities segments, primarily consisting of the activities of the parent company, Entergy Corporation
Pilgrim	Pilgrim Nuclear Power Station (nuclear), previously owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in May 2019 and was sold in August 2019
PPA	Purchased power agreement or power purchase agreement
PUCT	Public Utility Commission of Texas
Registrant Subsidiaries	Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.
River Bend	River Bend Station (nuclear), owned by Entergy Louisiana
SEC	Securities and Exchange Commission
System Agreement	Agreement, effective January 1, 1983, as modified, among the Utility operating companies relating to the sharing of generating capacity and other power resources. The agreement terminated effective August 2016.
System Energy	System Energy Resources, Inc.
TWh	Terawatt-hour(s), which equals one billion kilowatt-hours
Unit Power Sales Agreement	Agreement, dated as of June 10, 1982, as amended and approved by the FERC, among Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy, relating to the sale of capacity and energy from System Energy’s share of Grand Gulf
Utility	Entergy’s business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution
Utility operating companies	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas

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DEFINITIONS (Concluded)

Abbreviation or Acronym	Term
Vermont Yankee	Vermont Yankee Nuclear Power Station (nuclear), owned by an Entergy subsidiary in the Entergy Wholesale Commodities business segment, which ceased power production in December 2014 and was disposed of in January 2019
Waterford 3	Unit No. 3 (nuclear) of the Waterford Steam Electric Station, owned by Entergy Louisiana
weather-adjusted usage	Electric usage excluding the effects of deviations from normal weather
White Bluff	White Bluff Steam Electric Generating Station, 57% owned by Entergy Arkansas

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ENTERGY CORPORATION AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Entergy operates primarily through two business segments: Utility and Entergy Wholesale Commodities.

•	The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business.

•

The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown and sale of each of the Entergy Wholesale Commodities nuclear power plants.

See Note 7 to the financial statements herein for financial information regarding Entergy’s business segments.

Results of Operations

Third Quarter 2019 Compared to Third Quarter 2018

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the third quarter 2019 to the third quarter 2018 showing how much the line item increased or (decreased) in comparison to the prior period:

		Utility				Entergy Wholesale Commodities				Parent & Other (a)				Entergy
		(In Thousands)
3rd Quarter 2018 Consolidated Net Income (Loss)			$507,745				$105,571				($73,498	)			$539,818
Operating revenues		115,943				(79,717		)		30				36,256
Fuel, fuel-related expenses, and gas purchased for resale		(138,700		)		6,349				21				(132,330		)
Purchased power		(120,948		)		(2,072		)		(21		)		(123,041		)
Other regulatory charges (credits)		(32,316		)		—				—				(32,316		)
Other operation and maintenance		23,668				(72,791		)		806				(48,317		)
Asset write-offs, impairments, and related charges		—				42,871				—				42,871
Taxes other than income taxes		10,379				(6,268		)		(296		)		3,815
Depreciation and amortization		55,786				(1,716		)		521				54,591
Other income		(18,467		)		(82,237		)		230				(100,474		)
Interest expense		10,273				(2,766		)		(935		)		6,572
Other expenses		6,382				15,707				—				22,089
Income taxes		208,733				104,804				(1,330		)		312,207
3rd Quarter 2019 Consolidated Net Income (Loss)			$581,964				($140,501	)			($72,004	)			$369,459

(a)	Parent & Other includes eliminations, which are primarily intersegment activity.

Refer to “ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS” for further information with respect to operating statistics.

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

Third quarter 2019 results of operations includes a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.

Third quarter 2018 results of operations includes impairment charges of $155 million ($123 million net-of-tax) due to costs being charged directly to expense as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business, a $107 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a restructuring of the investment holdings in one of its nuclear plant decommissioning trust funds, and a $23 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a state income tax audit. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 3 to the financial statements in the Form 10-K for discussion of the state income tax audit and restructuring of its interest in the decommissioning trust fund.

Utility

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$2,724
Fuel, rider, and other revenues that do not significantly affect net income	(218		)
Return of unprotected excess accumulated deferred income taxes to customers	186
Retail electric price	99
Volume/weather	49
2019 operating revenues		$2,840

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In third quarter 2019, $91 million was returned to customers through reductions in operating revenues as compared to $277 million in third quarter 2018. There is no effect on net income as the reductions in operating revenues were offset by reductions in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

The retail electric price variance is primarily due to:

•	an increase in formula rate plan revenues effective September 2018 at Entergy Louisiana and an interim increase in formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for St. Charles Power Station, each as approved by the LPSC;

•	an increase in formula rate plan rates effective with the first billing cycle of January 2019 at Entergy Arkansas, as approved by the APSC;

•	a base rate increase effective October 2018 at Entergy Texas, as approved by the PUCT; and

•	an increase in formula rate plan revenues at Entergy Mississippi effective with the first billing cycle of July 2019, as approved by the MPSC.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

The volume/weather variance is primarily due to increased usage during the unbilled sales period.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $380 million for the third quarter 2018 to $300 million for the third quarter 2019 primarily due to the shutdown of Pilgrim in May 2019 and lower capacity prices.

Following are key performance measures for Entergy Wholesale Commodities for the third quarters 2019 and 2018:

	2019		2018
Owned capacity (MW) (a)	3,274		3,962
GWh billed	6,847		7,576
Entergy Wholesale Commodities Nuclear Fleet (b)
Capacity factor	98%		90%
GWh billed	6,210		6,976
Average energy price ($/MWh)	$37.29		$38.01
Average capacity price ($/kW-month)	$4.50		$9.32

(a)	The reduction in owned capacity is due to the shutdown of the 688 MW Pilgrim plant in May 2019.

(b)	The Entergy Wholesale Commodities nuclear power plants had no refueling outage days in the third quarters 2019 and 2018.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $635 million for the third quarter 2018 to $658 million for the third quarter 2019 primarily due to:

•	an increase of $11 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $10 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance;

•	an increase of $9 million in loss provisions;

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Entergy Corporation and Subsidiaries

Management's Financial Discussion and Analysis

•	an increase of $4 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services; and

•	an increase of $4 million in storm damage provisions at Entergy Mississippi. See Note 2 to the financial statements herein and in the Form 10-K for discussion of storm cost recovery.

The increase was partially offset by:

•

a decrease of $11 million in nuclear generation expenses primarily due to a lower scope of work performed in the third quarter 2019 as compared to the third quarter 2018 and the effect of recording the final court decision in the River Bend lawsuit against the DOE related to spent nuclear fuel storage costs. The damages awarded included the reimbursement of approximately $5 million of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense. See Note 1 to the financial statements herein for discussion of the spent nuclear fuel litigation;

•	a $6 million loss in third quarter 2018 on the sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense; and

•	a decrease of $5 million in energy efficiency costs due to the timing of recovery from customers.

Depreciation and amortization expenses increased primarily due to:

•	additions to plant in service, including the St. Charles Power Station;

•	a reduction of approximately $26 million in depreciation expense recorded in the third quarter 2018 as part of a settlement approved by the FERC in the Unit Power Sales Agreement proceeding; and

•	new depreciation rates at Entergy Mississippi, as approved by the MPSC, and at Entergy Texas, as approved by the PUCT.

The increase was partially offset by updated depreciation rates used in calculating Grand Gulf plant depreciation and amortization expenses under the Unit Power Sales Agreement, as approved by the FERC. See Note 2 to the financial statements in the Form 10-K for further discussion of the Unit Power Sales Agreement proceeding.

Other regulatory charges (credits) include regulatory charges of $18 million recorded in third quarter 2018 to reflect the effects of regulatory agreements to return the benefits of the lower income tax rate in 2018 to Entergy Louisiana customers. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

Other income decreased primarily due to changes in decommissioning trust fund activity, including portfolio rebalancing of certain of the decommissioning trust funds in the third quarter 2018.

Interest expense increased primarily due to the issuance in March 2019 of $525 million of 4.20% Series mortgage bonds by Entergy Louisiana and the issuance in March 2019 of $350 million of 4.20% Series mortgage bonds by Entergy Arkansas.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $209 million for the third quarter 2018 to $136 million for the third quarter 2019 primarily due to:

•	a decrease of $37 million in nuclear generation expenditures primarily due to the absence of other operation and maintenance expenses in the third quarter 2019 from the Pilgrim plant, which was sold in August 2019. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant; and

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Management's Financial Discussion and Analysis

•

a decrease of $26 million in severance and retention expenses in the third quarter 2019 compared to the third quarter 2018. Severance and retention expenses were incurred in 2019 and 2018 due to management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses resulting from management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities’ merchant nuclear fleet.

Asset write-offs, impairments, and related charges for the third quarter 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019. Asset write-offs, impairments, and related charges for the third quarter 2018 include impairment charges of $155 million ($123 million net-of-tax) as a result of an asset retirement obligation revision and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of long-lived assets. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.

Other income decreased primarily due to lower gains on decommissioning trust fund investments in the third quarter 2019 compared to the third quarter 2018, including the effect of portfolio rebalancing in the third quarter 2018. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

Other expenses increased primarily due to an increase in nuclear refueling outage expenses as a result of the amortization in 2019 of costs associated with a refueling outage at Palisades.

Income Taxes

The effective income tax rate was 7.3% for the third quarter 2019. The difference in the effective income tax rate for the third quarter 2019 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (110.2%) for the third quarter 2018. The difference in the effective income tax rate for the third quarter 2018 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes, a restructuring of the investment holdings in one of the Entergy Wholesale Commodities’ nuclear plant decommissioning trusts for which additional tax basis is now recoverable, and the conclusion of a state income tax audit involving Entergy Wholesale Commodities. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for a discussion of the restructuring and the conclusion of the state income tax audit.

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Management's Financial Discussion and Analysis

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following are income statement variances for Utility, Entergy Wholesale Commodities, Parent & Other, and Entergy comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018 showing how much the line item increased or (decreased) in comparison to the prior period:

		Utility				Entergy Wholesale Commodities				Parent & Other (a)				Entergy
		(In Thousands)
2018 Consolidated Net Income (Loss)			$1,104,078				$31,456				($210,657	)			$924,877
Operating revenues		3,164				(83,849		)		82				(80,603		)
Fuel, fuel-related expenses, and gas purchased for resale		(114,405		)		18,559				71				(95,775		)
Purchased power		(244,938		)		(5,725		)		(67		)		(250,730		)
Other regulatory charges (credits)		(262,114		)		—				—				(262,114		)
Other operation and maintenance		42,858				(86,812		)		(3,128		)		(47,082		)
Asset write-offs, impairments, and related charges		—				(8,599		)		—				(8,599		)
Taxes other than income taxes		15,137				(11,962		)		(1,142		)		2,033
Depreciation and amortization		79,223				(2,501		)		1,169				77,891
Other income		1,676				123,799				(4,894		)		120,581
Interest expense		21,800				(1,431		)		6,743				27,112
Other expenses		14,077				46,036				—				60,113
Income taxes		406,417				192,645				(5,695		)		593,367
2019 Consolidated Net Income (Loss)			$1,150,863				($68,804	)			($213,420	)			$868,639

(a)	Parent & Other includes eliminations, which are primarily intersegment activity.

Refer to “ENTERGY CORPORATION AND SUBSIDIARIES - SELECTED OPERATING RESULTS” for further information with respect to operating statistics.

Results of operations for the nine months ended September 30, 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019 and impairment charges of $98 million ($77 million net-of-tax) due to costs being charged directly to expense as incurred as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet.

Results of operations for the nine months ended September 30, 2018 include impairment charges of $297 million ($235 million net-of-tax) due to costs being charged directly to expense as a result of the impaired value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business, a $107 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a restructuring of the investment holdings in one of its nuclear plant decommissioning trust funds, a $52 million income tax benefit, recognized by Entergy Louisiana, as a result of the settlement of the 2012-2013 IRS audit, associated

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with the Hurricane Katrina and Hurricane Rita contingent sharing obligation associated with the Louisiana Act 55 financing, and a $23 million reduction of income tax expense, recognized by Entergy Wholesale Commodities, as a result of a state income tax audit. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 3 to the financial statements in the Form 10-K for discussion of the IRS audit settlement, the state income tax audit, and restructuring of its interest in the decommissioning trust fund.

Utility

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$7,390
Fuel, rider, and other revenues that do not significantly affect net income	(381		)
Return of unprotected excess accumulated deferred income taxes to customers	215
Retail electric price	200
Volume/weather	(31		)
2019 operating revenues		$7,393

The Utility operating companies’ results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from activity at the Utility operating companies in response to the enactment of the Tax Cuts and Jobs Act. The return of unprotected excess accumulated deferred income taxes began in second quarter 2018. In the nine months ended September 30, 2019, $212 million was returned to customers through reductions in operating revenues as compared to $427 million in the nine months ended September 30, 2018. There is no effect on net income as the reductions in operating revenues were offset by reductions in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

The retail electric price variance is primarily due to:

•	an increase in formula rate plan revenues effective September 2018 at Entergy Louisiana and an interim increase in formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for St. Charles Power Station, each as approved by the LPSC;

•	an increase in formula rate plan rates effective with the first billing cycle of January 2019 at Entergy Arkansas, as approved by the APSC;

•	a base rate increase effective October 2018 at Entergy Texas, as approved by the PUCT; and

•	an increase in formula rate plan revenues at Entergy Mississippi effective with the first billing cycle of July 2019, as approved by the MPSC.

See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the regulatory proceedings discussed above.

    

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The volume/weather variance is primarily due to a decrease of 1,741 GWh, or 2%, in billed electricity usage, including the effect of less favorable weather on residential and commercial sales, partially offset by increased usage during the unbilled sales period.

Entergy Wholesale Commodities

Operating revenues for Entergy Wholesale Commodities decreased from $1,108 million for the nine months ended September 30, 2018 to $1,024 million for the nine months ended September 30, 2019 primarily due to the shutdown of Pilgrim in May 2019 and lower capacity prices, partially offset by higher volume in the Entergy Wholesale Commodities nuclear fleet resulting from fewer non-refueling outage days.

Following are key performance measures for Entergy Wholesale Commodities for the nine months ended September 30, 2019 and 2018:

	2019		2018
Owned capacity (MW) (a)	3,274		3,962
GWh billed	21,308		21,853
Entergy Wholesale Commodities Nuclear Fleet
Capacity factor	91%		86%
GWh billed	19,602		20,096
Average energy price ($/MWh)	$40.85		$40.72
Average capacity price ($/kW-month)	$4.83		$7.01
Refueling outage days:
Indian Point 2	—		33
Indian Point 3	29		—

(a)	The reduction in owned capacity is due to the shutdown of the 688 MW Pilgrim plant in May 2019.

Other Income Statement Items

Utility

Other operation and maintenance expenses increased from $1,852 million for the nine months ended September 30, 2018 to $1,894 million for the nine months ended September 30, 2019 primarily due to:

•	an increase of $27 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $26 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance; and

•	an increase of $13 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services.

The increase was partially offset by:

•	a decrease of $22 million in nuclear generation expenses primarily due to a lower scope of work performed in 2019 as compared to 2018; and

•	a decrease of $11 million in energy efficiency costs due to the timing of recovery from customers.

    

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Management's Financial Discussion and Analysis

Depreciation and amortization expenses increased primarily due to:

•	additions to plant in service, including the St. Charles Power Station;

•	a reduction of approximately $26 million in depreciation expense recorded in the third quarter 2018 as part of a settlement approved by the FERC in the Unit Power Sales Agreement proceeding; and

•	new depreciation rates at Entergy Mississippi, as approved by the MPSC, and at Entergy Texas, as approved by the PUCT.

The increase was partially offset by updated depreciation rates used in calculating Grand Gulf plant depreciation and amortization expenses under the Unit Power Sales Agreement, as approved by the FERC. See Note 2 to the financial statements in the Form 10-K for further discussion of the Unit Power Sales Agreement proceeding.

Other regulatory charges (credits) include the following significant activity:

•	a regulatory charge recorded in second quarter 2018 to reflect the return of unprotected excess accumulated deferred income taxes per an agreement approved by the MPSC in June 2018 that resulted in a reduction in net utility plant of $127 million. There is no effect on net income as the regulatory charge was offset by a reduction in income tax expense in 2018; and

•	regulatory charges of $73 million recorded in 2018 to reflect the effects of regulatory agreements to return the benefits of the lower income tax rate in 2018 to Entergy Louisiana customers.

See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.     

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2019, which included the Lake Charles Power Station, Montgomery County Power Station, and New Orleans Power Station projects. The increase was substantially offset by changes in decommissioning trust fund activity, including portfolio rebalancing of certain decommissioning trust funds in 2018.

Interest expense increased primarily due to:

•	the issuance in March 2019 of $525 million of 4.20% Series mortgage bonds by Entergy Louisiana;

•	the issuance in March 2019 of $350 million of 4.20% Series mortgage bonds by Entergy Arkansas; and

•	the issuance in May 2018 of $250 million of 4.00% Series mortgage bonds by Entergy Arkansas.

See Note 5 to the financial statements in the Form 10-K and Note 4 to the financial statements herein for a discussion of long-term debt.

Entergy Wholesale Commodities

Other operation and maintenance expenses decreased from $600 million for the nine months ended September 30, 2018 to $513 million for the nine months ended September 30, 2019 primarily due to:

•	a decrease of $49 million in nuclear generation expenditures primarily due to the absence of other operation and maintenance expenses in the nine months ended September 30, 2019 from the Pilgrim plant, which was sold in August 2019. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant; and

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•

a decrease of $29 million in severance and retention expenses in the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018. Severance and retention expenses were incurred in 2019 and 2018 due to management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 7 to the financial statements herein for further discussion of severance and retention expenses resulting from management’s strategy to shut down and sell all of the remaining plants in the Entergy Wholesale Commodities’ merchant nuclear fleet.

Asset write-offs, impairments, and related charges for the nine months ended September 30, 2019 include a loss of $191 million ($156 million net-of-tax) as a result of the sale of the Pilgrim plant in August 2019 and impairment charges of $98 million ($77 million net-of-tax) related to nuclear refueling outage spending and expenditures for capital assets. Asset write-offs, impairments, and related charges for the nine months ended September 30, 2018 include impairment charges of $297 million ($235 million net-of-tax) related to an asset retirement obligation revision, nuclear refueling outage spending, and expenditures for capital assets. These costs were charged to expense as incurred as a result of the impaired fair value of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to shut down and sell all of the remaining plants in Entergy Wholesale Commodities’ merchant nuclear fleet. See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. See Note 14 to the financial statements in the Form 10-K for a discussion of impairment of long-lived assets. See Note 16 to the financial statements herein and Note 13 to the financial statements in the Form 10-K for further discussion of the sale of the Pilgrim plant.

Other income increased primarily due to higher gains on decommissioning trust fund investments in the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018. See Notes 8 and 9 to the financial statements herein for a discussion of decommissioning trust fund investments.

Other expenses increased primarily due to an increase in nuclear refueling outage expenses as a result of the amortization in 2019 of costs associated with a refueling outage at Palisades.

Income Taxes

The effective income tax rate was 7.8% for the nine months ended September 30, 2019. The difference in the effective income tax rate for the nine months ended September 30, 2019 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes and the tax effects of the disposition of Vermont Yankee. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 10 to the financial statements herein for a discussion of the tax effects of the Vermont Yankee disposition.

The effective income tax rate was (128.4%) for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to amortization of excess accumulated deferred income taxes, a restructuring of the investment holdings in one of the Entergy Wholesale Commodities’ nuclear plant decommissioning trusts for which additional tax basis is now recoverable, and an IRS audit settlement for the 2012-2013 tax returns. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for a discussion of the IRS audit settlement and the restructuring.

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Management's Financial Discussion and Analysis

Income Tax Legislation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Income Tax Legislation” in the Form 10-K for a discussion of the Tax Cuts and Jobs Act enacted in December 2017.  Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

 

Entergy Wholesale Commodities Exit from the Merchant Power Business

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K for a discussion of management’s strategy to shut down and sell all remaining plants in the Entergy Wholesale Commodities’ merchant nuclear fleet.  Following are updates to that discussion.

 

Vermont Yankee Disposition

As discussed in more detail in Note 16 to the financial statements herein, in January 2019, Entergy transferred 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC, the owner of the Vermont Yankee plant, to a subsidiary of NorthStar.

Sale of Pilgrim

 

As discussed in the Form 10-K, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of Pilgrim, for $1,000 (subject to adjustments for net liabilities and other amounts). On August 22, 2019, the NRC approved the transfer of Pilgrim’s facility licenses to Holtec. At that time, hearing requests filed by the Commonwealth of Massachusetts and Pilgrim Watch challenging Holtec’s financial qualifications and the sufficiency of the NRC’s review of the associated environmental impacts of the license transfer were pending with the NRC Commissioners. The NRC approval order included a condition acknowledging the NRC’s longstanding authority to modify, condition, or rescind the license transfer order as a result of any hearing that may be conducted.  On August 26, 2019, as permitted by the August 22 order, Entergy and Holtec closed the transaction. On September 3 and 4, 2019, Pilgrim Watch and Massachusetts each filed with the NRC motions to stay the effectiveness of the August 22 order pending the resolution of the NRC hearing process. The NRC has not yet ruled on the Pilgrim Watch and Massachusetts hearing requests or the stay motions. In addition, on September 25, 2019, Massachusetts filed a petition with the U.S. Court of Appeals for the District of Columbia Circuit, asking the court to vacate the NRC’s August 22 license transfer approval order and related approvals. On October 16, 2019, Entergy and Holtec filed a motion to intervene in the U.S. Court of Appeals proceeding. On October 28, 2019, Massachusetts filed a motion for stay pending appeal. The court of appeals has not yet ruled on Massachusetts’ petition.

    

The sale of Entergy Nuclear Generation Company to Holtec included the transfer of the nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $191 million ($156 million net-of-tax) in the third quarter 2019. See Note 16 to the financial statements herein for discussion of the closing of the Pilgrim transaction.

Planned Sale of Indian Point Energy Center

In April 2019, Entergy entered into an agreement to sell, directly or indirectly, 100% of the equity interests in the subsidiaries that own Indian Point 1, Indian Point 2, and Indian Point 3, after Indian Point 3 has been shut down and defueled, to a Holtec International subsidiary for decommissioning. The sale includes the transfer of the licenses, spent fuel, decommissioning liabilities, and nuclear decommissioning trusts for the three units.

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The transaction is subject to closing conditions, including approval from the NRC. Entergy and Holtec also plan to seek an order from the New York State Public Service Commission disclaiming jurisdiction, or alternatively approving the transaction. Closing is also conditioned on obtaining from the New York State Department of Environmental Conservation an agreement related to Holtec’s decommissioning plan as being consistent with applicable standards. The transaction closing is targeted for May 2021, following the defueling of Indian Point 3.

As consideration for the transfer to Holtec of its interest in Indian Point, Entergy will receive nominal cash consideration. The Indian Point transaction is expected to result in a loss based on the difference between Entergy’s adjusted net investment in the subsidiaries at closing and the sale price net of any agreed adjustments. As of September 30, 2019, Entergy’s adjusted net investment in the Indian Point units was $240 million. The primary variables in the ultimate loss that Entergy will incur are the values of the nuclear decommissioning trusts and the asset retirement obligations at closing, the financial results from plant operations until the closing, and the level of any unrealized deferred tax balances at closing. The terms of the transaction include limitations on withdrawals from the nuclear decommissioning trusts to fund decommissioning activities and controls on how Entergy manages the investment of nuclear decommissioning trust assets between signing and closing; however, the agreement does not require a minimum level of funding in the nuclear decommissioning trusts as a condition to closing.

Costs Associated with Entergy Wholesale Commodities Strategic Transactions

Entergy expects to incur employee retention and severance expenses associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. In addition, Entergy Wholesale Commodities incurred impairment charges related to nuclear fuel spending, nuclear refueling outage spending, and expenditures for capital assets of $8 million for the three months ended September 30, 2019 and $98 million for the nine months ended September 30, 2019. These costs were charged to expense as incurred as a result of the impaired value of certain of the Entergy Wholesale Commodities nuclear plants’ long-lived assets due to the significantly reduced remaining estimated operating lives associated with management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business. Entergy expects to continue to incur costs associated with nuclear fuel-related spending and expenditures for capital assets and, except for Palisades, expects to continue to charge these costs to expense as incurred because Entergy expects the value of the plants to continue to be impaired.

Liquidity and Capital Resources

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy’s capital structure, capital expenditure plans and other uses of capital, and sources of capital.  Following are updates to that discussion.

Capital Structure

Entergy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio for Entergy as of September 30, 2019 is primarily due to the settlement of the remaining equity forwards in 2019. See Note 3 to the financial statements herein for a discussion of the equity forward sale agreements.

	September 30, 2019			December 31, 2018
Debt to capital	65.4	%		66.7	%
Effect of excluding securitization bonds	(0.4	%)		(0.6	%)
Debt to capital, excluding securitization bonds (a)	65.0	%		66.1	%
Effect of subtracting cash	(1.2	%)		(0.6	%)
Net debt to net capital, excluding securitization bonds (a)	63.8	%		65.5	%

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Management's Financial Discussion and Analysis

(a)	Calculation excludes the Arkansas, Louisiana, New Orleans, and Texas securitization bonds, which are non-recourse to Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas, respectively.

Net debt consists of debt less cash and cash equivalents.  Debt consists of notes payable and commercial paper, financing lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt, common shareholders’ equity, and subsidiaries’ preferred stock without sinking fund.  Net capital consists of capital less cash and cash equivalents.  Entergy uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy’s financial condition because the securitization bonds are non-recourse to Entergy, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy’s financial condition because net debt indicates Entergy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019:

Capacity		Borrowings		Letters of Credit		Capacity Available
(In Millions)
$3,500		$155		$6		$3,339

A covenant in Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  The calculation of this debt ratio under Entergy Corporation’s credit facility is different than the calculation of the debt to capital ratio above. One such difference is that it excludes the effects, among other things, of certain impairments related to the Entergy Wholesale Commodities nuclear generation assets.  Entergy is currently in compliance with the covenant and expects to remain in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility’s maturity date may occur.  See Note 4 to the financial statements herein for additional discussion of the Entergy Corporation credit facility and discussion of the Registrant Subsidiaries’ credit facilities.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion. As of September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding. The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%.

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

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Management's Financial Discussion and Analysis

Capital Expenditure Plans and Other Uses of Capital

See the table and discussion in the Form 10-K under “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources - Capital Expenditure Plans and Other Uses of Capital,” that sets forth the amounts of planned construction and other capital investments by operating segment for 2019 through 2021. Following are updates to that discussion.

Preliminary Capital Investment Plan Estimate for 2020-2022

Entergy is developing its capital investment plan for 2020 through 2022 and currently anticipates that the Utility will make approximately $11.4 billion in capital investments during that period and that Entergy Wholesale Commodities will make approximately $65 million in capital investments, not including nuclear fuel, during that period. The preliminary Utility estimate includes specific investments such as the Lake Charles Power Station, Washington Parish Energy Center, Sunflower Solar Facility, New Orleans Power Station, New Orleans Solar Station and Montgomery County Power Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in Entergy’s nuclear fleet; software and security; and other investments. The preliminary Entergy Wholesale Commodities estimate includes amounts associated with specific investments, such as component replacement, software and security, and dry cask storage. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of business restructuring, regulatory constraints and requirements, environmental regulations, business opportunities, market volatility, economic trends, changes in project plans, and the ability to access capital.

St. Charles Power Station

As discussed in the Form 10-K, the LPSC issued an order in December 2016 approving certification that the public necessity and convenience would be served by the construction of the St. Charles Power Station. Commercial operation commenced in May 2019.

Choctaw Generating Station

In August 2018, Entergy Mississippi announced that it signed an asset purchase agreement to acquire from a subsidiary of GenOn Energy Inc. the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi.  The purchase price is expected to be approximately $314 million.  Entergy Mississippi also expects to invest in various plant upgrades at the facility after closing and expects the total cost of the acquisition to be approximately $401 million.  The purchase was contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and state regulatory and permitting agencies.  These included regulatory approvals from the MPSC and the FERC. Clearance under the Hart-Scott-Rodino Antitrust Improvements Act has occurred. In September 2019 the FERC approved the acquisition.  In October 2018, Entergy Mississippi filed an application with the MPSC seeking approval of the acquisition and cost recovery. In a separate filing in October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity additions approved by the MPSC. Entergy Mississippi executed a joint stipulation as to all issues with the Mississippi Public Utilities Staff and, in October 2019, the MPSC adopted the joint stipulation which approved Entergy Mississippi’s request to acquire, own, operate, improve, and maintain the facility. The MPSC approved the expected total cost of the acquisition of approximately $401 million and authorized Entergy Mississippi to recover acquisition and ownership costs of the facility through its formula rate plan, including costs incurred before the effective date of the interim capacity rate mechanism, which Entergy Mississippi expects to be approved later this year. Entergy Mississippi purchased the plant in October 2019.

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New Orleans Power Station

In June 2016, Entergy New Orleans filed an application with the City Council seeking a public interest determination and authorization to construct the New Orleans Power Station, a 226 MW advanced combustion turbine in New Orleans, Louisiana, at the site of the existing Michoud generating facility, which was retired effective May 31, 2016. In January 2017 several intervenors filed testimony opposing the construction of the New Orleans Power Station on various grounds. In July 2017, Entergy New Orleans submitted a supplemental and amending application to the City Council seeking approval to construct either the originally proposed 226 MW advanced combustion turbine, or alternatively, a 128 MW unit composed of natural gas-fired reciprocating engines and a related cost recovery plan. The cost estimate for the alternative 128 MW unit is $210 million. In addition, the application renewed the commitment to pursue up to 100 MW of renewable resources to serve New Orleans. In March 2018 the City Council adopted a resolution approving construction of the 128 MW unit. The targeted commercial operation date is mid-2020, subject to receipt of all necessary permits.

In April 2018 intervenors opposing the construction of the New Orleans Power Station filed with the City Council a request for rehearing, which was subsequently denied, and a petition for judicial review of the City Council’s decision, and also filed a lawsuit challenging the City Council’s approval based on Louisiana’s open meeting law. In May 2018 the City Council announced that it would initiate an investigation into allegations that Entergy New Orleans, Entergy, or some other entity paid or participated in paying certain attendees and speakers in support of the New Orleans Power Station to attend or speak at certain meetings organized by the City Council. In June 2018, Entergy New Orleans produced documents in response to a City Council resolution relating to this investigation. In October 2018 investigators for the City Council released their report, concluding that individuals were paid to attend and/or speak in support of the New Orleans Power Station and that Entergy New Orleans “knew or should have known that such conduct occurred or reasonably might occur.”  The City Council issued a resolution requiring Entergy New Orleans to show cause why it should not be fined $5 million as a result of the findings in the report. In November 2018, Entergy New Orleans submitted its response to the show cause resolution, disagreeing with certain characterizations and omissions of fact in the report and asserting that the City Council could not legally impose the proposed fine.  Simultaneous with the filing of its response to the show cause resolution, Entergy New Orleans sent a letter to the City Council re-asserting that the City Council’s imposition of the proposed fine would be unlawful, but acknowledging that the actions of a subcontractor, which was retained by an Entergy New Orleans contractor without the knowledge or contractually-required consent of Entergy New Orleans, were contrary to Entergy’s values.  In that letter, Entergy New Orleans offered to donate $5 million to the City Council to resolve the show cause proceeding.  In January 2019, Entergy New Orleans submitted a new settlement proposal to the City Council. The proposal retains the components of the first offer but adds to it a commitment to make reasonable efforts to limit the costs of the project to the $210 million cost estimate with advanced notification of anticipated cost overruns, additional reporting requirements for cost and environmental items, and a commitment regarding reliability investment and to work with the New Orleans Sewerage and Water Board to provide a reliable source of power. In February 2019 the City Council approved a resolution approving the settlement proposal and allowing the construction of the New Orleans Power Station to commence.

Also in February 2019, certain intervenors in the City Council proceeding on the New Orleans Power Station filed suit in Louisiana state court challenging the Louisiana Department of Environmental Quality’s issuance of the New Orleans Power Station’s air permit. Entergy New Orleans intervened in that lawsuit and, along with the Louisiana Department of Environmental Quality, filed exceptions seeking dismissal of the lawsuit. In June 2019 the state court judge sustained the exceptions and dismissed the plaintiffs’ petition with prejudice. Also in June 2019, a state court judge in New Orleans affirmed the City Council’s approval of the New Orleans Power Station and dismissed the petition for judicial review that had been filed in April 2018. The petitioners have filed an appeal of that ruling. Also in June 2019, with regard to the lawsuit challenging the City Council’s decision on the basis of a violation of the open meetings law, the same state court judge in New Orleans ruled that there was a violation of the open meetings law at the February 2018 meeting of the City Council’s Utilities, Cable, Telecommunications and Technology Committee at which that Committee considered the New Orleans Power Station approval, and further ruled that, although there was no violation of the open meetings law at the March 2018 full City Council meeting at which the New Orleans Power Station was

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approved, both the approval of the Committee and the approval of the full City Council were void. The City Council and Entergy New Orleans have each filed a suspensive appeal of the open meetings law ruling. A suspensive appeal suspends the effect of the judgment in the open meetings law proceeding while the appeal is being taken. The petitioners sought in the state appellate court, and then at the Louisiana Supreme Court, to terminate the suspension of the effect of the judgment, but both courts declined to do so. Appellate briefing on the merits both in the open meetings law appeal and in the judicial review appeal is scheduled to begin in November 2019. The New Orleans Power Station related settlement that was approved by the full City Council in February 2019 and that allowed Entergy New Orleans to move forward with the construction of the New Orleans Power Station was not affected by the state court judge’s open meetings ruling. Construction of the plant is underway and continuing.

Searcy Solar Facility

               In March 2019, Entergy Arkansas announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar energy facility that will be sited on approximately 800 acres in White County near Searcy, Arkansas.  The purchase is contingent upon, among other things, obtaining necessary approvals from applicable federal and state regulatory and permitting agencies.  The project will be constructed by a subsidiary of NextEra Energy Resources.  Entergy Arkansas will purchase the facility upon completion and after the other purchase contingencies have been met.  Closing is expected to occur by the end of 2021. In May 2019, Entergy Arkansas filed a petition with the APSC seeking a finding that the transaction is in the public interest and requesting all necessary approvals. In September 2019 other parties filed testimony largely supporting the resource acquisition but disputing Entergy Arkansas’s proposed method of cost recovery. Entergy Arkansas filed its rebuttal testimony in October 2019. A hearing is scheduled in January 2020.

Sunflower Solar Facility

    In November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi.  The estimated base purchase price is approximately $138.4 million.  The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 million. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and state regulatory and permitting agencies.  The project will be built by Sunflower County Solar Project, LLC, a sub-subsidiary of Recurrent Energy, LLC. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met.  In December 2018, Entergy Mississippi filed a joint petition with Sunflower Solar Project at the MPSC for Sunflower Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility.  Entergy Mississippi has proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the annual ownership costs of the Sunflower Solar Facility. In August 2019 consultants retained by the Mississippi Public Utilities Staff filed a report expressing concerns regarding the project economics and recommended that, should the MPSC wish to approve the project, Entergy Mississippi should be required to guarantee the energy output of the unit. Entergy Mississippi and the Staff are engaged in settlement discussions to address these concerns.  A hearing before the MPSC is targeted to occur in the fourth quarter of 2019. Closing is targeted to occur by the end of 2021.

Dividends

Declarations of dividends on Entergy’s common stock are made at the discretion of the Board.  Among other things, the Board evaluates the level of Entergy’s common stock dividends based upon earnings per share from the Utility operating segment and the Parent and Other portion of the business, financial strength, and future investment opportunities.  At its October 2019 meeting, the Board declared a dividend of $0.93 per share, an increase from the previous $0.91 quarterly dividend per share that Entergy has paid since the third quarter 2018.

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Cash Flow Activity

As shown in Entergy’s Consolidated Statements of Cash Flows, cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Millions)
Cash and cash equivalents at beginning of period		$481				$781
Cash flow provided by (used in):
Operating activities	2,118				1,860
Investing activities	(3,025		)		(3,000		)
Financing activities	1,382				1,347
Net increase in cash and cash equivalents	475				207
Cash and cash equivalents at end of period		$956				$988

Operating Activities

Net cash flow provided by operating activities increased $258 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a decrease of $193 million in pension contributions in 2019 as compared to the same period in 2018. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding;

•	the decrease in the return of unprotected excess accumulated deferred income taxes to Utility customers. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the regulatory activity regarding the Tax Cuts and Jobs Act;

•	an increase due to the timing of recovery of fuel and purchased power costs in 2019 as compared to the same period in 2018. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•	an increase of $94 million due to Vermont Yankee decommissioning spending in 2018; and

•	a decrease of $30 million in spending on nuclear refueling outage expenses in 2019 as compared to the same period in 2018.

The increase was partially offset by:

•	$140 million in severance and retention payments paid in 2019. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” herein and in the Form 10-K for a discussion of management’s strategy to exit the Entergy Wholesale Commodities’ merchant power business;

•	lower Entergy Wholesale Commodities revenues in 2019; and

•	the effect of less favorable weather on billed Utility sales in 2019.

Investing Activities

Net cash flow used in investing activities increased $25 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to an increase of $197 million in construction expenditures, primarily in the Utility business, as discussed below, partially offset by:

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•	a decrease of $116 million in nuclear fuel purchases due to variations from year to year in the timing and pricing of fuel reload requirements, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

•	a decrease of $67 million primarily due to changes in collateral posted to provide credit support to secure its obligations under agreements to sell power produced by Entergy Wholesale Commodities’ power plants.

The increase in construction expenditures in the Utility business is primarily due to:

•	an increase of $138 million primarily due to investment in the infrastructure of the distribution system, including increased spending on advanced metering infrastructure;

•	an increase of $76 million in storm spending in 2019; and

•	an increase of $164 million in transmission construction expenditures due to a higher scope of work performed in 2019 on various projects.

The increase in construction expenditures was partially offset by:

•	a decrease of $60 million in nuclear construction expenditures primarily due to lower spending in 2019 on various nuclear projects;

•	a decrease of $40 million in fossil-fueled generation construction expenditures primarily due to a lower scope of work performed in 2019 on various projects; and

•	a decrease of $36 million in information technology capital expenditures primarily due to lower spending in 2019 on critical infrastructure protection.

Financing Activities

Net cash flow provided by financing activities increased $35 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	proceeds of $608 million from the issuance of common stock as a result of the settlement of the remaining equity forwards in May 2019. See Note 3 to the financial statements herein for discussion of the equity forward sale agreements;

•	net repayments of short-term borrowings of $111 million in 2018 by the nuclear fuel company variable interest entities;

•	an increase of $65 million in treasury stock issuances in 2019 due to a larger amount of previously repurchased Entergy Corporation common stock issued in 2019 to satisfy stock option exercises; and

•	the issuance of $35 million aggregate liquidation value 5.375% Series A preferred stock in September 2019 by Entergy Texas.

The increase was partially offset by:

•	long-term debt activity providing approximately $1,274 million of cash in 2019 compared to approximately $1,422 million in 2018;

•	the repurchase in first quarter 2019 of $50 million of Class A mandatorily redeemable preferred membership units in Entergy Holdings Company LLC, a wholly-owned Entergy subsidiary, that were held by a third party;

•	an increase of $44 million in common dividends paid as a result of an increase in the shares outstanding and an increase in the quarterly dividend paid in 2019 compared to 2018; and

•	net repayments of $25 million of commercial paper in 2019 compared to net issuances of $480 million in 2018.

For the details of Entergy’s commercial paper program, the nuclear fuel company variable interest entities’ short-term borrowings, and long-term debt, see Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K.

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Rate, Cost-recovery, and Other Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Rate, Cost-recovery, and Other Regulation” in the Form 10-K for discussions of rate regulation, federal regulation, and related regulatory proceedings.

State and Local Rate Regulation and Fuel-Cost Recovery

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding these proceedings.

Federal Regulation

See Note 2 to the financial statements herein for updates to the discussion in the Form 10-K regarding federal regulatory proceedings.

Market and Credit Risk Sensitive Instruments

Commodity Price Risk

Power Generation

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy in the day ahead or spot markets.  Entergy Wholesale Commodities also sells unforced capacity, which allows load-serving entities to meet specified reserve and related requirements placed on them by the ISOs in their respective areas.  Entergy Wholesale Commodities’ forward physical power contracts consist of contracts to sell energy only, contracts to sell capacity only, and bundled contracts in which it sells both capacity and energy.  While the terminology and payment mechanics vary in these contracts, each of these types of contracts requires Entergy Wholesale Commodities to deliver MWh of energy, make capacity available, or both. In addition to its forward physical power contracts, Entergy Wholesale Commodities may also use a combination of financial contracts, including swaps, collars, and options, to manage forward commodity price risk. The sensitivities may not reflect the total maximum upside potential from higher market prices. The information contained in the following table represents projections at a point in time and will vary over time based on numerous factors, such as future market prices, contracting activities, and generation. Following is a summary of Entergy Wholesale Commodities’ current forward capacity and generation contracts as well as total revenue projections based on market prices as of September 30, 2019 (2019 represents the remainder of the year):

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Entergy Wholesale Commodities Nuclear Portfolio

		2019		2020		2021		2022
Energy
Percent of planned generation under contract (a):
Unit-contingent (b)		97%		97%		92%		66%
Planned generation (TWh) (c) (d)		6.1		17.8		9.6		2.8
Average revenue per MWh on contracted volumes:
Expected based on market prices as of September 30, 2019		$34.4		$41.6		$56.8		$58.8
Capacity
Percent of capacity sold forward (e):
Bundled capacity and energy contracts (f)		28%		37%		68%		97%
Capacity contracts (g)		38%		28%		—%		—%
Total		66%		65%		68%		97%
Planned net MW in operation (average) (d)		3,167		2,195		1,158		338
Average revenue under contract per kW per month (applies to capacity contracts only)		$3.5		$3.3		$—		$—
Total Energy and Capacity Revenues (h)
Expected sold and market total revenue per MWh		$36.7		$44.9		$54.5		$46.8
Sensitivity: -/+ $10 per MWh market price change		$36.4-$36.9		$44.7-$45.1		$53.6-$55.3		$43.4-$50.3

(a)	Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts, or options that mitigate price uncertainty. Positions that are not classified as hedges are netted in the planned generation under contract.

(b)

Transaction under which power is supplied from a specific generation asset; if the asset is not operating, the seller is generally not liable to the buyer for any damages. Certain unit-contingent sales include a guarantee of availability. Availability guarantees provide for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold. All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.

(c)	Amount of output expected to be generated by Entergy Wholesale Commodities nuclear resources considering plant operating characteristics and outage schedules.

(d)	Assumes the planned shutdown of Indian Point 2 on April 30, 2020, planned shutdown of Indian Point 3 on April 30, 2021, and planned shutdown of Palisades on May 31, 2022. For a discussion regarding the planned shutdown of the Indian Point 2, Indian Point 3, and Palisades plants, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” above.

(e)	Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.

(f)	A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.

(g)	A contract for the sale of an installed capacity product in a regional market.

(h)	Includes assumptions on converting a portion of the portfolio to contracted with fixed price and excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

Entergy estimates that a positive $10 per MWh change in the annual average energy price in the markets in which the Entergy Wholesale Commodities nuclear business sells power, based on September 30, 2019 market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax income

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of $2 million for the remainder of 2019. As of September 30, 2018, a positive $10 per MW change would have had a corresponding effect on pre-tax income of ($1) million for the remainder of 2018. A negative $10 per MWh change in the annual average energy price in the markets based on September 30, 2019 market conditions, planned generation volumes, and hedged positions, would have a corresponding effect on pre-tax income of ($2) million for the remainder of 2019. As of September 30, 2018, a negative $10 per MW change would have had a corresponding effect on pre-tax income of $1 million for the remainder of 2018.

Some of the agreements to sell the power produced by Entergy Wholesale Commodities’ power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations under the agreements. The Entergy subsidiary is required to provide credit support based upon the difference between the current market prices and contracted power prices in the regions where Entergy Wholesale Commodities sells power. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  Cash and letters of credit are also acceptable forms of credit support. At September 30, 2019, based on power prices at that time, Entergy had liquidity exposure of $85 million under the guarantees in place supporting Entergy Wholesale Commodities transactions and $21 million of posted cash collateral. In the event of a decrease in Entergy Corporation’s credit rating to below investment grade, based on power prices as of September 30, 2019, Entergy would have been required to provide approximately $30 million of additional cash or letters of credit under some of the agreements. As of September 30, 2019, the liquidity exposure associated with Entergy Wholesale Commodities assurance requirements, including return of previously posted collateral from counterparties, would increase by $140 million for a $1 per MMBtu increase in gas prices in both the short- and long-term markets.

As of September 30, 2019, substantially all of the credit exposure associated with the planned energy output under contract for Entergy Wholesale Commodities nuclear plants through 2022 is with counterparties or their guarantors that have public investment grade credit ratings.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters. The following is an update to that discussion.

Pilgrim

In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In August 2019, Entergy transferred 100% of the equity interests in Entergy Nuclear Generation Company, the owner of Pilgrim, to a subsidiary of Holtec International.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See Note 1 to the financial statements in the Form 10-K for discussion of new accounting pronouncements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Three Months Ended								Nine Months Ended
	2019				2018				2019				2018
	(In Thousands, Except Share Data)
OPERATING REVENUES
Electric		$2,812,934				$2,697,887				$7,279,683				$7,276,374
Natural gas	27,269				26,352				112,916				112,990
Competitive businesses	300,372				380,080				1,023,768				1,107,606
TOTAL	3,140,575				3,104,319				8,416,367				8,496,970
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	596,939				729,269				1,542,592				1,638,367
Purchased power	316,339				439,380				1,001,707				1,252,437
Nuclear refueling outage expenses	52,044				37,937				153,447				116,057
Other operation and maintenance	805,696				854,013				2,430,617				2,477,699
Asset write-offs, impairments, and related charges	198,086				155,215				288,483				297,082
Decommissioning	101,811				93,829				308,557				285,834
Taxes other than income taxes	165,731				161,916				487,715				485,682
Depreciation and amortization	379,219				324,628				1,099,990				1,022,099
Other regulatory charges (credits)	4,781				37,097				(38,698		)		223,416
TOTAL	2,620,646				2,833,284				7,274,410				7,798,673
OPERATING INCOME	519,929				271,035				1,141,957				698,297
OTHER INCOME
Allowance for equity funds used during construction	33,161				32,354				108,546				92,367
Interest and investment income	82,295				177,081				406,663				265,086
Miscellaneous - net	(50,086		)		(43,591		)		(160,614		)		(123,439		)
TOTAL	65,370				165,844				354,595				234,014
INTEREST EXPENSE
Interest expense	201,412				195,311				603,517				570,548
Allowance for borrowed funds used during construction	(14,773		)		(15,244		)		(49,034		)		(43,177		)
TOTAL	186,639				180,067				554,483				527,371
INCOME BEFORE INCOME TAXES	398,660				256,812				942,069				404,940
Income taxes	29,201				(283,006		)		73,430				(519,937		)
CONSOLIDATED NET INCOME	369,459				539,818				868,639				924,877
Preferred dividend requirements of subsidiaries	4,219				3,439				12,438				10,317
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION		$365,240				$536,379				$856,201				$914,560
Earnings per average common share:
Basic		$1.84				$2.96				$4.42				$5.06
Diluted		$1.82				$2.92				$4.38				$5.01
Basic average number of common shares outstanding	198,932,387				181,002,303				193,876,557				180,845,440
Diluted average number of common shares outstanding	200,492,935				183,664,583				195,685,851				182,692,325
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Three Months Ended								Nine Months Ended
	2019				2018				2019				2018
	(In Thousands)
Net Income		$369,459				$539,818				$868,639				$924,877
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss) (net of tax expense (benefit) of ($5,343), ($8,517), $14,547, and ($480))	(20,103		)		(32,004		)		62,453				(1,645		)
Pension and other postretirement liabilities (net of tax expense of $6,760, $4,126, $13,086, and $12,919)	25,464				15,265				48,510				47,404
Net unrealized investment gain (loss) (net of tax expense (benefit) of $1,303, ($825), $17,472, and $1,078)	5,271				(1,745		)		33,244				(37,242		)
Other comprehensive income (loss)	10,632				(18,484		)		144,207				8,517
Comprehensive Income	380,091				521,334				1,012,846				933,394
Preferred dividend requirements of subsidiaries	4,219				3,439				12,438				10,317
Comprehensive Income Attributable to Entergy Corporation		$375,872				$517,895				$1,000,408				$923,077
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Consolidated net income			$868,639				$924,877
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		1,634,677				1,517,344
Deferred income taxes, investment tax credits, and non-current taxes accrued		373,723				82,641
Asset write-offs, impairments, and related charges		225,175				210,263
Changes in working capital:
Receivables		(231,005		)		(153,703		)
Fuel inventory		(14,399		)		49,728
Accounts payable		(175,246		)		79,949
Taxes accrued		(2,420		)		43,510
Interest accrued		(2,314		)		(9,398		)
Deferred fuel costs		90,319				(25,284		)
Other working capital accounts		(19,232		)		(86,063		)
Changes in provisions for estimated losses		14,114				28,599
Changes in other regulatory assets		(92,861		)		207,135
Changes in other regulatory liabilities		(19,115		)		(413,684		)
Changes in pensions and other postretirement liabilities		(132,044		)		(345,526		)
Other		(400,064		)		(250,884		)
Net cash flow provided by operating activities		2,117,947				1,859,504
INVESTING ACTIVITIES
Construction/capital expenditures		(3,079,726		)		(2,883,047		)
Allowance for equity funds used during construction		108,867				92,829
Nuclear fuel purchases		(55,176		)		(170,819		)
Proceeds from sale of assets		19,801				12,915
Insurance proceeds received for property damages		7,040				10,523
Changes in securitization account		(4,213		)		(12,985		)
Payments to storm reserve escrow account		(6,184		)		(4,515		)
Decrease (increase) in other investments		30,370				(36,140		)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		2,369				—
Proceeds from nuclear decommissioning trust fund sales		3,518,616				4,177,919
Investment in nuclear decommissioning trust funds		(3,566,690		)		(4,187,161		)
Net cash flow used in investing activities		(3,024,926		)		(3,000,481		)
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
FINANCING ACTIVITIES
Proceeds from the issuance of:
Long-term debt		7,133,571				5,604,131
Preferred stock of subsidiary		33,486				—
Treasury stock		89,303				24,646
Common stock		607,650				—
Retirement of long-term debt		(5,859,714		)		(4,181,820		)
Repurchase of preferred membership units		(50,000		)		—
Changes in credit borrowings and commercial paper - net		(24,550		)		368,370
Other		(9,175		)		25,540
Dividends paid:
Common stock		(526,408		)		(482,865		)
Preferred stock		(12,328		)		(10,317		)
Net cash flow provided by financing activities		1,381,835				1,347,685
Net increase in cash and cash equivalents		474,856				206,708
Cash and cash equivalents at beginning of period		480,975				781,273
Cash and cash equivalents at end of period			$955,831				$987,981
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized			$584,622				$558,381
Income taxes			($8,649	)			$18,200
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$70,395				$56,690
Temporary cash investments		885,436				424,285
Total cash and cash equivalents		955,831				480,975
Accounts receivable:
Customer		732,763				558,494
Allowance for doubtful accounts		(7,987		)		(7,322		)
Other		132,547				167,722
Accrued unbilled revenues		481,048				395,511
Total accounts receivable		1,338,371				1,114,405
Deferred fuel costs		—				27,251
Fuel inventory - at average cost		131,703				117,304
Materials and supplies - at average cost		803,843				752,843
Deferred nuclear refueling outage costs		173,229				230,960
Prepayments and other		258,695				234,326
TOTAL		3,661,672				2,958,064
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds		6,128,647				6,920,164
Non-utility property - at cost (less accumulated depreciation)		326,704				304,382
Other		448,140				437,265
TOTAL		6,903,491				7,661,811
PROPERTY, PLANT, AND EQUIPMENT
Electric		52,705,142				49,831,486
Natural gas		533,217				496,150
Construction work in progress		2,871,054				2,888,639
Nuclear fuel		707,198				861,272
TOTAL PROPERTY, PLANT, AND EQUIPMENT		56,816,611				54,077,547
Less - accumulated depreciation and amortization		22,695,886				22,103,101
PROPERTY, PLANT, AND EQUIPMENT - NET		34,120,725				31,974,446
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $268,177 as of September 30, 2019 and $360,790 as of December 31, 2018)		4,839,357				4,746,496
Deferred fuel costs		239,793				239,496
Goodwill		377,172				377,172
Accumulated deferred income taxes		67,438				54,593
Other		296,620				262,988
TOTAL		5,820,380				5,680,745
TOTAL ASSETS			$50,506,268				$48,275,066
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt			$520,012				$650,009
Notes payable and commercial paper		1,917,788				1,942,339
Accounts payable		1,328,631				1,496,058
Customer deposits		409,090				411,505
Taxes accrued		251,821				254,241
Interest accrued		190,877				193,192
Deferred fuel costs		115,761				52,396
Pension and other postretirement liabilities		57,374				61,240
Current portion of unprotected excess accumulated deferred income taxes		117,575				248,127
Other		194,117				134,437
TOTAL		5,103,046				5,443,544
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		4,552,456				4,107,152
Accumulated deferred investment tax credits		206,837				213,101
Regulatory liability for income taxes-net		1,677,707				1,817,021
Other regulatory liabilities		1,871,005				1,620,254
Decommissioning and asset retirement cost liabilities		6,068,323				6,355,543
Accumulated provisions		528,172				514,107
Pension and other postretirement liabilities		2,487,906				2,616,085
Long-term debt (includes securitization bonds of $338,408 as of September 30, 2019 and $423,858 as of December 31, 2018)		16,938,014				15,518,303
Other		783,330				1,006,249
TOTAL		35,113,750				33,767,815
Commitments and Contingencies
Subsidiaries' preferred stock without sinking fund		219,411				219,402
EQUITY
Common stock, $.01 par value, authorized 500,000,000 shares; issued 270,035,180 shares in 2019 and 261,587,009 shares in 2018		2,700				2,616
Paid-in capital		6,553,009				5,951,431
Retained earnings		9,057,749				8,721,150
Accumulated other comprehensive loss		(419,772		)		(557,173		)
Less - treasury stock, at cost (70,947,950 shares in 2019 and 72,530,866 shares in 2018)		5,158,625				5,273,719
Total common shareholder's equity		10,035,061				8,844,305
Subsidiary's preferred stock without sinking fund		35,000				—
TOTAL		10,070,061				8,844,305
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY			$50,506,268				$48,275,066
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2018
(Unaudited)
					Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock				Common Stock				Treasury Stock				Paid-in Capital				Retained Earnings				Accumulated Other Comprehensive Loss				Total
	(In Thousands)
Balance at December 31, 2017		$—				$2,548				($5,397,637	)			$5,433,433				$7,977,702				($23,531	)			$7,992,515
Implementation of accounting standards	—				—				—				—				576,257				(632,617		)		(56,360		)
Balance at January 1, 2018	—				2,548				(5,397,637		)		5,433,433				8,553,959				(656,148		)		7,936,155
Consolidated net income	3,439				—				—				—				132,761				—				136,200
Other comprehensive income	—				—				—				—				—				79,145				79,145
Common stock issuances related to stock plans	—				—				20,477				(16,170		)		—				—				4,307
Common stock dividends declared	—				—				—				—				(160,887		)		—				(160,887		)
Preferred dividend requirements of subsidiaries	(3,439		)		—				—				—				—				—				(3,439		)
Reclassification pursuant to ASU 2018-02	—				—				—				—				(32,043		)		15,505				(16,538		)
Balance at March 31, 2018	—				2,548				(5,377,160		)		5,417,263				8,493,790				(561,498		)		7,974,943
Consolidated net income	3,439				—				—				—				245,421				—				248,860
Other comprehensive loss	—				—				—				—				—				(52,144		)		(52,144		)
Common stock issuances related to stock plans	—				—				3,035				12,141				—				—				15,176
Common stock dividends declared	—				—				—				—				(160,935		)		—				(160,935		)
Preferred dividend requirements of subsidiaries	(3,439		)		—				—				—				—				—				(3,439		)
Balance at June 30, 2018	—				2,548				(5,374,125		)		5,429,404				8,578,276				(613,642		)		8,022,461
Consolidated net income	3,439				—				—				—				536,379				—				539,818
Other comprehensive loss	—				—				—				—				—				(18,484		)		(18,484		)
Common stock issuances related to stock plans	—				—				21,108				12,292				—				—				33,400
Common stock dividends declared	—				—				—				—				(161,044		)		—				(161,044		)
Preferred dividend requirements of subsidiaries	(3,439		)		—				—				—				—				—				(3,439		)
Balance at September 30, 2018		$—				$2,548				($5,353,017	)			$5,441,696				$8,953,611				($632,126	)			$8,412,712
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2019
(Unaudited)
					Common Shareholders’ Equity
	Subsidiaries' Preferred Stock				Common Stock				Treasury Stock				Paid-in Capital				Retained Earnings				Accumulated Other Comprehensive Loss				Total
	(In Thousands)
Balance at December 31, 2018		$—				$2,616				($5,273,719	)			$5,951,431				$8,721,150				($557,173	)			$8,844,305
Implementation of accounting standards	—				—				—				—				6,806				(6,806		)		—
Balance at January 1, 2019	—				2,616				(5,273,719		)		5,951,431				8,727,956				(563,979		)		8,844,305
Consolidated net income	4,109				—				—				—				254,537				—				258,646
Other comprehensive income	—				—				—				—				—				12,827				12,827
Common stock issuances related to stock plans	—				—				62,537				(31,248		)		—				—				31,289
Common stock dividends declared	—				—				—				—				(172,591		)		—				(172,591		)
Preferred dividend requirements of subsidiaries	(4,109		)		—				—				—				—				—				(4,109		)
Balance at March 31, 2019	—				2,616				(5,211,182		)		5,920,183				8,809,902				(551,152		)		8,970,367
Consolidated net income	4,109				—				—				—				236,424				—				240,533
Other comprehensive income	—				—				—				—				—				120,748				120,748
Settlement of equity forwards through common stock issuance	—				84				—				607,566				—				—				607,650
Common stock issuance costs	—				—				—				(7		)		—				—				(7		)
Common stock issuances related to stock plans	—				—				23,391				11,791				—				—				35,182
Common stock dividends declared	—				—				—				—				(172,861		)		—				(172,861		)
Preferred dividend requirements of subsidiaries	(4,109		)		—				—				—				—				—				(4,109		)
Balance at June 30, 2019	—				2,700				(5,187,791		)		6,539,533				8,873,465				(430,404		)		9,797,503
Consolidated net income	4,219				—				—				—				365,240				—				369,459
Other comprehensive income	—				—				—				—				—				10,632				10,632
Common stock issuances related to stock plans	—				—				29,166				13,476				—				—				42,642
Common stock dividends declared	—				—				—				—				(180,956		)		—				(180,956		)
Subsidiary's preferred stock issuance	35,000				—				—				—				—				—				35,000
Preferred dividend requirements of subsidiaries	(4,219		)		—				—				—				—				—				(4,219		)
Balance at September 30, 2019		$35,000				$2,700				($5,158,625	)			$6,553,009				$9,057,749				($419,772	)			$10,070,061
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars in Millions)
Utility electric operating revenues:
Residential			$1,155				$1,139				$16			1
Commercial		722				694				28				4
Industrial		686				683				3				—
Governmental		62				61				1				2
Total billed retail		2,625				2,577				48				2
Sales for resale		63				76				(13		)		(17	)
Other		125				45				80				178
Total			$2,813				$2,698				$115			4
Utility billed electric energy sales (GWh):
Residential		11,627				11,821				(194		)		(2	)
Commercial		8,499				8,726				(227		)		(3	)
Industrial		12,861				12,879				(18		)		—
Governmental		705				714				(9		)		(1	)
Total retail		33,692				34,140				(448		)		(1	)
Sales for resale		3,025				2,978				47				2
Total		36,717				37,118				(401		)		(1	)
Entergy Wholesale Commodities:
Operating revenues			$300				$380				($80	)		(21	)
Billed electric energy sales (GWh)		6,847				7,576				(729		)		(10	)
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars in Millions)
Utility electric operating revenues:
Residential			$2,727				$2,800				($73	)		(3	)
Commercial		1,872				1,871				1				—
Industrial		1,929				1,905				24				1
Governmental		172				174				(2		)		(1	)
Total billed retail		6,700				6,750				(50		)		(1	)
Sales for resale		223				215				8				4
Other		357				311				46				15
Total			$7,280				$7,276				$4			—
Utility billed electric energy sales (GWh):
Residential		27,749				28,857				(1,108		)		(4	)
Commercial		21,764				22,401				(637		)		(3	)
Industrial		36,509				36,503				6				—
Governmental		1,932				1,934				(2		)		—
Total retail		87,954				89,695				(1,741		)		(2	)
Sales for resale		10,009				8,788				1,221				14
Total		97,963				98,483				(520		)		(1	)
Entergy Wholesale Commodities:
Operating revenues			$1,024				$1,108				($84	)		(8	)
Billed electric energy sales (GWh)		21,308				21,853				(545		)		(2	)

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ENTERGY CORPORATION AND SUBSIDIARIES

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

NOTE 1.  COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

ANO Damage, Outage, and NRC Reviews

See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs.

Pilgrim NRC Oversight and Shutdown

See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

 

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.

Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion.

Capital Funds Agreement (Entergy Corporation and System Energy)

Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.

NOTE 2.  RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Regulatory activity regarding the Tax Cuts and Jobs Act

System Energy

In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning.

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Entergy Corporation and Subsidiaries

Notes to Financial Statements

Fuel and purchased power cost recovery

Entergy Arkansas

Production Cost Allocation Rider

In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020.

Energy Cost Recovery Rider

In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding.

Entergy Louisiana

In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations.

Entergy Mississippi

Mississippi Attorney General Complaint

As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting

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and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court.

Entergy Texas

In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2019 Formula Rate Plan Filing

In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a

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write off of the $11.2 million White Bluff scrubber regulatory asset.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2017 Formula Rate Plan Filing

Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019.

2018 Formula Rate Plan Filing

In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues.

Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing.

Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests.

Investigation of Costs Billed by Entergy Services

In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit.

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Retail Rates - Gas

2018 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review.

Gas Rate Stabilization Plan Extension Request

In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020.

Filings with the MPSC (Entergy Mississippi)

Formula Rate Plan

In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019.

Filings with the City Council (Entergy New Orleans)

Retail Rates

See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by

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the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting.

Filings with the PUCT (Entergy Texas)

Base Rate Case

In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT.

Other Filings

In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application.

In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT.

In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending.

System Agreement Cost Equalization Proceedings

As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the

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calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:

	Payments (Receipts)
	(In Millions)
Entergy Arkansas	($4)
Entergy Louisiana	($23)
Entergy Mississippi	$16
Entergy New Orleans	$5
Entergy Texas	$6

These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019.

Rough Production Cost Equalization

2010 Rate Filing Based on Calendar Year 2009 Production Costs

In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:

	Payments (Receipts)
	(In Millions)
Entergy Arkansas	$2
Entergy Louisiana	$6
Entergy Mississippi	($4)
Entergy New Orleans	($1)
Entergy Texas	($3)

 

In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the

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payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint.

In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding.

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019

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settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding.

In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint).

In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period.

In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding.

Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020.

In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity.

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In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt.

In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable.

Grand Gulf Sale-leaseback Renewal Complaint

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1.

In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019.

In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties.

In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511

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million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.

NOTE 3.  EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas)

Common Stock

Earnings per Share

The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:

	For the Three Months Ended September 30,
	2019											2018
	(In Millions, Except Per Share Data)
	Income				Shares			$/share				Income				Shares			$/share
Basic earnings per share
Net income attributable to Entergy Corporation		$365.2			198.9				$1.84				$536.4			181.0				$2.96
Average dilutive effect of:
Stock options					0.7			(0.01		)						0.4			(0.01		)
Other equity plans					0.9			(0.01		)						0.8			(0.01		)
Equity forwards					—			—								1.5			(0.02		)
Diluted earnings per share		$365.2			200.5				$1.82				$536.4			183.7				$2.92

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018.

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Notes to Financial Statements

	For the Nine Months Ended September 30,
	2019											2018
	(In Millions, Except Per Share Data)
	Income				Shares			$/share				Income				Shares			$/share
Basic earnings per share
Net income attributable to Entergy Corporation		$856.2			193.9				$4.42				$914.6			180.8				$5.06
Average dilutive effect of:
Stock options					0.5			(0.01		)						0.3			(0.01		)
Other equity plans					0.7			(0.02		)						0.7			(0.01		)
Equity forwards					0.6			(0.01		)						0.9			(0.03		)
Diluted earnings per share		$856.2			195.7				$4.38				$914.6			182.7				$5.01

The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018. Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018.

Equity Forward Sale Agreements

As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million. In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million.

Treasury Stock

During the nine months ended September 30, 2019, Entergy Corporation issued 1,582,916 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2019.

Retained Earnings

On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019.

Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales.

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Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:

	Cash flow hedges net unrealized gain (loss)				Pension and other postretirement liabilities				Net unrealized investment gain (loss)				Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, July 1, 2019		$51,736				($508,876	)			$26,736				($430,404	)
Other comprehensive income (loss) before reclassifications	(5,190		)		—				8,350				3,160
Amounts reclassified from accumulated other comprehensive income (loss)	(14,913		)		25,464				(3,079		)		7,472
Net other comprehensive income (loss) for the period	(20,103		)		25,464				5,271				10,632
Ending balance, September 30, 2019		$31,633				($483,412	)			$32,007				($419,772	)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component:

	Cash flow hedges net unrealized gain (loss)				Pension and other postretirement liabilities				Net unrealized investment gain (loss)				Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Beginning balance, July 1, 2018		($14,874	)			($589,926	)			($8,842	)			($613,642	)
Other comprehensive income (loss) before reclassifications	(40,401		)		—				(7,173		)		(47,574		)
Amounts reclassified from accumulated other comprehensive income (loss)	8,397				15,265				5,428				29,090
Net other comprehensive income (loss) for the period	(32,004		)		15,265				(1,745		)		(18,484		)
Ending balance, September 30, 2018		($46,878	)			($574,661	)			($10,587	)			($632,126	)

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Notes to Financial Statements

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:

	Cash flow hedges net unrealized gain (loss)				Pension and other postretirement liabilities				Net unrealized investment gain (loss)				Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Ending balance, December 31, 2018		($23,135	)			($531,922	)			($2,116	)			($557,173	)
Implementation of accounting standards	(7,685		)		—				879				(6,806		)
Beginning balance, January 1, 2019		($30,820	)			($531,922	)			($1,237	)			($563,979	)
Other comprehensive income (loss) before reclassifications	122,481				—				37,724				160,205
Amounts reclassified from accumulated other comprehensive income (loss)	(60,028		)		48,510				(4,480		)		(15,998		)
Net other comprehensive income (loss) for the period	62,453				48,510				33,244				144,207
Ending balance, September 30, 2019		$31,633				($483,412	)			$32,007				($419,772	)

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component:

	Cash flow hedges net unrealized gain (loss)				Pension and other postretirement liabilities				Net unrealized investment gain (loss)				Total Accumulated Other Comprehensive Income (Loss)
	(In Thousands)
Ending balance, December 31, 2017		($37,477	)			($531,099	)			$545,045				($23,531	)
Implementation of accounting standards	—				—				(632,617		)		(632,617		)
Beginning balance, January 1, 2018		($37,477	)			($531,099	)			($87,572	)			($656,148	)
Other comprehensive income (loss) before reclassifications	(31,816		)		—				(50,958		)		(82,774		)
Amounts reclassified from accumulated other comprehensive income (loss)	30,171				47,404				13,716				91,291
Net other comprehensive income (loss) for the period	(1,645		)		47,404				(37,242		)		8,517
Reclassification pursuant to ASU 2018-02	(7,756		)		(90,966		)		114,227				15,505
Ending balance, September 30, 2018		($46,878	)			($574,661	)			($10,587	)			($632,126	)

The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018:

		Pension and Other Postretirement Liabilities
		2019				2018
		(In Thousands)
Beginning balance, July 1,			($8,091	)			($57,451	)
Amounts reclassified from accumulated other comprehensive income (loss)		(969		)		(500		)
Net other comprehensive income (loss) for the period		(969		)		(500		)
Ending balance, September 30,			($9,060	)			($57,951	)

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The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018:

		Pension and Other Postretirement Liabilities
		2019				2018
		(In Thousands)
Beginning balance, January 1,			($6,153	)			($46,400	)
Amounts reclassified from accumulated other comprehensive income (loss)		(2,907		)		(1,502		)
Net other comprehensive income (loss) for the period		(2,907		)		(1,502		)
Reclassification pursuant to ASU 2018-02		—				(10,049		)
Ending balance, September 30,			($9,060	)			($57,951	)

    

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows:

	Amounts reclassified from AOCI								Income Statement Location
	2019				2018
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts		$18,925				($10,566	)		Competitive business operating revenues
Interest rate swaps	(48		)		(63		)		Miscellaneous - net
Total realized gain (loss) on cash flow hedges	18,877				(10,629		)
	(3,964		)		2,232				Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)		$14,913				($8,397	)
Pension and other postretirement liabilities
Amortization of prior-service credit		$5,325				$5,425			(a)
Amortization of loss	(20,919		)		(24,740		)		(a)
Settlement loss	(16,630		)		(76		)		(a)
Total amortization	(32,224		)		(19,391		)
	6,760				4,126				Income taxes
Total amortization (net of tax)		($25,464	)			($15,265	)
Net unrealized investment gain (loss)
Realized gain (loss)		$4,872				($8,589	)		Interest and investment income
	(1,793		)		3,161				Income taxes
Total realized investment gain (loss) (net of tax)		$3,079				($5,428	)
Total reclassifications for the period (net of tax)		($7,472	)			($29,090	)

(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows:

	Amounts reclassified from AOCI								Income Statement Location
	2019				2018
	(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts		$76,129				($37,913	)		Competitive business operating revenues
Interest rate swaps	(145		)		(278		)		Miscellaneous - net
Total realized gain (loss) on cash flow hedges	75,984				(38,191		)
	(15,956		)		8,020				Income taxes
Total realized gain (loss) on cash flow hedges (net of tax)		$60,028				($30,171	)
Pension and other postretirement liabilities
Amortization of prior-service credit		$15,977				$16,278			(a)
Amortization of loss	(58,888		)		(74,503		)		(a)
Settlement loss	(18,685		)		(2,098		)		(a)
Total amortization	(61,596		)		(60,323		)
	13,086				12,919				Income taxes
Total amortization (net of tax)		($48,510	)			($47,404	)
Net unrealized investment gain (loss)
Realized gain (loss)		$7,088				($21,703	)		Interest and investment income
	(2,608		)		7,987				Income taxes
Total realized investment gain (loss) (net of tax)		$4,480				($13,716	)
Total reclassifications for the period (net of tax)		$15,998				($91,291	)

(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows:

		Amounts reclassified from AOCI								Income Statement Location
		2019				2018
		(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit			$1,837				$1,934			(a)
Amortization of loss		(526		)		(1,257		)		(a)
Total amortization		1,311				677
		(342		)		(177		)		Income taxes
Total amortization (net of tax)		969				500
Total reclassifications for the period (net of tax)			$969				$500

(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows:

		Amounts reclassified from AOCI								Income Statement Location
		2019				2018
		(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service credit			$5,511				$5,802			(a)
Amortization of loss		(1,578		)		(3,770		)		(a)
Total amortization		3,933				2,032
		(1,026		)		(530		)		Income taxes
Total amortization (net of tax)		2,907				1,502
Total reclassifications for the period (net of tax)			$2,907				$1,502

(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

Preferred Stock

In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share.

Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy

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Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.

NOTE 4.  REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019.

Capacity		Borrowings		Letters of Credit		Capacity Available
(In Millions)
$3,500		$155		$6		$3,339

Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%.

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows:

Company		Expiration Date		Amount of Facility		Interest Rate (a)		Amount Drawn as of September 30, 2019		Letters of Credit Outstanding as of September 30, 2019
Entergy Arkansas		April 2020		$20 million (b)		3.17%		$—		$—
Entergy Arkansas		September 2024		$150 million (c)		3.17%		$—		$—
Entergy Louisiana		September 2024		$350 million (c)		3.17%		$—		$—
Entergy Mississippi		May 2020		$37.5 million (d)		3.54%		$—		$—
Entergy Mississippi		May 2020		$35 million (d)		3.54%		$—		$—
Entergy Mississippi		May 2020		$10 million (d)		3.54%		$—		$—
Entergy New Orleans		November 2021		$25 million (c)		3.32%		$—		$0.8 million
Entergy Texas		September 2024		$150 million (c)		3.54%		$—		$1.3 million

(a)	The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility.

(b)	Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

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(c)	The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

(d)	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019:

Company		Amount of Uncommitted Facility		Letter of Credit Fee		Letters of Credit Issued as of September 30, 2019 (a)
Entergy Arkansas		$25 million		0.70%		$1 million
Entergy Louisiana		$125 million		0.70%		$11.7 million
Entergy Mississippi		$65 million		0.70%		$8.1 million
Entergy New Orleans		$15 million		1.00%		$1 million
Entergy Texas		$50 million		0.70%		$26.2 million

(a)	As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:

	Authorized		Borrowings
	(In Millions)
Entergy Arkansas	$250		$—
Entergy Louisiana	$450		$—
Entergy Mississippi	$175		$—
Entergy New Orleans	$150		$46
Entergy Texas	$200		$—
System Energy	$200		$—

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Notes to Financial Statements

Vermont Yankee Asset Retirement Management, LLC Credit Facility

In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar.

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019:

Company		Expiration Date		Amount of Facility		Weighted Average Interest Rate on Borrowings (a)		Amount Outstanding as of September 30, 2019
				(Dollars in Millions)
Entergy Arkansas VIE		September 2021		$80		3.41%		$30.3
Entergy Louisiana River Bend VIE		September 2021		$105		3.37%		$84.3
Entergy Louisiana Waterford VIE		September 2021		$105		3.41%		$65.5
System Energy VIE		September 2021		$120		3.42%		$53.6

(a)	Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization.

The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows:

Company		Description		Amount
Entergy Arkansas VIE		3.65% Series L due July 2021		$90 million
Entergy Arkansas VIE		3.17% Series M due December 2023		$40 million
Entergy Louisiana River Bend VIE		3.38% Series R due August 2020		$70 million
Entergy Louisiana Waterford VIE		3.92% Series H due February 2021		$40 million
Entergy Louisiana Waterford VIE		3.22% Series I due December 2023		$20 million
System Energy VIE		3.42% Series J due April 2021		$100 million

In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

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Debt Issuances and Retirements

(Entergy Arkansas)

In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes.

(Entergy Louisiana)

In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes.

(Entergy Mississippi)

In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes.

(Entergy Texas)

In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes.

In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049.

Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes.

(System Energy)

In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022.

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Notes to Financial Statements

Fair Value

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:

	Book Value of Long-Term Debt				Fair Value of Long-Term Debt (a) (b)
	(In Thousands)
Entergy		$17,458,026				$18,628,268
Entergy Arkansas		$3,538,384				$3,621,073
Entergy Louisiana		$7,344,160				$8,038,675
Entergy Mississippi		$1,469,454				$1,586,199
Entergy New Orleans		$478,619				$522,688
Entergy Texas		$1,938,303				$2,128,842
System Energy		$570,001				$554,374

(a)	The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year.

(b)	Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:

	Book Value of Long-Term Debt				Fair Value of Long-Term Debt (a) (b)
	(In Thousands)
Entergy		$16,168,312				$15,880,239
Entergy Arkansas		$3,225,759				$3,002,627
Entergy Louisiana		$6,805,768				$6,834,134
Entergy Mississippi		$1,325,750				$1,276,452
Entergy New Orleans		$483,704				$491,569
Entergy Texas		$1,513,735				$1,528,828
System Energy		$630,750				$596,123

(a)	The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year.

(b)	Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

NOTE 5.  STOCK-BASED COMPENSATION (Entergy Corporation)

Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

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Notes to Financial Statements

Stock Options

Entergy granted options on 693,161 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2019 with a fair value of $8.32 per option.  As of September 30, 2019, there were options on 2,515,896 shares of common stock outstanding with a weighted-average exercise price of $78.53.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of September 30, 2019.  The aggregate intrinsic value of the stock options outstanding as of September 30, 2019 was $97.7 million.

The following table includes financial information for outstanding stock options for the three months ended September 30, 2019 and 2018:

	2019				2018
	(In Millions)
Compensation expense included in Entergy’s net income		$0.9				$1.1
Tax benefit recognized in Entergy’s net income		$0.2				$0.2
Compensation cost capitalized as part of fixed assets and materials and supplies		$0.4				$0.1

The following table includes financial information for outstanding stock options for the nine months ended September 30, 2019 and 2018:

	2019				2018
	(In Millions)
Compensation expense included in Entergy’s net income		$2.9				$3.3
Tax benefit recognized in Entergy’s net income		$0.7				$0.8
Compensation cost capitalized as part of fixed assets and materials and supplies		$1.0				$0.5

Other Equity Awards

In January 2019, the Board approved and Entergy granted 355,537 restricted stock awards and 180,824 long-term incentive awards under the 2015 Equity Ownership Plan.  The restricted stock awards were made effective as of January 31, 2019 and were valued at $89.19 per share, which was the closing price of Entergy’s common stock on that date.  One-third of the restricted stock awards will vest upon each anniversary of the grant date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period.

In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. For the 2019-2021 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on a cumulative adjusted earnings per share metric.  The performance units were granted as of January 31, 2019 and eighty percent were valued at $102.07 per share based on various factors, primarily market conditions; and twenty percent were valued at $89.19 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.

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The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2019 and 2018:

	2019				2018
	(In Millions)
Compensation expense included in Entergy’s net income		$8.4				$8.5
Tax benefit recognized in Entergy’s net income		$2.1				$2.2
Compensation cost capitalized as part of fixed assets and materials and supplies		$3.0				$2.5

The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2019 and 2018:

	2019				2018
	(In Millions)
Compensation expense included in Entergy’s net income		$25.6				$26.0
Tax benefit recognized in Entergy’s net income		$6.5				$6.6
Compensation cost capitalized as part of fixed assets and materials and supplies		$8.8				$7.3

NOTE 6.  RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Components of Qualified Net Pension Cost

Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:

	2019				2018
	(In Thousands)
Service cost - benefits earned during the period		$33,553				$38,752
Interest cost on projected benefit obligation	73,261				66,854
Expected return on assets	(103,751		)		(110,535		)
Amortization of prior service cost	—				99
Amortization of net loss	60,395				68,526
Settlement charges	16,291				—
Net pension costs		$79,749				$63,696

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Notes to Financial Statements

Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:

	2019				2018
	(In Thousands)
Service cost - benefits earned during the period		$100,766				$116,256
Interest cost on projected benefit obligation	221,114				200,562
Expected return on assets	(311,494		)		(331,605		)
Amortization of prior service cost	—				297
Amortization of net loss	177,233				205,578
Settlement charges	17,591				—
Net pension costs		$205,210				$191,088

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components:

2019		Entergy Arkansas				Entergy Louisiana				Entergy  Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$5,260				$7,284				$1,629				$568				$1,350				$1,549
Interest cost on projected benefit obligation		14,175				15,882				4,068				1,873				3,613				3,364
Expected return on assets		(20,177		)		(22,651		)		(5,969		)		(2,696		)		(5,862		)		(4,678		)
Amortization of net loss		11,840				11,643				3,104				1,529				2,334				2,850
Net pension cost			$11,098				$12,158				$2,832				$1,274				$1,435				$3,085

2018		Entergy Arkansas				Entergy Louisiana				Entergy  Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$6,189				$8,446				$1,822				$673				$1,589				$1,776
Interest cost on projected benefit obligation		13,004				14,940				3,769				1,813				3,348				3,227
Expected return on assets		(21,851		)		(24,809		)		(6,502		)		(2,993		)		(6,523		)		(4,991		)
Amortization of net loss		13,412				14,450				3,610				1,954				2,626				3,715
Net pension cost			$10,754				$13,027				$2,699				$1,447				$1,040				$3,727

The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components:

2019		Entergy Arkansas				Entergy Louisiana				Entergy  Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$15,782				$21,852				$4,887				$1,706				$4,050				$4,649
Interest cost on projected benefit obligation		42,525				47,646				12,204				5,621				10,837				10,091
Expected return on assets		(60,529		)		(67,955		)		(17,905		)		(8,089		)		(17,586		)		(14,032		)
Amortization of net loss		35,522				34,929				9,313				4,588				7,002				8,550
Net pension cost			$33,300				$36,472				$8,499				$3,826				$4,303				$9,258

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2018		Entergy Arkansas				Entergy Louisiana				Entergy  Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$18,567				$25,338				$5,466				$2,019				$4,767				$5,328
Interest cost on projected benefit obligation		39,012				44,820				11,307				5,439				10,044				9,681
Expected return on assets		(65,553		)		(74,427		)		(19,506		)		(8,979		)		(19,569		)		(14,973		)
Amortization of net loss		40,236				43,350				10,830				5,862				7,878				11,145
Net pension cost			$32,262				$39,081				$8,097				$4,341				$3,120				$11,181

Non-Qualified Net Pension Cost

Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
2019		$67				$38				$69				$5				$119
2018		$114				$42				$73				$20				$122

Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
2019		$211				$122				$257				$16				$365
2018		$369				$138				$230				$62				$529

Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.

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Notes to Financial Statements

Components of Net Other Postretirement Benefit Cost (Income)

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:

	2019				2018
	(In Thousands)
Service cost - benefits earned during the period		$4,675				$6,782
Interest cost on accumulated postretirement benefit obligation (APBO)	11,975				12,681
Expected return on assets	(9,562		)		(10,373		)
Amortization of prior service credit	(8,844		)		(9,251		)
Amortization of net loss	358				3,432
Net other postretirement benefit cost (income)		($1,398	)			$3,271

Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:

	2019				2018
	(In Thousands)
Service cost - benefits earned during the period		$14,025				$20,346
Interest cost on accumulated postretirement benefit obligation (APBO)	35,925				38,043
Expected return on assets	(28,686		)		(31,119		)
Amortization of prior service credit	(26,532		)		(27,753		)
Amortization of net loss	1,074				10,296
Net other postretirement benefit cost (income)		($4,194	)			$9,813

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components:

2019		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$591				$1,160				$262				$92				$236				$243
Interest cost on APBO		1,807				2,666				670				395				854				476
Expected return on assets		(3,991		)		—				(1,199		)		(1,237		)		(2,276		)		(697		)
Amortization of prior service credit		(1,238		)		(1,837		)		(439		)		(171		)		(561		)		(363		)
Amortization of net (gain) loss		144				(174		)		181				58				121				89
Net other postretirement benefit cost (income)			($2,687	)			$1,815				($525	)			($863	)			($1,626	)			($252	)

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2018		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$793				$1,556				$321				$129				$330				$306
Interest cost on APBO		1,997				2,789				683				417				939				500
Expected return on assets		(4,342		)		—				(1,303		)		(1,313		)		(2,446		)		(783		)
Amortization of prior service credit		(1,278		)		(1,934		)		(456		)		(186		)		(579		)		(378		)
Amortization of net loss		289				388				377				34				206				233
Net other postretirement benefit cost (income)			($2,541	)			$2,799				($378	)			($919	)			($1,550	)			($122	)

The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components:

2019		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$1,773				$3,480				$786				$276				$708				$729
Interest cost on APBO		5,421				7,998				2,010				1,185				2,562				1,428
Expected return on assets		(11,973		)		—				(3,597		)		(3,711		)		(6,828		)		(2,091		)
Amortization of prior service credit		(3,714		)		(5,511		)		(1,317		)		(513		)		(1,683		)		(1,089		)
Amortization of net (gain) loss		432				(522		)		543				174				363				267
Net other postretirement benefit cost (income)			($8,061	)			$5,445				($1,575	)			($2,589	)			($4,878	)			($756	)

2018		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Thousands)
Service cost - benefits earned during the period			$2,379				$4,668				$963				$387				$990				$918
Interest cost on APBO		5,991				8,367				2,049				1,251				2,817				1,500
Expected return on assets		(13,026		)		—				(3,909		)		(3,939		)		(7,338		)		(2,349		)
Amortization of prior service credit		(3,834		)		(5,802		)		(1,368		)		(558		)		(1,737		)		(1,134		)
Amortization of net loss		867				1,164				1,131				102				618				699
Net other postretirement benefit cost (income)			($7,623	)			$8,397				($1,134	)			($2,757	)			($4,650	)			($366	)

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Notes to Financial Statements

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018:

2019		Qualified Pension Costs				Other Postretirement Costs				Non-Qualified Pension Costs				Total
		(In Thousands)
Entergy
Amortization of prior service (cost) credit			$—				$5,375				($50	)			$5,325
Amortization of net gain (loss)		(20,686		)		308				(541		)		(20,919		)
Settlement loss		(16,257		)		—				(373		)		(16,630		)
			($36,943	)			$5,683				($964	)			($32,224	)
Entergy Louisiana
Amortization of prior service credit			$—				$1,837				$—				$1,837
Amortization of net gain (loss)		(699		)		174				(1		)		(526		)
			($699	)			$2,011				($1	)			$1,311

2018		Qualified Pension Costs				Other Postretirement Costs				Non-Qualified Pension Costs				Total
		(In Thousands)
Entergy
Amortization of prior service (cost) credit			($99	)			$5,595				($71	)			$5,425
Amortization of net loss		(21,958		)		(1,932		)		(850		)		(24,740		)
Settlement loss		—				—				(76		)		(76		)
			($22,057	)			$3,663				($997	)			($19,391	)
Entergy Louisiana
Amortization of prior service credit			$—				$1,934				$—				$1,934
Amortization of net loss		(867		)		(388		)		(2		)		(1,257		)
			($867	)			$1,546				($2	)			$677

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Notes to Financial Statements

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018:

2019		Qualified Pension Costs				Other Postretirement Costs				Non-Qualified Pension Costs				Total
		(In Thousands)
Entergy
Amortization of prior service (cost) credit			$—				$16,125				($148	)			$15,977
Amortization of net gain (loss)		(58,156		)		923				(1,655		)		(58,888		)
Settlement loss		(17,557		)		—				(1,128		)		(18,685		)
			($75,713	)			$17,048				($2,931	)			($61,596	)
Entergy Louisiana
Amortization of prior service credit			$—				$5,511				$—				$5,511
Amortization of net gain (loss)		(2,096		)		522				(4		)		(1,578		)
			($2,096	)			$6,033				($4	)			$3,933

2018		Qualified Pension Costs				Other Postretirement Costs				Non-Qualified Pension Costs				Total
		(In Thousands)
Entergy
Amortization of prior service (cost) credit			($297	)			$16,786				($211	)			$16,278
Amortization of net loss		(65,870		)		(5,801		)		(2,832		)		(74,503		)
Settlement loss		—				—				(2,098		)		(2,098		)
			($66,167	)			$10,985				($5,141	)			($60,323	)
Entergy Louisiana
Amortization of prior service credit			$—				$5,802				$—				$5,802
Amortization of net loss		(2,601		)		(1,164		)		(5		)		(3,770		)
			($2,601	)			$4,638				($5	)			$2,032

Employer Contributions

Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
	(In Thousands)
Expected 2019 pension contributions		$27,112				$26,451				$7,701				$1,800				$1,645				$8,285
Pension contributions made through September 2019		$18,222				$18,272				$5,186				$1,237				$1,192				$5,631
Remaining estimated pension contributions to be made in 2019		$8,890				$8,179				$2,515				$563				$453				$2,654

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Notes to Financial Statements

NOTE 7.  BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy Corporation

Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity.

Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:

		Utility				Entergy Wholesale Commodities				All Other				Eliminations				Entergy
		(In Thousands)
2019
Operating revenues			$2,840,222				$300,363				$9				($19	)			$3,140,575
Income taxes			$71,698				($30,855	)			($11,642	)			$—				$29,201
Consolidated net income (loss)			$581,964				($140,501	)			($40,105	)			($31,899	)			$369,459
2018
Operating revenues			$2,724,279				$380,080				$—				($40	)			$3,104,319
Income taxes			($137,035	)			($135,659	)			($10,312	)			$—				($283,006	)
Consolidated net income (loss)			$507,745				$105,571				($41,601	)			($31,897	)			$539,818

Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:

		Utility				Entergy Wholesale Commodities				All Other				Eliminations				Entergy
		(In Thousands)
2019
Operating revenues		$7,392,641				$1,023,757				$11					($42	)		$8,416,367
Income taxes		$81,283				$25,763					($33,616	)			$—			$73,430
Consolidated net income (loss)		$1,150,863					($68,804	)			($117,725	)			($95,695	)		$868,639
Total assets as of September 30, 2019		$48,348,371				$4,122,007				$501,983					($2,466,093	)		$50,506,268
2018
Operating revenues		$7,389,477				$1,107,606					$—				($113	)		$8,496,970
Income taxes			($325,134	)			($166,882	)			($27,921	)			$—				($519,937	)
Consolidated net income (loss)		$1,104,078				$31,456					($114,962	)			($95,695	)		$924,877
Total assets as of December 31, 2018		$44,777,167				$5,459,275				$733,366					($2,694,742	)		$48,275,066

The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.

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As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions.

Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:

	2019												2018
	Employee retention and severance expenses and other benefits-related costs				Contracted economic development costs				Total				Employee retention and severance expenses and other benefits-related costs				Contracted economic development costs				Total
	(In Millions)
Balance as of July 1,		$181				$14				$195				$143				$14				$157
Restructuring costs accrued	14				—				14				43				—				43
Cash paid out	86				—				86				—				—				—
Balance as of September 30,		$109				$14				$123				$186				$14				$200

In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions.

Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:

	2019												2018
	Employee retention and severance expenses and other benefits-related costs				Contracted economic development costs				Total				Employee retention and severance expenses and other benefits-related costs				Contracted economic development costs				Total
	(In Millions)
Balance as of January 1,		$179				$14				$193				$83				$14				$97
Restructuring costs accrued	70				—				70				103				—				103
Cash paid out	140				—				140				—				—				—
Balance as of September 30,		$109				$14				$123				$186				$14				$200

In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions.

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Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022.

Registrant Subsidiaries

Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

NOTE 8.  RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers.

As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow.

Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.

Derivatives

Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions

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while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments.

Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh.

Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral.

Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.   

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

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During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018.

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The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument		Balance Sheet Location		Fair Value (a)		Offset (b)		Net (c) (d)		Business
				(In Millions)
Derivatives designated as hedging instruments
Assets:
Electricity swaps and options		Prepayments and other (current portion)		$35		($5)		$30		Entergy Wholesale Commodities
Electricity swaps and options		Other deferred debits and other assets (non-current portion)		$14		($2)		$12		Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options		Other current liabilities (current portion)		$5		($5)		$—		Entergy Wholesale Commodities
Electricity swaps and options		Other non-current liabilities (non-current portion)		$2		($2)		$—		Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Electricity swaps and options		Prepayments and other (current portion)		$9		($3)		$6		Entergy Wholesale Commodities
Natural gas swaps and options		Other deferred debits and other assets (non-current portion)		$1		$—		$1		Utility
Financial transmission rights		Prepayments and other		$17		($1)		$16		Utility and Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options		Other current liabilities (current portion)		$4		($4)		$—		Entergy Wholesale Commodities
Natural gas swaps and options		Other current liabilities (current portion)		$4		$—		$4		Utility
Natural gas swaps and options		Other non-current liabilities (non-current portion)		$1		$—		$1		Utility

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The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument		Balance Sheet Location		Fair Value (a)		Offset (b)		Net (c) (d)		Business
				(In Millions)
Derivatives designated as hedging instruments
Assets:
Electricity swaps and options		Prepayments and other (current portion)		$32		($32)		$—		Entergy Wholesale Commodities
Electricity swaps and options		Other deferred debits and other assets (non-current portion)		$7		($7)		$—		Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options		Other current liabilities (current portion)		$54		($33)		$21		Entergy Wholesale Commodities
Electricity swaps and options		Other non-current liabilities (non-current portion)		$20		($7)		$13		Entergy Wholesale Commodities
Derivatives not designated as hedging instruments
Assets:
Electricity swaps and options		Prepayments and other (current portion)		$4		($2)		$2		Entergy Wholesale Commodities
Electricity swaps and options		Other deferred debits and other assets (non-current portion)		$1		$—		$1		Entergy Wholesale Commodities
Natural gas swaps and options		Other deferred debits and other assets (non-current portion)		$2		$—		$2		Utility
Financial transmission rights		Prepayments and other		$16		($1)		$15		Utility and Entergy Wholesale Commodities
Liabilities:
Electricity swaps and options		Other current liabilities (current portion)		$1		($1)		$—		Entergy Wholesale Commodities
Natural gas swaps and options		Other current liabilities		$1		$—		$1		Utility

(a)	Represents the gross amounts of recognized assets/liabilities

(b)	Represents the netting of fair value balances with the same counterparty

(c)	Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)	Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018.

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The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows:

Instrument		Amount of gain (loss) recognized in other comprehensive income		Income Statement location		Amount of gain reclassified from accumulated other comprehensive income into income (a)
		(In Millions)				(In Millions)
2019
Electricity swaps and options		($7)		Competitive businesses operating revenues		$19
2018
Electricity swaps and options		($51)		Competitive businesses operating revenues		($11)

(a)	Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively

The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows:

Instrument		Amount of gain recognized in other comprehensive income		Income Statement location		Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)
		(In Millions)				(In Millions)
2019
Electricity swaps and options		$145		Competitive businesses operating revenues		$76
2018
Electricity swaps and options		($40)		Competitive businesses operating revenues		($38)

    

(a)	Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively

Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million.

Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to

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operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.    

Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings.

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows:

Instrument		Amount of gain (loss) recognized in accumulated other comprehensive income		Income Statement location		Amount of gain (loss) recorded in the income statement
		(In Millions)				(In Millions)
2019
Natural gas swaps		$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	($2)
Financial transmission rights		$—		Purchased power expense	(b)	$25
Electricity swaps and options		$—	(c)	Competitive business operating revenues		$1
2018
Natural gas swaps		$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	$—
Financial transmission rights		$—		Purchased power expense	(b)	$31
Electricity swaps and options		$—	(c)	Competitive business operating revenues		($2)

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The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows:

Instrument		Amount of gain (loss) recognized in accumulated other comprehensive income		Income Statement location		Amount of gain (loss) recorded in the income statement
		(In Millions)				(In Millions)
2019
Natural gas swaps and options		$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	($9)
Financial transmission rights		$—		Purchased power expense	(b)	$78
Electricity swaps and options		$—	(c)	Competitive business operating revenues		$4
2018
Natural gas swaps		$—		Fuel, fuel-related expenses, and gas purchased for resale	(a)	$5
Financial transmission rights		$—		Purchased power expense	(b)	$104
Electricity swaps and options		$—	(c)	Competitive business operating revenues		$—

(a)

Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)

Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)	Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.

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The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging.

Instrument		Balance Sheet Location		Fair Value (a)		Offset (b)		Net (c) (d)		Registrant
				(In Millions)
Assets:
Natural gas swaps and options		Prepayments and other		$0.1		$—		$0.1		Entergy Louisiana
Natural gas swaps and options		Other deferred debits and other assets (non-current portion)		$1.0		$—		$1.0		Entergy Louisiana
Financial transmission rights		Prepayments and other		$4.0		($0.1)		$3.9		Entergy Arkansas
Financial transmission rights		Prepayments and other		$9.1		$—		$9.1		Entergy Louisiana
Financial transmission rights		Prepayments and other		$1.5		$—		$1.5		Entergy Mississippi
Financial transmission rights		Prepayments and other		$0.7		$—		$0.7		Entergy New Orleans
Financial transmission rights		Prepayments and other		$1.7		($0.4)		$1.3		Entergy Texas
Liabilities:
Natural gas swaps and options		Other current liabilities		$2.2		$—		$2.2		Entergy Louisiana
Natural gas swaps and options		Other non-current liabilities		$1.4		$—		$1.4		Entergy Louisiana
Natural gas swaps		Other current liabilities		$1.1		$—		$1.1		Entergy Mississippi
Natural gas swaps		Other current liabilities		$0.1		$—		$0.1		Entergy New Orleans

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The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows:

Instrument		Balance Sheet Location		Fair Value (a)		Offset (b)		Net (c) (d)		Registrant
				(In Millions)
Assets:
Natural gas swaps and options		Prepayments and other		$0.3		$—		$0.3		Entergy Louisiana
Natural gas swaps and options		Other deferred debits and other assets		$1.6		$—		$1.6		Entergy Louisiana
Financial transmission rights		Prepayments and other		$3.6		($0.2)		$3.4		Entergy Arkansas
Financial transmission rights		Prepayments and other		$8.4		($0.1)		$8.3		Entergy Louisiana
Financial transmission rights		Prepayments and other		$2.2		$—		$2.2		Entergy Mississippi
Financial transmission rights		Prepayments and other		$1.3		$—		$1.3		Entergy New Orleans
Liabilities:
Financial transmission rights		Other current liabilities		$0.9		($1.4)		($0.5)		Entergy Texas
Natural gas swaps and options		Other current liabilities		$1.1		$—		$1.1		Entergy Louisiana
Natural gas swaps		Other current liabilities		$0.1		$—		$0.1		Entergy New Orleans

(a)	Represents the gross amounts of recognized assets/liabilities

(b)	Represents the netting of fair value balances with the same counterparty

(c)	Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

(d)	As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas.

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The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows:

Instrument		Income Statement Location		Amount of gain (loss) recorded in the income statement		Registrant
				(In Millions)
2019
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		($1.7)	(a)	Entergy Louisiana
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		($0.3)	(a)	Entergy Mississippi
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		($0.1)	(a)	Entergy New Orleans
Financial transmission rights		Purchased power expense		$3.5	(b)	Entergy Arkansas
Financial transmission rights		Purchased power expense		$14.4	(b)	Entergy Louisiana
Financial transmission rights		Purchased power expense		$1.9	(b)	Entergy Mississippi
Financial transmission rights		Purchased power expense		($0.3)	(b)	Entergy New Orleans
Financial transmission rights		Purchased power expense		$5.5	(b)	Entergy Texas
2018
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		($0.7)	(a)	Entergy Louisiana
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		$0.1	(a)	Entergy Mississippi
Financial transmission rights		Purchased power expense		$10.1	(b)	Entergy Arkansas
Financial transmission rights		Purchased power expense		$13.8	(b)	Entergy Louisiana
Financial transmission rights		Purchased power expense		$5.4	(b)	Entergy Mississippi
Financial transmission rights		Purchased power expense		$2.0	(b)	Entergy New Orleans
Financial transmission rights		Purchased power expense		($0.4)	(b)	Entergy Texas

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The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows:

Instrument		Income Statement Location		Amount of gain (loss) recorded in the income statement		Registrant
				(In Millions)
2019
Natural gas swaps and options		Fuel, fuel-related expenses, and gas purchased for resale		($3.6)	(a)	Entergy Louisiana
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		($5.5)	(a)	Entergy Mississippi
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		$0.1	(a)	Entergy New Orleans
Financial transmission rights		Purchased power expense		$15.4	(b)	Entergy Arkansas
Financial transmission rights		Purchased power expense		$40.9	(b)	Entergy Louisiana
Financial transmission rights		Purchased power expense		$5.3	(b)	Entergy Mississippi
Financial transmission rights		Purchased power expense		$2.2	(b)	Entergy New Orleans
Financial transmission rights		Purchased power expense		$13.6	(b)	Entergy Texas
2018
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		$4.2	(a)	Entergy Louisiana
Natural gas swaps		Fuel, fuel-related expenses, and gas purchased for resale		$0.9	(a)	Entergy Mississippi
Financial transmission rights		Purchased power expense		$20.1	(b)	Entergy Arkansas
Financial transmission rights		Purchased power expense		$57.2	(b)	Entergy Louisiana
Financial transmission rights		Purchased power expense		$23.0	(b)	Entergy Mississippi
Financial transmission rights		Purchased power expense		$10.5	(b)	Entergy New Orleans
Financial transmission rights		Purchased power expense		($5.6)	(b)	Entergy Texas

(a)

Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)

Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy

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Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.  

The three levels of the fair value hierarchy are:

•

Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–	quoted prices for similar assets or liabilities in active markets;

–	quoted prices for identical assets or liabilities in inactive markets;

–	inputs other than quoted prices that are observable for the asset or liability; or

–	inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•

Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations

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in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer.

The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms.

The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.  

On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer.

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The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$885				$—				$—				$885
Decommissioning trust funds (a):
Equity securities		836				—				—				836
Debt securities		1,214				1,754				—				2,968
Common trusts (b)														2,325
Power contracts		—				—				48				48
Securitization recovery trust account		55				—				—				55
Escrow accounts		410				—				—				410
Gas hedge contracts		—				1				—				1
Financial transmission rights		—				—				16				16
			$3,400				$1,755				$64				$7,544
Liabilities:
Gas hedge contracts			$4				$1				$—				$5

2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$424				$—				$—				$424
Decommissioning trust funds (a):
Equity securities		1,686				—				—				1,686
Debt securities		1,259				1,625				—				2,884
Common trusts (b)														2,350
Power contracts		—				—				3				3
Securitization recovery trust account		51				—				—				51
Escrow accounts		403				—				—				403
Gas hedge contracts		—				2				—				2
Financial transmission rights		—				—				15				15
			$3,823				$1,627				$18				$7,818
Liabilities:
Power contracts			$—				$—				$34				$34
Gas hedge contracts		1				—				—				1
			$1				$—				$34				$35

(a)	The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)	Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:

	2019								2018
	Power Contracts				Financial transmission rights				Power Contracts				Financial transmission rights
	(In Millions)
Balance as of July 1,		$72				$29				($25	)			$41
Total gains (losses) for the period (a)
Included in earnings	1				—				(4		)		—
Included in other comprehensive income	(7		)		—				(51		)		—
Included as a regulatory liability/asset	—				12				—				19
Settlements	(18		)		(25		)		13				(31		)
Balance as of September 30,		$48				$16				($67	)			$29

(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:

	2019								2018
	Power Contracts				Financial transmission rights				Power Contracts				Financial transmission rights
	(In Millions)
Balance as of January 1,		($31	)			$15				($65	)			$21
Total gains (losses) for the period (a)
Included in earnings	4				—				(5		)		(1		)
Included in other comprehensive income	145				—				(40		)		—
Included as a regulatory liability/asset	—				44				—				67
Issuances of financial transmission rights	—				35				—				46
Settlements	(70		)		(78		)		43				(104		)
Balance as of September 30,		$48				$16				($67	)			$29

(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018.

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The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019:

Transaction Type		Fair Value		Significant Unobservable Inputs		Range from Average %			Effect on Fair Value
		(In Millions)							(In Millions)
Power contracts - electricity swaps		$48		Unit contingent discount		+/-	4% - 4.75%		$4 - $5

The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:

Significant Unobservable Input		Transaction Type		Position		Change to Input		Effect on Fair Value
Unit contingent discount		Electricity swaps		Sell		Increase (Decrease)		Decrease (Increase)

The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels.

Entergy Arkansas

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$76.7				$—				$—				$76.7
Decommissioning trust funds (a):
Equity securities		6.2				—				—				6.2
Debt securities		101.4				306.3				—				407.7
Common trusts (b)														631.9
Securitization recovery trust account		7.9				—				—				7.9
Financial transmission rights		—				—				3.9				3.9
			$192.2				$306.3				$3.9				$1,134.3

2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Decommissioning trust funds (a):
Equity securities			$4.0				$—				$—				$4.0
Debt securities		94.8				286.5				—				381.3
Common trusts (b)														526.7
Securitization recovery trust account		4.7				—				—				4.7
Financial transmission rights		—				—				3.4				3.4
			$103.5				$286.5				$3.4				$920.1

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Entergy Louisiana

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$127.8				$—				$—				$127.8
Decommissioning trust funds (a):
Equity securities		5.3				—				—				5.3
Debt securities		183.7				409.7				—				593.4
Common trusts (b)														886.9
Escrow accounts		294.5				—				—				294.5
Securitization recovery trust account		10.1				—				—				10.1
Gas hedge contracts		0.1				1.0				—				1.1
Financial transmission rights		—				—				9.1				9.1
			$621.5				$410.7				$9.1				$1,928.2
Liabilities:
Gas hedge contracts			$2.2				$1.4				$—				$3.6

2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$43.1				$—				$—				$43.1
Decommissioning trust funds (a):
Equity securities		13.3				—				—				13.3
Debt securities		162.0				370.9				—				532.9
Common trusts (b)														738.8
Escrow accounts		289.5				—				—				289.5
Securitization recovery trust account		3.6				—				—				3.6
Gas hedge contracts		—				1.9				—				1.9
Financial transmission rights		—				—				8.3				8.3
			$511.5				$372.8				$8.3				$1,631.4
Liabilities:
Gas hedge contracts			$0.7				$0.4				$—				$1.1

Entergy Mississippi

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$98.9				$—				$—				$98.9
Escrow accounts		33.0				—				—				33.0
Financial transmission rights		—				—				1.5				1.5
			$131.9				$—				$1.5				$133.4
Liabilities:
Gas hedge contracts			$1.1				$—				$—				$1.1

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2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$36.9				$—				$—				$36.9
Escrow accounts		32.4				—				—				32.4
Financial transmission rights		—				—				2.2				2.2
			$69.3				$—				$2.2				$71.5

Entergy New Orleans

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Securitization recovery trust account			$5.3				$—				$—				$5.3
Escrow accounts		82.2				—				—				82.2
Financial transmission rights		—				—				0.7				0.7
			$87.5				$—				$0.7				$88.2
Liabilities:
Gas hedge contracts			$0.1				$—				$—				$0.1

2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$19.7				$—				$—				$19.7
Securitization recovery trust account		2.2				—				—				2.2
Escrow accounts		80.9				—				—				80.9
Financial transmission rights		—				—				1.3				1.3
			$102.8				$—				$1.3				$104.1
Liabilities:
Gas hedge contracts			$0.1				$—				$—				$0.1

Entergy Texas

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$92.3				$—				$—				$92.3
Securitization recovery trust account		31.6				—				—				31.6
Financial transmission rights		—				—				1.3				1.3
			$123.9				$—				$1.3				$125.2

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2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Securitization recovery trust account			$40.2				$—				$—				$40.2
Liabilities:
Financial transmission rights			$—				$—				$0.5				$0.5

System Energy

2019		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$164.2				$—				$—				$164.2
Decommissioning trust funds (a):
Equity securities		5.8				—				—				5.8
Debt securities		206.0				189.3				—				395.3
Common trusts (b)														601.2
			$376.0				$189.3				$—				$1,166.5

2018		Level 1				Level 2				Level 3				Total
		(In Millions)
Assets:
Temporary cash investments			$95.6				$—				$—				$95.6
Decommissioning trust funds (a):
Equity securities		4.4				—				—				4.4
Debt securities		224.5				139.7				—				364.2
Common trusts (b)														500.9
			$324.5				$139.7				$—				$965.1

(a)	The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)	Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Millions)
Balance as of July 1,		$8.2				$15.6				$2.8				$2.0				$0.6
Gains (losses) included as a regulatory liability/asset	(0.8		)		7.9				0.6				(1.6		)		6.2
Settlements	(3.5		)		(14.4		)		(1.9		)		0.3				(5.5		)
Balance as of September 30,		$3.9				$9.1				$1.5				$0.7				$1.3

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Millions)
Balance as of July 1,		$10.5				$18.2				$4.4				$3.0				$4.7
Gains (losses) included as a regulatory liability/asset	10.9				7.6				4.7				1.1				(5.0		)
Settlements	(10.1		)		(13.8		)		(5.4		)		(2.0		)		0.4
Balance as of September 30,		$11.3				$12.0				$3.7				$2.1				$0.1

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Millions)
Balance as of January 1,		$3.4				$8.3				$2.2				$1.3				($0.5	)
Issuances of financial transmission rights	9.6				18.7				3.9				2.7				0.1
Gains (losses) included as a regulatory liability/asset	6.3				23.0				0.6				(1.1		)		15.3
Settlements	(15.4		)		(40.9		)		(5.2		)		(2.2		)		(13.6		)
Balance as of September 30,		$3.9				$9.1				$1.5				$0.7				$1.3

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The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Millions)
Balance as of January 1,		$3.0				$10.2				$2.1				$2.2				$3.4
Issuances of financial transmission rights	11.8				20.0				4.5				3.7				6.1
Gains (losses) included as a regulatory liability/asset	16.6				39.0				20.1				6.7				(15.0		)
Settlements	(20.1		)		(57.2		)		(23.0		)		(10.5		)		5.6
Balance as of September 30,		$11.3				$12.0				$3.7				$2.1				$0.1

NOTE 9.  DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

As discussed in Note 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million.

As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 million.

Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for Indian Point 1, Indian Point 2, Indian Point 3, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 million, respectively. The equity securities

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are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:

		Fair Value				Total Unrealized Gains				Total Unrealized Losses
		(In Millions)
2019
Debt Securities (a)			$2,462				$114				$2
2018
Debt Securities (a)			$2,495				$19				$35

(a)	Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale.

The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.15%, an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:

		Fair Value				Gross Unrealized Losses
		(In Millions)
Less than 12 months			$236				$2
More than 12 months		67				—
Total			$303				$2

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:

	Fair Value				Gross Unrealized Losses
	(In Millions)
Less than 12 months		$652				$9
More than 12 months	782				26
Total		$1,434				$35

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:

	2019				2018
	(In Millions)
Less than 1 year		$165				$199
1 year - 5 years	870				1,066
5 years - 10 years	636				544
10 years - 15 years	89				77
15 years - 20 years	98				78
20 years+	604				531
Total		$2,462				$2,495

During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $11 million and $4 million, respectively, and gross losses of $0.4 million and $15 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $20 million and $6 million, respectively, and gross losses of $3 million and $37 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings.

The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below.

Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:

		Fair Value				Total Unrealized Gains				Total Unrealized Losses
		(In Millions)
2019
Debt Securities			$407.7				$11.8				$0.9
2018
Debt Securities			$381.3				$0.6				$8.2

The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon

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rate of approximately 2.78%, an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:

		Fair Value				Gross Unrealized Losses
		(In Millions)
Less than 12 months			$51.5				$0.8
More than 12 months		21.0				0.1
Total			$72.5				$0.9

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:

	Fair Value				Gross Unrealized Losses
	(In Millions)
Less than 12 months		$65.8				$0.5
More than 12 months	231.1				7.7
Total		$296.9				$8.2

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:

	2019				2018
	(In Millions)
Less than 1 year		$50.3				$32.5
1 year - 5 years	120.4				170.3
5 years - 10 years	144.5				114.0
10 years - 15 years	24.3				10.3
15 years - 20 years	14.2				8.1
20 years+	54.0				46.1
Total		$407.7				$381.3

During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2 million and $0.01 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses.

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During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $2.1 million and $0.1 million, respectively, and gross losses of $0.1 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:

		Fair Value				Total Unrealized Gains				Total Unrealized Losses
		(In Millions)
2019
Debt Securities			$593.4				$32.6				$0.3
2018
Debt Securities			$532.9				$4.1				$6.0

The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018.  As of September 30, 2019, the available-for-sale debt securities have an average coupon rate of approximately 3.85%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:

		Fair Value				Gross Unrealized Losses
		(In Millions)
Less than 12 months			$49.3				$0.3
More than 12 months		12.9				—
Total			$62.2				$0.3

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The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:

	Fair Value				Gross Unrealized Losses
	(In Millions)
Less than 12 months		$170.1				$2.1
More than 12 months	145.8				3.9
Total		$315.9				$6.0

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:

	2019				2018
	(In Millions)
Less than 1 year		$56.6				$31.1
1 year - 5 years	138.2				130.5
5 years - 10 years	118.4				111.0
10 years - 15 years	34.7				29.0
15 years - 20 years	45.0				37.1
20 years+	200.5				194.2
Total		$593.4				$532.9

During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2.5 million and $1.9 million, respectively, and gross losses of $29 thousand and $3.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $4.2 million and $2.5 million, respectively, and gross losses of $0.2 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

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System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:

		Fair Value				Total Unrealized Gains				Total Unrealized Losses
		(In Millions)
2019
Debt Securities			$395.3				$19.7				$0.1
2018
Debt Securities			$364.2				$2.9				$5.8

The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.09%, an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years.

The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:

		Fair Value				Gross Unrealized Losses
	(In Millions)
Less than 12 months			$38.8				$0.1
More than 12 months		4.3				—
Total			$43.1				$0.1

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:

	Fair Value				Gross Unrealized Losses
	(In Millions)
Less than 12 months		$89.7				$2.4
More than 12 months	79.8				3.4
Total		$169.5				$5.8

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The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:

	2019				2018
	(In Millions)
Less than 1 year		$11.2				$22.8
1 year - 5 years	187.7				188.0
5 years - 10 years	92.7				73.4
10 years - 15 years	3.0				5.2
15 years - 20 years	5.9				10.2
20 years+	94.8				64.6
Total		$395.3				$364.2

During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $1.7 million and $6.5 thousand, respectively, and gross losses of $0.2 million and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $3.6 million and $0.3 million, respectively, and gross losses of $0.6 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings.

Other-than-temporary impairments and unrealized gains and losses

Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments. 

NOTE 10.  INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Tax Cuts and Jobs Act

During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders

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and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:

	Three Months Ended September 30,								Nine Months Ended September 30,
	2019				2018				2019				2018
	(In Millions)
Entergy		$96				$283				$219				$562
Entergy Arkansas		$41				$153				$99				$260
Entergy Louisiana		$17				$55				$31				$86
Entergy Mississippi		$—				$32				$—				$161
Entergy New Orleans		$7				$9				$9				$9
Entergy Texas		$31				$—				$73				$—
System Entergy		$—				$34				$7				$46

Other Tax Matters    

In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years.

In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance.

Vermont Yankee

The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.

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NOTE 11.  PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Construction Expenditures in Accounts Payable

Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.

NOTE 12.  VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.

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NOTE 13.  REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:

		2019				2018
		(In Thousands)
Utility:
Residential			$1,154,455				$1,138,744
Commercial		722,334				693,760
Industrial		686,122				682,823
Governmental		61,697				60,647
Total billed retail		2,624,608				2,575,974
Sales for resale (a)		63,082				76,247
Other electric revenues (b)		115,352				42,847
Non-customer revenues (c)		9,892				2,819
Total electric revenues		2,812,934				2,697,887
Natural gas		27,269				26,352
Entergy Wholesale Commodities:
Competitive businesses sales (a)		282,420				407,763
Non-customer revenues (c)		17,952				(27,683		)
Total competitive businesses		300,372				380,080
Total operating revenues			$3,140,575				$3,104,319

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Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:

		2019				2018
		(In Thousands)
Utility:
Residential			$2,727,367				$2,799,539
Commercial		1,871,416				1,871,380
Industrial		1,928,857				1,904,828
Governmental		172,280				173,949
Total billed retail		6,699,920				6,749,696
Sales for resale (a)		222,834				214,984
Other electric revenues (b)		326,771				289,668
Non-customer revenues (c)		30,158				22,026
Total electric revenues		7,279,683				7,276,374
Natural gas		112,916				112,990
Entergy Wholesale Commodities:
Competitive businesses sales (a)		923,288				1,148,460
Non-customer revenues (c)		100,480				(40,854		)
Total competitive businesses		1,023,768				1,107,606
Total operating revenues			$8,416,367				$8,496,970

The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows:

2019		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Residential			$253,627				$426,012				$177,785				$81,468				$215,563
Commercial		162,564				277,071				131,596				56,430				94,673
Industrial		156,024				376,595				44,054				8,613				100,836
Governmental		5,907				18,731				12,551				19,030				5,478
Total billed retail		578,122				1,098,409				365,986				165,541				416,550
Sales for resale (a)		58,953				81,664				9,569				6,876				16,704
Other electric revenues (b)		47,085				37,521				20,499				2,537				9,177
Non-customer revenues (c)		3,366				4,280				2,678				1,784				446
Total electric revenues		687,526				1,221,874				398,732				176,738				442,877
Natural gas		—				9,803				—				17,466				—
Total operating revenues			$687,526				$1,231,677				$398,732				$194,204				$442,877

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2018		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Residential			$250,081				$408,680				$170,258				$86,014				$223,711
Commercial		119,950				272,985				126,987				62,428				111,409
Industrial		126,079				393,884				44,383				9,655				108,823
Governmental		4,445				17,566				11,488				20,364				6,785
Total billed retail		500,555				1,093,115				353,116				178,461				450,728
Sales for resale (a)		60,338				71,634				7,876				4,863				23,290
Other electric revenues (b)		4,446				34,220				4,079				(1,107		)		2,735
Non-customer revenues (c)		3,060				(2,691		)		2,663				1,947				478
Total electric revenues		568,399				1,196,278				367,734				184,164				477,231
Natural gas		—				10,334				—				16,018				—
Total operating revenues			$568,399				$1,206,612				$367,734				$200,182				$477,231

The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows:

2019		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Residential			$621,208				$980,443				$423,395				$192,165				$510,156
Commercial		412,697				715,983				331,785				156,152				254,799
Industrial		396,515				1,108,193				120,490				24,353				279,306
Governmental		15,776				53,547				33,108				53,916				15,933
Total billed retail		1,446,196				2,858,166				908,778				426,586				1,060,194
Sales for resale (a)		213,038				248,827				19,377				25,680				48,251
Other electric revenues (b)		107,599				130,269				47,887				8,093				37,329
Non-customer revenues (c)		9,434				15,564				7,671				4,414				1,157
Total electric revenues		1,776,267				3,252,826				983,713				464,773				1,146,931
Natural gas		—				44,498				—				68,418				—
Total operating revenues			$1,776,267				$3,297,324				$983,713				$533,191				$1,146,931

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2018		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Residential			$644,735				$972,113				$451,331				$208,821				$522,539
Commercial		334,325				719,652				354,799				171,224				291,380
Industrial		335,529				1,114,898				133,012				26,493				294,896
Governmental		12,859				51,581				33,788				56,503				19,218
Total billed retail		1,327,448				2,858,244				972,930				463,041				1,128,033
Sales for resale (a)		179,637				272,690				21,645				24,390				71,828
Other electric revenues (b)		98,571				124,749				35,055				7,404				28,468
Non-customer revenues (c)		8,372				7,390				7,536				4,749				1,328
Total electric revenues		1,614,028				3,263,073				1,037,166				499,584				1,229,657
Natural gas		—				45,671				—				67,319				—
Total operating revenues			$1,614,028				$3,308,744				$1,037,166				$566,903				$1,229,657

(a)

Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues.

(b)	Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)	Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

NOTE 14. ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion.

In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units.

In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.

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NOTE 15. LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)

Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows.

General

As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases.

Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

Entergy incurred the following total lease costs for the three months ended September 30, 2019:

		(In Thousands)
Operating lease cost			$16,086
Financing lease cost:
Amortization of right-of-use assets			$2,945
Interest on lease liabilities			$763

Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019.

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Entergy incurred the following total lease costs for the nine months ended September 30, 2019:

		(In Thousands)
Operating lease cost			$47,061
Financing lease cost:
Amortization of right-of-use assets			$10,837
Interest on lease liabilities			$2,597

Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.

The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities.

The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
Operating lease cost		$3,306				$3,003				$1,752				$349				$1,074
Financing lease cost:
Amortization of right-of-use assets		$621				$1,014				$369				$178				$335
Interest on lease liabilities		$105				$161				$65				$29				$54

Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019.

The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
Operating lease cost		$9,724				$8,854				$5,220				$1,058				$3,135
Financing lease cost:
Amortization of right-of-use assets		$2,448				$4,014				$1,408				$696				$965
Interest on lease liabilities		$408				$612				$241				$114				$153

Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.

The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities.

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Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
Operating leases		$49,503				$34,248				$18,149				$3,894				$13,074
Financing leases		$11,094				$16,795				$6,994				$2,913				$5,515

The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:

		(In Thousands)
Current liabilities:
Operating leases			$52,348
Financing leases			$11,482
Non-current liabilities:
Operating leases			$184,404
Financing leases			$53,252

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:

	Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases		$10,662				$9,969				$6,137				$1,138				$3,427
Financing leases		$2,600				$3,860				$1,473				$626				$1,252
Non-current liabilities:
Operating leases		$38,881				$24,289				$12,254				$2,755				$9,689
Financing leases		$8,665				$12,925				$5,521				$2,286				$4,221

The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019:

Weighted average remaining lease terms:
Operating leases		5.10
Financing leases		6.79
Weighted average discount rate:
Operating leases		3.91	%
Financing leases		4.67	%

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The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:

	Entergy Arkansas			Entergy Louisiana			Entergy Mississippi			Entergy New Orleans			Entergy Texas
Weighted average remaining lease terms:
Operating leases	6.09			4.28			4.65			3.99			4.49
Financing leases	5.44			5.41			5.41			5.72			5.25
Weighted average discount rate:
Operating leases	3.75	%		3.74	%		3.77	%		3.94	%		3.86	%
Financing leases	3.75	%		3.75	%		3.71	%		3.93	%		3.84	%

Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows:

Year		Operating Leases				Financing Leases
		(In Thousands)
Remainder for 2019			$16,088				$3,608
2020		59,965				13,521
2021		53,791				11,973
2022		45,391				10,775
2023		35,050				9,664
Years thereafter		56,906				26,889
Minimum lease payments		267,191				76,430
Less: amount representing interest		30,438				11,696
Present value of net minimum lease payments			$236,753				$64,734

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Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows:

Operating Leases

Year		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Remainder of 2019			$3,168				$2,863				$1,968				$332				$1,022
2020		11,756				10,518				6,066				1,196				4,014
2021		9,911				8,787				4,937				939				3,279
2022		7,613				6,068				3,503				659				2,338
2023		6,341				4,079				1,376				497				1,994
Years thereafter		16,421				4,702				2,642				729				2,193
Minimum lease payments		55,210				37,017				20,492				4,352				14,840
Less: amount representing interest		5,667				2,759				2,101				459				1,724
Present value of net minimum lease payments			$49,543				$34,258				$18,391				$3,893				$13,116

Financing Leases

Year		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
Remainder of 2019			$713				$1,135				$429				$204				$375
2020		2,654				4,191				1,655				660				1,364
2021		2,258				3,536				1,490				549				1,171
2022		1,969				3,096				1,297				499				965
2023		1,728				2,635				1,078				451				827
Years thereafter		2,905				3,818				1,740				881				1,316
Minimum lease payments		12,227				18,411				7,689				3,244				6,018
Less: amount representing interest		961				1,626				695				332				545
Present value of net minimum lease payments			$11,266				$16,785				$6,994				$2,912				$5,473

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases.

In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K.

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General

As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):

Year		Operating Leases				Capital Leases
		(In Thousands)
2019			$94,043				$2,887
2020		82,191				2,887
2021		75,147				2,887
2022		60,808				2,887
2023		47,391				2,887
Years thereafter		88,004				16,117
Minimum lease payments		447,584				30,552
Less:  Amount representing interest		—				8,555
Present value of net minimum lease payments			$447,584				$21,997

Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016.

As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere):

Operating Leases

Year		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas
		(In Thousands)
2019			$20,421				$25,970				$9,344				$2,493				$5,744
2020		13,918				21,681				8,763				2,349				4,431
2021		11,931				19,514				7,186				1,901				3,625
2022		9,458				15,756				5,675				1,314				2,218
2023		7,782				12,092				2,946				1,043				1,561
Years thereafter		23,297				22,003				4,417				2,323				2,726
Minimum lease payments			$86,807				$117,016				$38,331				$11,423				$20,305

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Rental Expenses

Year		Entergy Arkansas				Entergy Louisiana				Entergy Mississippi				Entergy New Orleans				Entergy Texas				System Energy
		(In Millions)
2018			$6.2				$20.2				$4.6				$2.5				$3.1				$1.9
2017			$7.5				$23.0				$5.6				$2.5				$3.4				$2.2
2016			$8.0				$17.8				$4.0				$0.9				$2.8				$1.6

In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016.

On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02.

Power Purchase Agreements

As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows:

Year		Entergy Texas (a)				Entergy
		(In Thousands)
2019			$31,159				$31,159
2020		31,876				31,876
2021		32,609				32,609
2022		10,180				10,180
Minimum lease payments			$105,824				$105,824

(a)	Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.

Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016.

Sales and Leaseback Transactions

Waterford 3 Lease Obligation

In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements.

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In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid.

In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017.

Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016.

As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt.

In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana.

Grand Gulf Lease Obligations

In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy.

System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017.

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Notes to Financial Statements

As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:

	Amount
	(In Thousands)
2019		$17,188
2020	17,188
2021	17,188
2022	17,188
2023	17,188
Years thereafter	223,437
Total	309,377
Less: Amount representing interest	275,025
Present value of net minimum lease payments		$34,352

NOTE 16.  DISPOSITIONS (Entergy Corporation)

Vermont Yankee

As discussed in Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy transferred 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC, the owner of the Vermont Yankee plant, to a subsidiary of NorthStar.

Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. Vermont Yankee Asset Retirement Management, LLC, a subsidiary of Entergy, assumed the obligations under the credit facility. At the closing of the transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to Vermont Yankee Asset Retirement Management. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility.

Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019.

Pilgrim

In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $191 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair

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value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets.

________________

In the opinion of the management of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, the accompanying unaudited financial statements contain all adjustments (consisting primarily of normal recurring accruals and reclassification of previously reported amounts to conform to current classifications) necessary for a fair statement of the results for the interim periods presented.  Entergy’s business is subject to seasonal fluctuations, however, with peak periods occurring typically during the first and third quarters.  The results for the interim periods presented should not be used as a basis for estimating results of operations for a full year.

Part I, Item 3. Quantitative and Qualitative Disclosures About Market Risk

See “Market and Credit Risk Sensitive Instruments” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis.

Part I, Item 4. Controls and Procedures

Disclosure Controls and Procedures

As of September 30, 2019, evaluations were performed under the supervision and with the participation of Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy (individually “Registrant” and collectively the “Registrants”) management, including their respective Principal Executive Officers (PEO) and Principal Financial Officers (PFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, each PEO and PFO has concluded that, as to the Registrant or Registrants for which they serve as PEO or PFO, the Registrant’s or Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission rules and forms; and that the Registrant’s or Registrants’ disclosure controls and procedures are also effective in reasonably assuring that such information is accumulated and communicated to the Registrant’s or Registrants’ management, including their respective PEOs and PFOs, as appropriate to allow timely decisions regarding required disclosure.

Changes in Internal Controls over Financial Reporting

Under the supervision and with the participation of each Registrants’ management, including its respective PEO and PFO, each Registrant evaluated changes in internal control over financial reporting that occurred during the quarter ended September 30, 2019 and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

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MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $20.8 million primarily due to higher retail electric price and higher volume/weather, partially offset by higher depreciation and amortization expenses and lower other income.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income decreased $8.6 million primarily due to higher depreciation and amortization expenses, higher interest expense, lower volume/weather, and higher other operation and maintenance expenses, partially offset by higher retail electric price.

Operating Revenues

Third Quarter 2019 Compared to Third Quarter 2018

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$568.4
Fuel, rider, and other revenues that do not significantly affect net income	(30.8		)
Return of unprotected excess accumulated deferred income taxes to customers	111.4
Retail electric price	22.9
Volume/weather	15.6
2019 operating revenues		$687.5

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a tax adjustment rider beginning in April 2018. In third quarter 2019, $41.4 million was returned to customers as compared to $152.8 million in third quarter 2018. There is no effect on net income as the reduction in operating revenues in each period was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

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Management's Financial Discussion and Analysis

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of January 2019, as approved by the APSC. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to an increase in usage during the unbilled sales period, partially offset by a decrease of 302 GWh, or 5%, in billed electricity usage, including a decrease in industrial usage primarily due to a decrease in small industrial sales.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$1,614.0
Fuel, rider, and other revenues that do not significantly affect net income	(29.8		)
Return of unprotected excess accumulated deferred income taxes to customers	161.7
Retail electric price	50.6
Volume/weather	(20.2		)
2019 operating revenues		$1,776.3

Entergy Arkansas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a tax adjustment rider beginning in April 2018. In the nine months ended September 30, 2019, $98.7 million was returned to customers as compared to $260.4 million in the nine months ended September 30, 2018. There is no effect on net income as the reduction in operating revenues in each period was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of January 2019, as approved by the APSC. See Note 2 to the financial statements in the Form 10-K for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to a decrease of 719 GWh, or 4%, in billed electricity usage, including the effect of less favorable weather on residential and commercial sales and a decrease in industrial usage. The decrease in industrial usage is primarily due to a decrease in small industrial sales.

Other Income Statement Variances

Third Quarter 2019 Compared to Third Quarter 2018

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income decreased primarily due to changes in decommissioning trust fund investment activity.

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Interest expense increased primarily due to the issuance of $350 million of 4.20% Series mortgage bonds in March 2019.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Nuclear refueling outage expenses decreased primarily due to the amortization of lower costs associated with the most recent outages as compared to previous outages.

Other operation and maintenance expenses increased primarily due to:

•	an increase of $5.9 million due to spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $5.7 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance;

•	an increase of $3.8 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services;

•	an increase of $3.3 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2019 as compared to the same period in 2018; and

•	lower nuclear insurance refunds of $3 million.

The increase was offset by a decrease of $12 million in nuclear generation expenses primarily due to a lower scope of work performed in 2019 as compared to the same period in 2018 and a decrease of $5.9 million in energy efficiency costs due to the timing of recovery from customers.

Depreciation and amortization expenses increased primarily due to additions to plant in service.

Other income decreased primarily due to changes in decommissioning trust fund investment activity.

Interest expense increased primarily due to the issuance of $350 million of 4.20% Series mortgage bonds in March 2019 and the issuance of $250 million of 4.00% Series mortgage bonds in May 2018.

Income Taxes

The effective income tax rates were 4.5% for the third quarter 2019 and (13.1%) for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (631.3%) for the third quarter 2018. The difference in the effective income tax rate for the third quarter 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes and the provision for uncertain tax positions. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (286.4%) for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and certain book and tax differences related to utility plant items, partially offset by state income taxes. See Note 10 to the financial statements herein and

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Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$119				$6,216
Cash flow provided by (used in):
Operating activities	576,612				362,585
Investing activities	(506,676		)		(574,337		)
Financing activities	7,014				427,318
Net increase in cash and cash equivalents	76,950				215,566
Cash and cash equivalents at end of period		$77,069				$221,782

Operating Activities

Net cash flow provided by operating activities increased $214 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a decrease in the return of unprotected excess accumulated deferred income taxes to customers in 2019 as compared to the same period in 2018. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act;

•	a decrease of $33.9 million in spending on nuclear refueling outages in 2019;

•	a decrease of $33.8 million in pension contributions in 2019. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding; and

•	the timing of recovery of fuel and purchased power costs.

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Investing Activities

Net cash flow used in investing activities decreased $67.7 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a decrease of $43.3 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash payments during the nuclear fuel cycle;

•	a decrease of $42.6 million in nuclear construction expenditures primarily as a result of work performed in 2018 on various ANO 1 and 2 outage projects;

•	a decrease of $17.8 million in fossil-fueled generation construction expenditures due to a decrease in spending on various fossil-fueled generation projects in 2019 as compared to the same period in 2018;

•	a decrease of $10.8 million in transmission construction expenditures due to a lower scope of work performed in 2019 on various projects; and

•	a decrease of $11.7 million in information technology capital expenditures primarily due to lower spending in 2019 on critical infrastructure protection.

The decrease was partially offset by an increase of $39.3 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Arkansas’s distribution system, including increased spending on advanced metering infrastructure, and an increase of $13.3 million in storm spending.

Financing Activities

Net cash flow provided by financing activities decreased $420.3 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a $350 million capital contribution from Entergy Corporation in 2018 in anticipation of the return of unprotected excess accumulated deferred income taxes to customers and upcoming planned capital investments;

•	the issuance of $250 million of 4.00% Series mortgage bonds in May 2018;

•	a common equity distribution of $115 million in 2019 in order to maintain the targeted capital structure;

•	net repayments of long-term borrowings of $29.3 million in 2019 compared to net long-term borrowings of $45.5 million in 2018 on the Entergy Arkansas nuclear fuel company variable interest entity credit facility; and

•	money pool activity.

The decrease was partially offset by the issuance of $350 million of 4.20% Series mortgage bonds in March 2019 and net repayments of short-term borrowings of $50 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2018.

Decreases in Entergy Arkansas’s payable to the money pool are a use of cash flow, and Entergy Arkansas’s payable to the money pool decreased by $182.7 million in 2019 compared to decreasing by $166.1 million in 2018. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

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Capital Structure

Entergy Arkansas’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio is primarily due to the issuance of $350 million of mortgage bonds in March 2019.

	September 30, 2019			December 31, 2018
Debt to capital	53.3	%		52.0	%
Effect of excluding the securitization bonds	(0.1	%)		(0.2	%)
Debt to capital, excluding securitization bonds (a)	53.2	%		51.8	%
Effect of subtracting cash	(0.5	%)		—	%
Net debt to net capital, excluding securitization bonds (a)	52.7	%		51.8	%

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Arkansas.

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, financing lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Arkansas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition because the securitization bonds are non-recourse to Entergy Arkansas, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy Arkansas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Arkansas’s financial condition because net debt indicates Entergy Arkansas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Arkansas’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Arkansas is developing its capital investment plan for 2020 through 2022 and currently anticipates making $2.5 billion in capital investments during that period. The preliminary estimate includes specific investments such as transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in ANO 1 and 2; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Arkansas’s receivables from or (payables to) the money pool were as follows:

September 30,  2019		December 31, 2018		September 30,  2018		December 31, 2017
(In Thousands)
$6,896		($182,738)		$13,421		($166,137)

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

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Entergy Arkansas has a credit facility in the amount of $150 million scheduled to expire in September 2024. Entergy Arkansas also has a $20 million credit facility scheduled to expire in April 2020. The $150 million credit facility includes fronting commitments for the issuance of letters of credit against $5 million of the borrowing capacity of the facility. As of September 30, 2019, no cash borrowings and no letters of credit were outstanding under the credit facilities. In addition, Entergy Arkansas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of September 30, 2019, a $1 million letter of credit was outstanding under Entergy Arkansas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Arkansas nuclear fuel company variable interest entity has a credit facility in the amount of $80 million scheduled to expire in September 2021.  As of September 30, 2019, $30.3 million in loans were outstanding under the credit facility for the Entergy Arkansas nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facility.

Searcy Solar Facility

In March 2019, Entergy Arkansas announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar energy facility that will be sited on approximately 800 acres in White County near Searcy, Arkansas.  The purchase is contingent upon, among other things, obtaining necessary approvals from applicable federal and state regulatory and permitting agencies.  The project will be constructed by a subsidiary of NextEra Energy Resources.  Entergy Arkansas will purchase the facility upon completion and after the other purchase contingencies have been met.  Closing is expected to occur by the end of 2021. In May 2019, Entergy Arkansas filed a petition with the APSC seeking a finding that the transaction is in the public interest and requesting all necessary approvals. In September 2019 other parties filed testimony largely supporting the resource acquisition but disputing Entergy Arkansas’s proposed method of cost recovery. Entergy Arkansas filed its rebuttal testimony in October 2019. A hearing is scheduled in January 2020.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery.  The following are updates to that discussion.

Retail Rates

2019 Formula Rate Plan Filing

In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.   In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the

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proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset.

Production Cost Allocation Rider

In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020.

Energy Cost Recovery Rider

In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding.

Opportunity Sales Proceeding

As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action.

In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint.

In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring

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30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding.

Net Metering Legislation

An Arkansas law was enacted effective July 2019 that, among other things, expands the definition of a “net metering customer” to include two additional types of customers: (1) customers that lease net metering facilities, subject to certain leasing arrangements, and (2) government entities or other entities exempt from state and federal income taxes that enter into a service contract for a net metering facility. The latter provision would allow eligible entities, many of whom are small and large general service customers, to purchase renewable energy directly from third party providers and receive bill credits for these purchases. The APSC was given authority under this law to address certain matters, such as cost shifting and the appropriate compensation for net metered energy, and has initiated proceedings for this purpose. Because of the size and number of customers eligible under this new law, there is a risk of loss of load and the shifting of significant costs from eligible entities to other customers.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Arkansas’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies. The following is an update to that discussion.

In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$687,526				$568,399				$1,776,267				$1,614,028
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		109,779				164,438				370,534				379,240
Purchased power		61,074				58,213				156,417				195,024
Nuclear refueling outage expenses		17,381				19,062				51,823				61,623
Other operation and maintenance		188,299				188,882				542,765				536,032
Decommissioning		17,422				15,226				50,351				44,971
Taxes other than income taxes		31,783				27,972				87,327				80,322
Depreciation and amortization		78,594				73,579				231,502				218,261
Other regulatory charges (credits) - net		1,018				(13,758		)		(8,873		)		(29,378		)
TOTAL		505,350				533,614				1,481,846				1,486,095
OPERATING INCOME		182,176				34,785				294,421				127,933
OTHER INCOME
Allowance for equity funds used during construction		3,977				3,735				10,777				12,214
Interest and investment income		8,788				12,060				19,193				21,352
Miscellaneous - net		(4,286		)		(3,063		)		(12,704		)		(10,815		)
TOTAL		8,479				12,732				17,266				22,751
INTEREST EXPENSE
Interest expense		35,454				31,632				104,664				92,315
Allowance for borrowed funds used during construction		(1,641		)		(1,739		)		(4,384		)		(5,737		)
TOTAL		33,813				29,893				100,280				86,578
INCOME BEFORE INCOME TAXES		156,842				17,624				211,407				64,106
Income taxes		7,126				(111,266		)		(27,729		)		(183,595		)
NET INCOME		149,716				128,890				239,136				247,701
Preferred dividend requirements		—				357				—				1,071
EARNINGS APPLICABLE TO COMMON EQUITY			$149,716				$128,533				$239,136				$246,630
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$239,136				$247,701
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		351,390				335,939
Deferred income taxes, investment tax credits, and non-current taxes accrued		85,246				28,463
Changes in assets and liabilities:
Receivables		(70,395		)		(33,422		)
Fuel inventory		(5,350		)		7,523
Accounts payable		(24,766		)		(20,904		)
Taxes accrued		(18,608		)		30,686
Interest accrued		20,206				13,558
Deferred fuel costs		52,468				24,463
Other working capital accounts		44,803				(8,827		)
Provisions for estimated losses		8,841				10,013
Other regulatory assets		(55,749		)		22,574
Other regulatory liabilities		32,537				(218,518		)
Pension and other postretirement liabilities		(26,136		)		(64,461		)
Other assets and liabilities		(57,011		)		(12,203		)
Net cash flow provided by operating activities		576,612				362,585
INVESTING ACTIVITIES
Construction expenditures		(488,487		)		(517,882		)
Allowance for equity funds used during construction		11,016				12,572
Nuclear fuel purchases		(26,732		)		(79,142		)
Proceeds from sale of nuclear fuel		22,834				31,897
Proceeds from nuclear decommissioning trust fund sales		199,031				259,331
Investment in nuclear decommissioning trust funds		(214,205		)		(269,913		)
Change in money pool receivable - net		(6,896		)		(13,421		)
Changes in securitization account		(3,238		)		(4,821		)
Insurance proceeds		—				7,043
Change in other investments		1				(1		)
Net cash flow used in investing activities		(506,676		)		(574,337		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		781,510				658,427
Retirement of long-term debt		(473,827		)		(372,447		)
Capital contribution from parent		—				350,000
Changes in short-term borrowings - net		—				(49,974		)
Changes in money pool payable - net		(182,738		)		(166,137		)
Distributions/dividends paid:
Common equity		(115,000		)		—
Preferred stock		—				(1,071		)
Other		(2,931		)		8,520
Net cash flow provided by financing activities		7,014				427,318
Net increase in cash and cash equivalents		76,950				215,566
Cash and cash equivalents at beginning of period		119				6,216
Cash and cash equivalents at end of period			$77,069				$221,782
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized			$80,644				$74,966
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$410				$118
Temporary cash investments		76,659				1
Total cash and cash equivalents		77,069				119
Securitization recovery trust account		7,904				4,666
Accounts receivable:
Customer		160,955				94,348
Allowance for doubtful accounts		(1,423		)		(1,264		)
Associated companies		45,499				48,184
Other		48,569				64,393
Accrued unbilled revenues		137,444				108,092
Total accounts receivable		391,044				313,753
Deferred fuel costs		—				19,235
Fuel inventory - at average cost		28,498				23,148
Materials and supplies - at average cost		207,541				196,314
Deferred nuclear refueling outage costs		33,581				78,966
Prepayments and other		17,447				14,553
TOTAL		763,084				650,754
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds		1,045,826				912,049
Other		5,476				5,480
TOTAL		1,051,302				917,529
UTILITY PLANT
Electric		12,041,822				11,611,041
Construction work in progress		299,195				243,731
Nuclear fuel		186,731				220,602
TOTAL UTILITY PLANT		12,527,748				12,075,374
Less - accumulated depreciation and amortization		4,985,276				4,864,818
UTILITY PLANT - NET		7,542,472				7,210,556
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $4,596 as of September 30, 2019 and $14,329 as of December 31, 2018)		1,590,726				1,534,977
Deferred fuel costs		67,591				67,294
Other		21,441				20,486
TOTAL		1,679,758				1,622,757
TOTAL ASSETS			$11,036,616				$10,401,596
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Accounts payable:
Associated companies			$55,971				$251,768
Other		195,783				187,387
Customer deposits		101,349				99,053
Taxes accrued		38,281				56,889
Interest accrued		39,099				18,893
Deferred fuel costs		33,530				—
Current portion of unprotected excess accumulated deferred income taxes		33,692				99,316
Other		48,516				23,943
TOTAL		546,221				737,249
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		1,172,542				1,085,545
Accumulated deferred investment tax credits		32,002				32,903
Regulatory liability for income taxes - net		480,573				505,748
Other regulatory liabilities		526,004				402,668
Decommissioning		1,224,936				1,048,428
Accumulated provisions		57,820				48,979
Pension and other postretirement liabilities		287,086				313,295
Long-term debt (includes securitization bonds of $14,016 as of September 30, 2019 and $20,898 as of December 31, 2018)		3,538,384				3,225,759
Other		63,809				17,919
TOTAL		7,383,156				6,681,244
Commitments and Contingencies
EQUITY
Member's equity		3,107,239				2,983,103
TOTAL		3,107,239				2,983,103
TOTAL LIABILITIES AND EQUITY			$11,036,616				$10,401,596
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Member's Equity
		(In Thousands)
Balance at December 31, 2017			$2,376,754
Net income		36,255
Preferred stock dividends		(357		)
Balance at March 31, 2018		2,412,652
Net income		82,556
Capital contribution from parent		350,000
Preferred stock dividends		(357		)
Balance at June 30, 2018		2,844,851
Net income		128,890
Preferred stock dividends		(357		)
Balance at September 30, 2018			$2,973,384
Balance at December 31, 2018			$2,983,103
Net income		39,121
Balance at March 31, 2019		3,022,224
Net income		50,299
Common equity distributions		(115,000		)
Balance at June 30, 2019		2,957,523
Net income		149,716
Balance at September 30, 2019			$3,107,239
See Notes to Financial Statements.

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ENTERGY ARKANSAS, LLC AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$254				$250				$4			2
Commercial		163				120				43				36
Industrial		156				126				30				24
Governmental		6				4				2				50
Total billed retail		579				500				79				16
Sales for resale:
Associated companies		30				23				7				30
Non-associated companies		29				37				(8		)		(22	)
Other		50				8				42				525
Total			$688				$568				$120			21
Billed Electric Energy Sales (GWh):
Residential		2,393				2,482				(89		)		(4	)
Commercial		1,761				1,816				(55		)		(3	)
Industrial		2,125				2,283				(158		)		(7	)
Governmental		67				67				—				—
Total retail		6,346				6,648				(302		)		(5	)
Sales for resale:
Associated companies		588				483				105				22
Non-associated companies		1,515				1,818				(303		)		(17	)
Total		8,449				8,949				(500		)		(6	)
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$621				$645				($24	)		(4	)
Commercial		413				334				79				24
Industrial		396				335				61				18
Governmental		16				13				3				23
Total billed retail		1,446				1,327				119				9
Sales for resale:
Associated companies		89				80				9				11
Non-associated companies		124				100				24				24
Other		117				107				10				9
Total			$1,776				$1,614				$162			10
Billed Electric Energy Sales (GWh):
Residential		6,144				6,455				(311		)		(5	)
Commercial		4,433				4,577				(144		)		(3	)
Industrial		5,800				6,064				(264		)		(4	)
Governmental		181				181				—				—
Total retail		16,558				17,277				(719		)		(4	)
Sales for resale:
Associated companies		1,694				1,206				488				40
Non-associated companies		6,071				4,706				1,365				29
Total		24,323				23,189				1,134				5

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $37 million primarily due to higher retail electric price and higher volume/weather. The increase was partially offset by higher depreciation and amortization expenses, higher other operation and maintenance expenses, and higher interest expense.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income increased $51.7 million primarily due to higher retail electric price. The increase was partially offset by a higher effective income tax rate, lower volume/weather, higher depreciation and amortization expenses, and higher interest expense.

Operating Revenues

Third Quarter 2019 Compared to Third Quarter 2018

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$1,206.6
Fuel, rider, and other revenues that do not significantly affect net income	(77.3		)
Retail electric price	52.0
Return of unprotected excess accumulated deferred income taxes to customers	37.6
Volume/weather	12.8
2019 operating revenues		$1,231.7

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an increase in formula rate plan revenues effective September 2018 and an interim increase in formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for St. Charles Power Station, each as approved by the LPSC. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through changes in the formula rate plan effective May 2018.

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In third quarter 2019, $17.2 million was returned to customers as compared to $54.8 million in third quarter 2018. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase in usage during the unbilled sales period.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$3,308.7
Fuel, rider, and other revenues that do not significantly affect net income	(159.2		)
Retail electric price	106.5
Return of unprotected excess accumulated deferred income taxes to customers	55.5
Volume/weather	(14.2		)
2019 operating revenues		$3,297.3

    

Entergy Louisiana’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The retail electric price variance is primarily due to an increase in formula rate plan revenues effective September 2018 and an interim increase in formula rate plan revenues effective June 2019 due to the inclusion of the first-year revenue requirement for the St. Charles Power Station, each as approved by the LPSC. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan proceedings.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through changes in the formula rate plan effective May 2018. In the nine months ended September 30, 2019, $30.8 million was returned to customers as compared to $86.3 million in the nine months ended September 30, 2018. There is no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to a decrease of 623 GWh, or 3%, in billed electricity usage for residential and commercial customers, including the effect of less favorable weather. The decrease was partially offset by an increase in industrial usage primarily due to an increase in demand from expansion projects, primarily in the chemicals industry.

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Management's Financial Discussion and Analysis

Other Income Statement Variances

Third Quarter 2019 Compared to Third Quarter 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $5.6 million in loss provisions;

•	an increase of $4.3 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement; and

•	an increase of $3.6 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance.

The increase was partially offset by a decrease of $3.9 million in nuclear generation expenses primarily due to proceeds of $5.2 million received in September 2019 from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 1 to the financial statements herein for a discussion of the spent nuclear fuel litigation.

    

Taxes other than income increased primarily due to an increase in ad valorem taxes resulting from higher assessments.

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the St. Charles Power Station, which was placed into service in May 2019.

Other regulatory charges (credits) include regulatory charges of $18.3 million recorded in third quarter 2018 to reflect the effects of a provision in the settlement reached in the formula rate plan extension proceeding to return the benefits of the lower federal income tax rate in 2018 to customers. See Note 2 to the financial statements in the Form 10-K for discussion of the formula rate plan extension proceeding.

Interest expense increased primarily due to the issuance of $525 million of 4.20% Series mortgage bonds in March 2019.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $10.4 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $8.3 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance; and

•	an increase of $3.5 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services.

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The increase was substantially offset by:

•	a decrease of $7.2 million in nuclear generation expenses primarily due to proceeds of $5.2 million received in September 2019 from the DOE litigation regarding spent nuclear fuel storage costs that were previously expensed and a lower scope of work performed during plant outages in 2019 as compared to the same period in 2018;

•	a decrease of $6 million in transmission expenses primarily due to a lower scope of work in 2019 as compared to the same period in 2018;

•	a decrease of $4 million in vegetation maintenance costs; and

•	a decrease of $3.6 million in energy efficiency costs due to the timing of recovery from customers.

See Note 1 to the financial statements herein for a discussion of the spent nuclear fuel litigation

Depreciation and amortization expenses increased primarily due to additions to plant in service, including the St. Charles Power Station, which was placed in service in May 2019.

Other regulatory charges (credits) include regulatory charges of $73.3 million recorded in 2018 to reflect the effects of a provision in the settlement reached in the formula rate plan extension proceeding to return the benefits of the lower federal income tax rate in 2018 to customers. See Note 2 to the financial statements in the Form 10-K for discussion of the formula rate plan extension proceeding.

Other income increased primarily due to changes in decommissioning trust fund investment activity.

Interest expense increased primarily due to the issuance of $525 million of 4.20% Series mortgage bonds in March 2019.

Income Taxes

The effective income tax rates were 17.7% for the third quarter 2019 and 16.3% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes, book and tax differences related to the non-taxable income distributions earned on preferred membership interests, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 1.3% for the third quarter 2018. The difference in the effective income tax rate for the third quarter 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes and book and tax differences related to the non-taxable income distributions earned on preferred membership interests, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was (6.3%) for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, an IRS audit settlement for the 2012-2013 tax returns, and book and tax differences related to the non-taxable income distributions earned on preferred membership interests, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act. See Note 3 to the financial statements in the Form 10-K for a discussion of the IRS audit settlement.

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Management's Financial Discussion and Analysis

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$43,364				$35,907
Cash flow provided by (used in):
Operating activities	962,443				943,300
Investing activities	(1,260,023		)		(1,283,844		)
Financing activities	382,261				518,222
Net increase in cash and cash equivalents	84,681				177,678
Cash and cash equivalents at end of period		$128,045				$213,585

Operating Activities

Net cash flow provided by operating activities increased $19.1 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a decrease of $40.1 million in pension contributions in 2019 as compared to 2018. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding;

•	proceeds of $16.6 million received in September 2019 from the DOE litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 1 to the financial statements herein for a discussion of the spent nuclear fuel litigation; and

•	a decrease in the return of unprotected excess accumulated deferred income taxes to customers. See Note 2 to the financial statements in the Form 10-K and Note 10 to the financial statements herein for a discussion of the effects and the regulatory activity regarding the Tax Cuts and Jobs Act.

The increase was partially offset by:

•	an increase of $68.4 million in spending on nuclear refueling outages;

•	the timing of payments to vendors; and

•	an increase of $18.7 million in storm spending in 2019.

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Management's Financial Discussion and Analysis

Investing Activities

Net cash flow used in investing activities decreased $23.8 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	a decrease of $214.4 million in fossil-fueled generation construction expenditures, primarily due to lower spending on the St. Charles Power Station and Lake Charles Power Station projects in 2019;

•	money pool activity;

•	a decrease of $11.6 million in information technology capital expenditures primarily due to lower spending in 2019 on critical infrastructure protection; and

•	several individually insignificant items.

The decrease was partially offset by:

•	an increase of $73.3 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and service deliveries, and the timing of cash payments during the nuclear fuel cycle;

•	an increase of $55.4 million in nuclear construction expenditures primarily due to increased spending on various projects in 2019;

•	an increase of $47.5 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy Louisiana’s distribution system, including increased spending on advanced metering infrastructure;

•	an increase of $38.9 million in transmission expenditures primarily due to a higher scope of work performed in 2019 as compared to the same period in 2018; and

•	an increase of $38.6 million in storm spending in 2019.

Decreases in Entergy Louisiana’s receivable from the money pool are a source of cash flow, and Entergy Louisiana’s receivable from the money pool decreased by $35.5 million for the nine months ended September 30, 2019 compared to increasing by $2.4 million for the nine months ended September 30, 2018. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities decreased $136 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	the issuance of $750 million of 4.00% Series mortgage bonds in March 2018. A portion of the proceeds was used to repay $375 million of 6.0% Series mortgage bonds in May 2018;

•	the issuance of $600 million of 4.20% Series mortgage bonds in August 2018. A portion of the proceeds was used to repay $300 million of 6.5% Series mortgage bonds in September 2018; and

•	an increase of $99 million in common equity distributions in 2019 primarily to maintain Entergy Louisiana’s targeted capital structure.

The decrease was partially offset by:

•	the issuance of $525 million of 4.20% Series mortgage bonds in March 2019;

•	net long-term borrowings of $29.2 million on the nuclear fuel company variable interest entities’ credit facilities in 2019 compared to net repayments of long-term borrowings of $37 million on the nuclear fuel company variable interest entities’ credit facilities in 2018; and

•	net repayments of short-term borrowings of $43.5 million in 2018 on the nuclear fuel company variable interest entities’ credit facilities.

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Management's Financial Discussion and Analysis

See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

Entergy Louisiana’s debt to capital ratio is shown in the following table.

 

	September 30, 2019			December 31, 2018
Debt to capital	53.8	%		53.6	%
Effect of excluding securitization bonds	(0.1	%)		(0.3	%)
Debt to capital, excluding securitization bonds (a)	53.7	%		53.3	%
Effect of subtracting cash	(0.5	%)		(0.1	%)
Net debt to net capital, excluding securitization bonds (a)	53.2	%		53.2	%

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Louisiana.

Debt consists of short-term borrowings, financing lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Louisiana uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because the securitization bonds are non-recourse to Entergy Louisiana, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy Louisiana also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Louisiana’s financial condition because net debt indicates Entergy Louisiana’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Louisiana’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Louisiana is developing its capital investment plan for 2020 through 2022 and currently anticipates making $4.4 billion in capital investments during that period. The preliminary estimate includes specific investments such as the Washington Parish Energy Center and Lake Charles Power Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to maintain reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; investments in River Bend and Waterford 3; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Louisiana’s receivables from the money pool were as follows:

September 30, 2019		December 31, 2018		September 30, 2018		December 31, 2017
(In Thousands)
$11,358		$46,843		$13,617		$11,173

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Louisiana has a credit facility in the amount of $350 million scheduled to expire in September 2024.  The credit facility includes fronting commitments for the issuance of letters of credit against $15 million of the

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Management's Financial Discussion and Analysis

borrowing capacity of the facility. As of September 30, 2019, there were no cash borrowings and no letters of credit outstanding under the credit facility.  In addition, Entergy Louisiana is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of September 30, 2019, a $11.7 million letter of credit was outstanding under Entergy Louisiana’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

The Entergy Louisiana nuclear fuel company variable interest entities have two separate credit facilities, each in the amount of $105 million and scheduled to expire in September 2021.  As of September 30, 2019, $84.3 million in loans were outstanding under the credit facility for the Entergy Louisiana River Bend nuclear fuel company variable interest entity. As of September 30, 2019, $65.5 million in loans were outstanding under the credit facility for the Entergy Louisiana Waterford nuclear fuel company variable interest entity. See Note 4 to the financial statements herein for additional discussion of the nuclear fuel company variable interest entity credit facilities.

St. Charles Power Station

As discussed in the Form 10-K, the LPSC issued an order in December 2016 approving certification that the public necessity and convenience would be served by the construction of the St. Charles Power Station. Commercial operation commenced in May 2019.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation and Fuel Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel cost recovery. The following are updates to that discussion.

Retail Rates - Electric

2017 Formula Rate Plan Filing

Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019.

2018 Formula Rate Plan Filing

In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues.

Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing.

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Management's Financial Discussion and Analysis

Several parties intervened in the proceeding, and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report, the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests.

Investigation of Costs Billed by Entergy Services

In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit.

Retail Rates - Gas

2018 Rate Stabilization Plan Filing

As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review.

Gas Rate Stabilization Plan Extension Request

In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020.

Fuel and purchased power recovery

In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations.

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Entergy Louisiana, LLC and Subsidiaries

Management's Financial Discussion and Analysis

Net Metering Rulemaking

In September 2019 the LPSC issued an order modifying its rules regarding net metering installations.  Among other things, the rule provides for 2-channel billing for net metering with excess energy put to the grid being compensated at the utility’s avoided cost.  However, the rule does provide that net meter installations in place as of December 31, 2019 will be subject to 1:1 net metering with excess energy put to the grid being compensated at the full retail rate for a period of 15 years (through December 31, 2034), after which those installations will be subject to 2-channel billing.  The rule also eliminates the existing limit on the cumulative number of net meter installations. 

Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Louisiana’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$1,221,874				$1,196,278				$3,252,826				$3,263,073
Natural gas		9,803				10,334				44,498				45,671
TOTAL		1,231,677				1,206,612				3,297,324				3,308,744
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		259,419				318,987				627,240				700,296
Purchased power		197,830				218,063				678,150				736,449
Nuclear refueling outage expenses		14,026				12,969				40,225				38,739
Other operation and maintenance		249,773				239,230				726,496				724,604
Decommissioning		15,606				13,654				43,544				39,906
Taxes other than income taxes		49,602				44,594				145,942				143,021
Depreciation and amortization		137,891				124,030				394,271				366,950
Other regulatory charges (credits) - net		(29,224		)		(1,433		)		(90,762		)		30,781
TOTAL		894,923				970,094				2,565,106				2,780,746
OPERATING INCOME		336,754				236,518				732,218				527,998
OTHER INCOME
Allowance for equity funds used during construction		14,609				20,423				59,194				57,292
Interest and investment income		45,237				53,009				166,721				143,137
Miscellaneous - net		(15,067		)		(25,782		)		(79,717		)		(56,217		)
TOTAL		44,779				47,650				146,198				144,212
INTEREST EXPENSE
Interest expense		78,350				73,084				230,684				216,762
Allowance for borrowed funds used during construction		(7,041		)		(10,168		)		(28,145		)		(28,382		)
TOTAL		71,309				62,916				202,539				188,380
INCOME BEFORE INCOME TAXES		310,224				221,252				675,877				483,830
Income taxes		54,964				2,944				109,900				(30,430		)
NET INCOME			$255,260				$218,308				$565,977				$514,260
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Three Months Ended								Nine Months Ended
	2019				2018				2019				2018
	(In Thousands)								(In Thousands)
Net Income		$255,260				$218,308				$565,977				$514,260
Other comprehensive loss
Pension and other postretirement liabilities (net of tax benefit of $342, $177, $1,026, and $530)	(969		)		(500		)		(2,907		)		(1,502		)
Other comprehensive loss	(969		)		(500		)		(2,907		)		(1,502		)
Comprehensive Income		$254,291				$217,808				$563,070				$512,758
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$565,977				$514,260
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		498,397				490,638
Deferred income taxes, investment tax credits, and non-current taxes accrued		174,825				167,603
Changes in working capital:
Receivables		(72,018		)		(61,281		)
Fuel inventory		(1,752		)		6,120
Accounts payable		(40,131		)		(20,481		)
Prepaid taxes and taxes accrued		78,910				(22,893		)
Interest accrued		5,102				2,382
Deferred fuel costs		(11,459		)		(25,781		)
Other working capital accounts		(62,332		)		(5,086		)
Changes in provisions for estimated losses		9,748				7,800
Changes in other regulatory assets		(103,635		)		49,245
Changes in other regulatory liabilities		(26,115		)		(29,943		)
Changes in pension and other postretirement liabilities		(15,761		)		(59,305		)
Other		(37,313		)		(69,978		)
Net cash flow provided by operating activities		962,443				943,300
INVESTING ACTIVITIES
Construction expenditures		(1,277,108		)		(1,322,633		)
Allowance for equity funds used during construction		59,194				57,292
Nuclear fuel purchases		(63,157		)		(32,362		)
Proceeds from the sale of nuclear fuel		11,608				54,088
Payments to storm reserve escrow account		(5,013		)		(3,297		)
Changes to securitization account		(6,467		)		(8,056		)
Proceeds from nuclear decommissioning trust fund sales		307,164				943,306
Investment in nuclear decommissioning trust funds		(331,138		)		(973,218		)
Changes in money pool receivable - net		35,485				(2,444		)
Insurance proceeds		7,040				3,480
Other		2,369				—
Net cash flow used in investing activities		(1,260,023		)		(1,283,844		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		2,332,003				1,950,482
Retirement of long-term debt		(1,798,014		)		(1,338,227		)
Changes in short-term borrowings - net		—				(43,540		)
Distributions paid:
Common equity		(155,000		)		(56,000		)
Other		3,272				5,507
Net cash flow provided by financing activities		382,261				518,222
Net increase in cash and cash equivalents		84,681				177,678
Cash and cash equivalents at beginning of period		43,364				35,907
Cash and cash equivalents at end of period			$128,045				$213,585
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized			$219,323				$208,028
Income taxes			$—				($2,973	)
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$224				$252
Temporary cash investments		127,821				43,112
Total cash and cash equivalents		128,045				43,364
Accounts receivable:
Customer		258,090				199,903
Allowance for doubtful accounts		(2,154		)		(1,813		)
Associated companies		81,906				123,363
Other		46,282				60,879
Accrued unbilled revenues		194,753				167,052
Total accounts receivable		578,877				549,384
Fuel inventory		36,170				34,418
Materials and supplies - at average cost		344,207				324,627
Deferred nuclear refueling outage costs		70,456				24,406
Prepayments and other		47,519				38,715
TOTAL		1,205,274				1,014,914
OTHER PROPERTY AND INVESTMENTS
Investment in affiliate preferred membership interests		1,390,587				1,390,587
Decommissioning trust funds		1,485,569				1,284,996
Storm reserve escrow account		294,538				289,525
Non-utility property - at cost (less accumulated depreciation)		308,095				286,555
Other		13,923				14,927
TOTAL		3,492,712				3,266,590
UTILITY PLANT
Electric		22,283,456				20,532,312
Natural gas		230,416				211,421
Construction work in progress		1,325,784				1,864,582
Nuclear fuel		291,404				298,022
TOTAL UTILITY PLANT		24,131,060				22,906,337
Less - accumulated depreciation and amortization		9,018,154				8,837,596
UTILITY PLANT - NET		15,112,906				14,068,741
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $32,939 as of September 30, 2019 and $49,753 as of December 31, 2018)		1,208,712				1,105,077
Deferred fuel costs		168,122				168,122
Other		27,297				28,371
TOTAL		1,404,131				1,301,570
TOTAL ASSETS			$21,215,023				$19,651,815
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt			$70,002				$2
Accounts payable:
Associated companies		86,781				102,749
Other		338,724				390,367
Customer deposits		152,627				155,314
Taxes accrued		109,778				30,868
Interest accrued		88,552				83,450
Deferred fuel costs		19,952				31,411
Current portion of unprotected excess accumulated deferred income taxes		33,231				31,457
Other		71,608				49,202
TOTAL		971,255				874,820
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		2,414,508				2,226,721
Accumulated deferred investment tax credits		113,346				116,999
Regulatory liability for income taxes - net		523,697				581,001
Other regulatory liabilities		778,199				748,784
Decommissioning		1,478,951				1,280,272
Accumulated provisions		320,503				310,755
Pension and other postretirement liabilities		627,155				643,171
Long-term debt (includes securitization bonds of $45,386 as of September 30, 2019 and $55,682 as of December 31, 2018)		7,274,158				6,805,766
Other		402,296				160,608
TOTAL		13,932,813				12,874,077
Commitments and Contingencies
EQUITY
Member's equity		6,320,015				5,909,071
Accumulated other comprehensive loss		(9,060		)		(6,153		)
TOTAL		6,310,955				5,902,918
TOTAL LIABILITIES AND EQUITY			$21,215,023				$19,651,815
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Common Equity
	Member’s Equity				Accumulated Other Comprehensive Loss				Total
	(In Thousands)
Balance at December 31, 2017		$5,355,204				($46,400	)			$5,308,804
Net income	111,593				—				111,593
Other comprehensive loss	—				(501		)		(501		)
Reclassification pursuant to ASU 2018-02	6,262				(10,049		)		(3,787		)
Other	24				—				24
Balance at March 31, 2018	5,473,083				(56,950		)		5,416,133
Net income	184,358				—				184,358
Other comprehensive loss	—				(501		)		(501		)
Common equity distributions	(56,000		)		—				(56,000		)
Other	(10		)		—				(10		)
Balance at June 30, 2018	5,601,431				(57,451		)		5,543,980
Net income	218,308				—				218,308
Other comprehensive loss	—				(500		)		(500		)
Other	(10		)		—				(10		)
Balance at September 30, 2018		$5,819,729				($57,951	)			$5,761,778
Balance at December 31, 2018		$5,909,071				($6,153	)			$5,902,918
Net income	127,633				—				127,633
Other comprehensive loss	—				(969		)		(969		)
Common equity distributions	(49,000		)		—				(49,000		)
Other	(11		)		—				(11		)
Balance at March 31, 2019	5,987,693				(7,122		)		5,980,571
Net income	183,084				—				183,084
Other comprehensive loss	—				(969		)		(969		)
Common equity distributions	(53,000		)		—				(53,000		)
Other	(14		)		—				(14		)
Balance at June 30, 2019	6,117,763				(8,091		)		6,109,672
Net income	255,260				—				255,260
Other comprehensive loss	—				(969		)		(969		)
Common equity distributions	(53,000		)		—				(53,000		)
Other	(8		)		—				(8		)
Balance at September 30, 2019		$6,320,015				($9,060	)			$6,310,955
See Notes to Financial Statements.

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ENTERGY LOUISIANA, LLC AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$426				$409				$17			4
Commercial		277				273				4				1
Industrial		376				394				(18		)		(5	)
Governmental		19				17				2				12
Total billed retail		1,098				1,093				5				—
Sales for resale:
Associated companies		66				58				8				14
Non-associated companies		16				14				2				14
Other		42				31				11				35
Total			$1,222				$1,196				$26			2
Billed Electric Energy Sales (GWh):
Residential		4,614				4,658				(44		)		(1	)
Commercial		3,325				3,382				(57		)		(2	)
Industrial		7,741				7,619				122				2
Governmental		215				216				(1		)		—
Total retail		15,895				15,875				20				—
Sales for resale:
Associated companies		1,494				1,545				(51		)		(3	)
Non-associated companies		526				369				157				43
Total		17,915				17,789				126				1
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$980				$972				$8			1
Commercial		716				720				(4		)		(1	)
Industrial		1,108				1,115				(7		)		(1	)
Governmental		54				51				3				6
Total billed retail		2,858				2,858				—				—
Sales for resale:
Associated companies		201				229				(28		)		(12	)
Non-associated companies		48				44				4				9
Other		146				132				14				11
Total			$3,253				$3,263				($10	)		—
Billed Electric Energy Sales (GWh):
Residential		10,815				11,221				(406		)		(4	)
Commercial		8,564				8,781				(217		)		(2	)
Industrial		22,577				22,160				417				2
Governmental		623				613				10				2
Total retail		42,579				42,775				(196		)		—
Sales for resale:
Associated companies		3,428				4,099				(671		)		(16	)
Non-associated companies		1,433				1,237				196				16
Total		47,440				48,111				(671		)		(1	)

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ENTERGY MISSISSIPPI, LLC

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $5.5 million primarily due to higher retail electric price and higher volume/weather, partially offset by a higher effective income tax rate and higher depreciation and amortization expenses.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income decreased $13.5 million primarily due to higher depreciation and amortization expenses, lower volume/weather, higher interest expense, and higher taxes other than income taxes, partially offset by higher retail electric price.

Operating Revenues

Third Quarter 2019 Compared to Third Quarter 2018

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$367.7
Fuel, rider, and other revenues that do not significantly affect net income	(9.8		)
Return of unprotected excess accumulated deferred income taxes to customers	25.8
Retail electric price	7.7
Volume/weather	7.3
2019 operating revenues		$398.7

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers is due to the return of unprotected excess accumulated deferred income taxes through customer bill credits over a three-month period from July 2018 through September 2018 per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Cuts and Jobs Act. There was no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of July 2019, as approved by the MPSC. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filing.

The volume/weather variance is primarily due to increased usage during the unbilled sales period.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$1,037.2
Fuel, rider, and other revenues that do not significantly affect net income	(80.7		)
Volume/weather	(8.1		)
Retail electric price	9.5
Return of unprotected excess accumulated deferred income taxes to customers	25.8
2019 operating revenues		$983.7

Entergy Mississippi’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to a decrease of 524 GWh, or 5%, in billed electricity usage, including the effect of less favorable weather on residential sales and a decrease in industrial usage. The decrease in industrial usage is primarily due to decreased small industrial sales.

The retail electric price variance is primarily due to an increase in formula rate plan rates effective with the first billing cycle of July 2019, as approved by the MPSC. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the formula rate plan filing.

The return of unprotected excess accumulated deferred income taxes to customers is due to the return of unprotected excess accumulated deferred income taxes through customer bill credits over a three-month period from July 2018 through September 2018 per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Cuts and Jobs Act. There was no effect on net income as the reduction in operating revenues was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Other Income Statement Variances

Third Quarter 2019 Compared to Third Quarter 2018

Other operation and maintenance expenses decreased primarily due to a $5.8 million loss in 2018 on the sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense. The decrease in other operation and maintenance expenses was significantly offset by an increase of $4 million in storm damage provisions. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of storm cost recovery.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Depreciation and amortization expenses increased primarily as a result of higher depreciation rates, as approved by the MPSC, and additions to plant in service.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $4 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $3.7 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed during plant outages;

•	an increase of $3.1 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance;

•	an increase of $1.5 million in loss provisions; and

•	an increase of $1.3 million in distribution operations and asset management costs due to higher advanced metering customer education costs and higher contract costs for meter reading services.

The increase was partially offset by:

•	a $5.8 million loss in 2018 on the sale of fuel oil inventory per an agreement approved by the MPSC in June 2018 resulting from the stipulation related to the effects of the Tax Act. There is no effect on net income as the loss on the sale of fuel oil inventory is offset by a reduction in income tax expense; and

•	a decrease of $5.8 million in storm damage provisions. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of storm cost recovery.

Taxes other than income taxes increased primarily due to an increase in ad valorem taxes, partially offset by lower local franchise taxes. Ad valorem taxes increased primarily due to higher millage rates due to a rate increase effective October 2018. Local franchise taxes decreased primarily due to lower residential and commercial revenues in 2019 compared to 2018.

Depreciation and amortization expenses increased primarily as a result of higher depreciation rates, as approved by the MPSC, and additions to plant in service.

Other regulatory charges include a regulatory charge recorded in second quarter 2018 to reflect the return of unprotected excess accumulated deferred income taxes per an agreement approved by the MPSC in June 2018 that resulted in a reduction in net utility plant of $127.2 million. There is no effect on net income as the regulatory charge was offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity related to the Tax Cuts and Jobs Act.

Interest expense increased primarily due to the issuance of $55 million of 4.52% Series mortgage bonds in December 2018 and $300 million of 3.85% Series mortgage bonds in June 2019, partially offset by the repayment, at maturity, of $150 million of 6.64% Series mortgage bonds in July 2019.

Income Taxes

The effective income tax rates were 22.8% for the third quarter 2019 and 21.6% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to state income taxes, partially offset by certain book and tax differences related to utility plant items.

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The effective income tax rate was (46.7%) for the third quarter 2018. The difference in the effective income tax rate for the third quarter 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 1,039.9% for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the amortization of excess accumulated deferred income taxes, state income taxes, and book and tax differences related to the allowance for equity funds used during construction. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$36,954				$6,096
Cash flow provided by (used in):
Operating activities	203,439				218,024
Investing activities	(276,307		)		(268,165		)
Financing activities	134,850				44,090
Net increase (decrease) in cash and cash equivalents	61,982				(6,051		)
Cash and cash equivalents at end of period		$98,936				$45

Operating Activities

Net cash flow provided by operating activities decreased $14.6 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	$26.2 million in proceeds from the sale of fuel oil inventory in 2018;

•	the timing of collection of storm damage rider revenues. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the storm damage rider; and

•	an increase of $6.2 million in storm spending in 2019.

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The decrease was partially offset by:

•	the return of unprotected excess accumulated deferred income taxes to customers in 2018;

•	the timing of recovery of fuel and purchased power costs; and

•	a decrease of $7 million in pension contributions in 2019 as compared to 2018. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

Investing Activities

Net cash flow used in investing activities increased $8.1 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	an increase of $20.3 million primarily due to investment in the infrastructure of Entergy Mississippi’s distribution system, including increased spending on advanced metering infrastructure;

•	an increase of $15.1 million in storm spending in 2019; and

•	an increase of $12.9 million in transmission construction expenditures primarily due to a higher scope of work performed in 2019 as compared to the same period in 2018.

The increase was partially offset by money pool activity.

Decreases in Entergy Mississippi’s receivable from the money pool are a source of cash flow, and Entergy Mississippi’s receivable from the money pool decreased by $32.5 million for the nine months ended September 30, 2019 compared to decreasing by $1.6 million for the nine months ended September 30, 2018. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $90.8 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to the issuance of $300 million of 3.85% Series mortgage bonds in June 2019. The increase was partially offset by the repayment, at maturity, of $150 million of 6.64% Series mortgage bonds in July 2019 and money pool activity. See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Increases in Entergy Mississippi’s payable to the money pool are a source of cash flow, and Entergy Mississippi’s payable to the money pool increased by $33.8 million for the nine months ended September 30, 2018.

Capital Structure

Entergy Mississippi’s debt to capital ratio is shown in the following table.

	September 30, 2019			December 31, 2018
Debt to capital	51.5	%		50.6	%
Effect of subtracting cash	(1.7	%)		(0.7	%)
Net debt to net capital	49.8	%		49.9	%

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, financing lease obligations, and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Mississippi uses the debt to capital ratio in analyzing

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Management's Financial Discussion and Analysis

its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition.  Entergy Mississippi uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Mississippi’s financial condition because net debt indicates Entergy Mississippi’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Mississippi’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

Entergy Mississippi is developing its capital investment plan for 2020 through 2022 and currently anticipates making $1.5 billion in capital investments during that period. The preliminary estimate includes specific investments such as the Sunflower Solar Facility; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; resource planning, including potential generation projects; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Mississippi’s receivables from or (payables to) the money pool were as follows:

September 30, 2019		December 31, 2018		September 30, 2018		December 31, 2017
(In Thousands)
$8,899		$41,380		($33,816)		$1,633

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Mississippi has three separate credit facilities in the aggregate amount of $82.5 million scheduled to expire in May 2020. No borrowings were outstanding under the credit facilities as of September 30, 2019.  In addition, Entergy Mississippi is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of September 30, 2019, $8.1 million of letters of credit were outstanding under Entergy Mississippi’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

In October 2019, Entergy Mississippi received a capital contribution of $130 million in anticipation of Entergy Mississippi’s purchase of the Choctaw Generating Station.

Choctaw Generating Station

    In August 2018, Entergy Mississippi announced that it signed an asset purchase agreement to acquire from a subsidiary of GenOn Energy Inc. the Choctaw Generating Station, an 810 MW natural gas fired combined-cycle turbine plant located near French Camp, Mississippi.  The purchase price is expected to be approximately $314 million.  Entergy Mississippi also expects to invest in various plant upgrades at the facility after closing and expects the total cost of the acquisition to be approximately $401 million.  The purchase was contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and state regulatory and permitting agencies.  These included regulatory approvals from the MPSC and the FERC. Clearance under the Hart-Scott-Rodino Antitrust Improvements Act has occurred. In September 2019 the FERC approved the acquisition.  In October 2018, Entergy Mississippi filed an application with the MPSC seeking approval of the acquisition and cost recovery. In a separate

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filing in October 2018, Entergy Mississippi proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the non-fuel annual ownership costs of the Choctaw Generating Station, as well as to allow similar cost recovery treatment for other future capacity additions approved by the MPSC. Entergy Mississippi executed a joint stipulation as to all issues with the Mississippi Public Utilities Staff and, in October 2019, the MPSC adopted the joint stipulation which approved Entergy Mississippi’s request to acquire, own, operate, improve, and maintain the facility. The MPSC approved the expected total cost of the acquisition of approximately $401 million and authorized Entergy Mississippi to recover acquisition and ownership costs of the facility through its formula rate plan, including costs incurred before the effective date of the interim capacity rate mechanism, which Entergy Mississippi expects to be approved later this year. Entergy Mississippi purchased the plant in October 2019.

Sunflower Solar Facility

In November 2018, Entergy Mississippi announced that it signed an agreement for the purchase of an approximately 100 MW to-be-constructed solar photovoltaic facility that will be sited on approximately 1,000 acres in Sunflower County, Mississippi.  The estimated base purchase price is approximately $138.4 million.  The estimated total investment, including the base purchase price and other related costs, for Entergy Mississippi to acquire the Sunflower Solar Facility is approximately $153.2 million. The purchase is contingent upon, among other things, obtaining necessary approvals, including full cost recovery, from applicable federal and state regulatory and permitting agencies.  The project will be built by Sunflower County Solar Project, LLC, a sub-subsidiary of Recurrent Energy, LLC. Entergy Mississippi will purchase the facility upon mechanical completion and after the other purchase contingencies have been met.  In December 2018, Entergy Mississippi filed a joint petition with Sunflower Solar Project at the MPSC for Sunflower Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility.  Entergy Mississippi has proposed revisions to its formula rate plan that would provide for a mechanism, the interim capacity rate adjustment mechanism, in the formula rate plan to recover the non-fuel related costs of additional owned capacity acquired by Entergy Mississippi, including the annual ownership costs of the Sunflower Solar Facility. In August 2019 consultants retained by the Mississippi Public Utilities Staff filed a report expressing concerns regarding the project economics and recommended that, should the MPSC wish to approve the project, Entergy Mississippi should be required to guarantee the energy output of the unit. Entergy Mississippi and the Staff are engaged in settlement discussions to address these concerns.  A hearing before the MPSC is targeted to occur in the fourth quarter of 2019. Closing is targeted to occur by the end of 2021.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of the formula rate plan and fuel and purchased power cost recovery. The following are updates to that discussion.

Mississippi Attorney General Complaint

As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Formula Rate Plan

In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019.

Storm Cost Recovery Filings with Retail Regulators

As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

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Entergy Mississippi, LLC

Management's Financial Discussion and Analysis

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy Mississippi’s accounting for utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY MISSISSIPPI, LLC
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$398,732				$367,734				$983,713				$1,037,166
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		87,386				78,533				188,006				207,724
Purchased power		78,286				104,787				223,461				289,397
Other operation and maintenance		69,253				69,936				195,357				193,979
Taxes other than income taxes		26,673				26,024				78,613				75,212
Depreciation and amortization		44,339				37,752				123,145				114,293
Other regulatory charges - net		5,771				5,487				11,708				133,715
TOTAL		311,708				322,519				820,290				1,014,320
OPERATING INCOME		87,024				45,215				163,423				22,846
OTHER INCOME
Allowance for equity funds used during construction		2,079				2,251				6,341				6,351
Interest and investment income		462				1				1,011				26
Miscellaneous - net		(1,648		)		116				(2,238		)		(1,866		)
TOTAL		893				2,368				5,114				4,511
INTEREST EXPENSE
Interest expense		15,922				13,950				45,804				41,916
Allowance for borrowed funds used during construction		(892		)		(944		)		(2,683		)		(2,662		)
TOTAL		15,030				13,006				43,121				39,254
INCOME (LOSS) BEFORE INCOME TAXES		72,887				34,577				125,416				(11,897		)
Income taxes		16,650				(16,156		)		27,114				(123,715		)
NET INCOME		56,237				50,733				98,302				111,818
Preferred dividend requirements and other		—				238				—				715
EARNINGS APPLICABLE TO COMMON EQUITY			$56,237				$50,495				$98,302				$111,103
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$98,302				$111,818
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		123,145				114,293
Deferred income taxes, investment tax credits, and non-current taxes accrued		32,596				40,537
Changes in assets and liabilities:
Receivables		(37,843		)		(49,456		)
Fuel inventory		(3,872		)		33,705
Accounts payable		(574		)		(9,845		)
Taxes accrued		(26,556		)		(24,280		)
Interest accrued		2,093				(4,767		)
Deferred fuel costs		47,569				9,826
Other working capital accounts		533				(8,348		)
Provisions for estimated losses		(3,099		)		7,894
Other regulatory assets		(923		)		26,060
Other regulatory liabilities		(16,615		)		(139,063		)
Pension and other postretirement liabilities		(6,930		)		(15,987		)
Other assets and liabilities		(4,387		)		125,637
Net cash flow provided by operating activities		203,439				218,024
INVESTING ACTIVITIES
Construction expenditures		(314,622		)		(275,189		)
Allowance for equity funds used during construction		6,341				6,351
Changes in money pool receivable - net		32,481				1,633
Other		(507		)		(960		)
Net cash flow used in investing activities		(276,307		)		(268,165		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		292,763				—
Retirement of long-term debt		(150,000		)		—
Changes in money pool payable - net		—				33,816
Distributions/dividends paid:
Preferred stock		—				(715		)
Other		(7,913		)		10,989
Net cash flow provided by financing activities		134,850				44,090
Net increase (decrease) in cash and cash equivalents		61,982				(6,051		)
Cash and cash equivalents at beginning of period		36,954				6,096
Cash and cash equivalents at end of period			$98,936				$45
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized			$41,753				$44,781
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$11				$11
Temporary cash investments		98,925				36,943
Total cash and cash equivalents		98,936				36,954
Accounts receivable:
Customer		98,245				73,205
Allowance for doubtful accounts		(615		)		(563		)
Associated companies		19,217				51,065
Other		10,173				8,647
Accrued unbilled revenues		60,867				50,171
Total accounts receivable		187,887				182,525
Deferred fuel costs		—				8,016
Fuel inventory - at average cost		15,803				11,931
Materials and supplies - at average cost		51,049				47,255
Prepayments and other		8,694				9,365
TOTAL		362,369				296,046
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)		4,564				4,576
Storm reserve escrow account		32,953				32,447
TOTAL		37,517				37,023
UTILITY PLANT
Electric		4,981,082				4,780,720
Construction work in progress		177,221				128,149
TOTAL UTILITY PLANT		5,158,303				4,908,869
Less - accumulated depreciation and amortization		1,681,597				1,641,821
UTILITY PLANT - NET		3,476,706				3,267,048
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets		343,972				343,049
Other		12,161				3,638
TOTAL		356,133				346,687
TOTAL ASSETS			$4,232,725				$3,946,804
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt			$—				$150,000
Accounts payable:
Associated companies		41,323				42,928
Other		81,260				79,117
Customer deposits		86,295				85,085
Taxes accrued		50,996				77,552
Interest accrued		22,324				20,231
Deferred fuel costs		39,553				—
Other		17,717				7,526
TOTAL		339,468				462,439
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		591,105				551,869
Accumulated deferred investment tax credits		10,066				10,186
Regulatory liability for income taxes - net		239,630				246,402
Other regulatory liabilities		23,779				33,622
Asset retirement cost liabilities		9,594				9,206
Accumulated provisions		48,043				51,142
Pension and other postretirement liabilities		86,036				93,100
Long-term debt		1,469,454				1,175,750
Other		25,022				20,862
TOTAL		2,502,729				2,192,139
Commitments and Contingencies
EQUITY
Member's equity		1,390,528				1,292,226
TOTAL		1,390,528				1,292,226
TOTAL LIABILITIES AND EQUITY			$4,232,725				$3,946,804
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Member's Equity
		(In Thousands)
Balance at December 31, 2017			$1,177,870
Net income		22,843
Preferred stock dividends		(238		)
Balance at March 31, 2018		1,200,475
Net income		38,242
Preferred stock dividends		(239		)
Balance at June 30, 2018		1,238,478
Net income		50,733
Preferred stock dividends		(238		)
Balance at September 30, 2018			$1,288,973
Balance at December 31, 2018			$1,292,226
Net income		15,398
Balance at March 31, 2019		1,307,624
Net income		26,667
Balance at June 30, 2019		1,334,291
Net income		56,237
Balance at September 30, 2019			$1,390,528
See Notes to Financial Statements.

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ENTERGY MISSISSIPPI, LLC
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$178				$170				$8			5
Commercial		132				127				5				4
Industrial		44				44				—				—
Governmental		12				12				—				—
Total billed retail		366				353				13				4
Sales for resale:
Non-associated companies		10				8				2				25
Other		23				7				16				229
Total			$399				$368				$31			8
Billed Electric Energy Sales (GWh):
Residential		1,832				1,899				(67		)		(4	)
Commercial		1,403				1,475				(72		)		(5	)
Industrial		654				692				(38		)		(5	)
Governmental		126				128				(2		)		(2	)
Total retail		4,015				4,194				(179		)		(4	)
Sales for resale:
Non-associated companies		472				303				169				56
Total		4,487				4,497				(10		)		—
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$423				$451				($28	)		(6	)
Commercial		332				355				(23		)		(6	)
Industrial		121				133				(12		)		(9	)
Governmental		33				34				(1		)		(3	)
Total billed retail		909				973				(64		)		(7	)
Sales for resale:
Non-associated companies		19				21				(2		)		(10	)
Other		56				43				13				30
Total			$984				$1,037				($53	)		(5	)
Billed Electric Energy Sales (GWh):
Residential		4,307				4,547				(240		)		(5	)
Commercial		3,548				3,722				(174		)		(5	)
Industrial		1,808				1,916				(108		)		(6	)
Governmental		327				329				(2		)		(1	)
Total retail		9,990				10,514				(524		)		(5	)
Sales for resale:
Non-associated companies		852				903				(51		)		(6	)
Total		10,842				11,417				(575		)		(5	)

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $3.5 million primarily due to higher volume/weather, partially offset by higher other operation and maintenance expenses.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income decreased $3.6 million primarily due to higher other operation and maintenance expenses, partially offset by higher other income.

Operating Revenues

Third Quarter 2019 Compared to Third Quarter 2018

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$200.2
Fuel, rider, and other revenues that do not significantly affect net income	(19.1		)
Volume/weather	5.2
Return of unprotected excess accumulated deferred income taxes to customers	7.9
2019 operating revenues		$194.2

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The volume/weather variance is primarily due to the effect of more favorable weather on residential and commercial sales.

The return of unprotected excess accumulated deferred income taxes to customers variance is due to a decrease in the return of unprotected excess accumulated deferred income taxes through the fuel adjustment clause. In the third quarter 2019, $1.1 million was returned to customers as compared to $9 million in the third quarter 2018. There is no effect on net income as the reduction in operating revenues in each period is offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

    

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Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$566.9
Fuel, rider, and other revenues that do not significantly affect net income	(40.6		)
Return of unprotected excess accumulated deferred income taxes to customers	6.9
2019 operating revenues		$533.2

Entergy New Orleans’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers variance is due to a decrease in the return of unprotected excess accumulated deferred income taxes through the fuel adjustment clause. In the nine months ended September 30, 2019, $2.1 million was returned to customers as compared to $9 million in the nine months ended September 30, 2018. There is no effect on net income as the reduction in operating revenues in each period is offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

Other Income Statement Variances

Third Quarter 2019 Compared to Third Quarter 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $1.1 million in loss provisions;

•	an increase of $1 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement; and

•	an increase of $0.9 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance.

The increase was partially offset by several individually insignificant items.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $4.8 million in information technology costs primarily due to higher costs related to a system conversion for Algiers customers;

•	an increase of $2.4 million in spending on customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $1.4 million in customer service costs primarily due to higher labor costs, including contract labor; and

•	an increase of $1.3 million in energy efficiency costs.

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The increase was partially offset by a decrease of $1.8 million in distribution expenses primarily due to lower contract labor costs.

Other income increased primarily due to an increase in allowance for equity funds used during construction resulting from higher construction work in progress in 2019, including the New Orleans Power Station project.

Income Taxes

The effective income tax rates were 3.6% for the third quarter 2019 and 10.2% for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes, certain book and tax differences related to utility plant items, and book and tax differences related to the allowance for equity funds used during construction, partially offset by state income taxes and the provision for uncertain tax positions. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rates were (20.0%) for the third quarter 2018 and 7.2% for the nine months ended September 30, 2018. The differences in the effective income tax rates for the third quarter 2018 and the nine months ended September 30, 2018 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and flow-through tax accounting, partially offset by state income taxes. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017.  Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion.  Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$19,677				$32,741
Cash flow provided by (used in):
Operating activities	77,433				100,327
Investing activities	(136,817		)		(133,233		)
Financing activities	39,733				33,085
Net increase (decrease) in cash and cash equivalents	(19,651		)		179
Cash and cash equivalents at end of period		$26				$32,920

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Operating Activities

Net cash flow provided by operating activities decreased $22.9 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to the timing of payments to vendors.

Investing Activities

Net cash flow used in investing activities increased $3.6 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	an increase of $13.6 million in distribution construction expenditures primarily due to investment in the reliability and infrastructure of Entergy New Orleans’s distribution system, including increased spending on advanced metering infrastructure; and

•	an increase of $13.4 million in transmission construction expenditures primarily due to a higher scope of work performed in 2019 as compared to the same period in 2018, including investment in Entergy New Orleans’s system reliability and infrastructure.

The increase was partially offset by money pool activity and a decrease of $7.6 million in fossil-fueled generation construction expenditures primarily due to lower spending on the New Orleans Power Station in 2019 as compared to the same period in 2018.

Decreases in Entergy New Orleans’s receivable from the money pool are a source of cash flow, and Entergy New Orleans’s receivable from the money pool decreased $22 million for the nine months ended September 30, 2019 compared to decreasing $10.6 million for the nine months ended September 30, 2018. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Net cash flow provided by financing activities increased $6.6 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to money pool activity and $23.8 million in common equity distributions in 2018, partially offset by the issuance of $60 million of 4.51% Series mortgage bonds in September 2018. There were no common equity distributions made in 2019 in anticipation of planned capital investments.

Increases in Entergy New Orleans’s payable to the money pool are a source of cash flow, and Entergy New Orleans’s payable to the money pool increased $46.3 million for the nine months ended September 30, 2019.

Capital Structure

Entergy New Orleans’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to the increase in member’s equity in 2019.

	September 30, 2019			December 31, 2018
Debt to capital	49.5	%		52.1	%
Effect of excluding securitization bonds	(3.3	%)		(3.5	%)
Debt to capital, excluding securitization bonds (a)	46.2	%		48.6	%
Effect of subtracting cash	—	%		(1.2	%)
Net debt to net capital, excluding securitization bonds (a)	46.2	%		47.4	%

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy New Orleans.

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Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings, financing lease obligations, long-term debt, including the currently maturing portion, and the long-term payable due to an associated company.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy New Orleans uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because the securitization bonds are non-recourse to Entergy New Orleans, as more fully described in Note 5 to the financial statements in the Form 10-K. Entergy New Orleans also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy New Orleans’s financial condition because net debt indicates Entergy New Orleans’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy New Orleans’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.  

Entergy New Orleans is developing its capital investment plan for 2020 through 2022 and currently anticipates making $585 million in capital investments during that period.  The preliminary estimate includes specific investments such as the New Orleans Power Station and New Orleans Solar Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy New Orleans’s receivables from or (payables to) the money pool were as follows:

September 30,  2019		December 31, 2018		September 30,  2018		December 31, 2017
(In Thousands)
($46,318)		$22,016		$2,116		$12,723

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy New Orleans has a credit facility in the amount of $25 million scheduled to expire in November 2021. The credit facility includes fronting commitments for the issuance of letters of credit against $10 million of the borrowing capacity of the facility. As of September 30, 2019, there were no cash borrowings and a $0.8 million letter of credit was outstanding under the facility. In addition, Entergy New Orleans is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of September 30, 2019, a $1 million letter of credit was outstanding under Entergy New Orleans’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

New Orleans Power Station

In June 2016, Entergy New Orleans filed an application with the City Council seeking a public interest determination and authorization to construct the New Orleans Power Station, a 226 MW advanced combustion turbine in New Orleans, Louisiana, at the site of the existing Michoud generating facility, which was retired effective May 31, 2016. In January 2017 several intervenors filed testimony opposing the construction of the New Orleans Power Station on various grounds. In July 2017, Entergy New Orleans submitted a supplemental and amending application to the City Council seeking approval to construct either the originally proposed 226 MW advanced combustion turbine, or alternatively, a 128 MW unit composed of natural gas-fired reciprocating engines and a related cost recovery plan. The cost estimate for the alternative 128 MW unit is $210 million. In addition, the application renewed the commitment

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to pursue up to 100 MW of renewable resources to serve New Orleans. In March 2018 the City Council adopted a resolution approving construction of the 128 MW unit. The targeted commercial operation date is mid-2020, subject to receipt of all necessary permits.

In April 2018 intervenors opposing the construction of the New Orleans Power Station filed with the City Council a request for rehearing, which was subsequently denied, and a petition for judicial review of the City Council’s decision, and also filed a lawsuit challenging the City Council’s approval based on Louisiana’s open meeting law. In May 2018 the City Council announced that it would initiate an investigation into allegations that Entergy New Orleans, Entergy, or some other entity paid or participated in paying certain attendees and speakers in support of the New Orleans Power Station to attend or speak at certain meetings organized by the City Council. In June 2018, Entergy New Orleans produced documents in response to a City Council resolution relating to this investigation. In October 2018 investigators for the City Council released their report, concluding that individuals were paid to attend and/or speak in support of the New Orleans Power Station and that Entergy New Orleans “knew or should have known that such conduct occurred or reasonably might occur.”  The City Council issued a resolution requiring Entergy New Orleans to show cause why it should not be fined $5 million as a result of the findings in the report. In November 2018, Entergy New Orleans submitted its response to the show cause resolution, disagreeing with certain characterizations and omissions of fact in the report and asserting that the City Council could not legally impose the proposed fine.  Simultaneous with the filing of its response to the show cause resolution, Entergy New Orleans sent a letter to the City Council re-asserting that the City Council’s imposition of the proposed fine would be unlawful, but acknowledging that the actions of a subcontractor, which was retained by an Entergy New Orleans contractor without the knowledge or contractually-required consent of Entergy New Orleans, were contrary to Entergy’s values.  In that letter, Entergy New Orleans offered to donate $5 million to the City Council to resolve the show cause proceeding.  In January 2019, Entergy New Orleans submitted a new settlement proposal to the City Council. The proposal retained the components of the first offer but added to it a commitment to make reasonable efforts to limit the costs of the project to the $210 million cost estimate with advanced notification of anticipated cost overruns, additional reporting requirements for cost and environmental items, and a commitment regarding reliability investment and to work with the New Orleans Sewerage and Water Board to provide a reliable source of power. In February 2019 the City Council approved a resolution approving the settlement proposal and allowing the construction of the New Orleans Power Station to commence.

Also in February 2019, certain intervenors in the City Council proceeding on the New Orleans Power Station filed suit in Louisiana state court challenging the Louisiana Department of Environmental Quality’s issuance of the New Orleans Power Station’s air permit. Entergy New Orleans intervened in that lawsuit and, along with the Louisiana Department of Environmental Quality, filed exceptions seeking dismissal of the lawsuit. In June 2019 the state court judge sustained the exceptions and dismissed the plaintiffs’ petition with prejudice. Also in June 2019, a state court judge in New Orleans affirmed the City Council’s approval of the New Orleans Power Station and dismissed the petition for judicial review that had been filed in April 2018. The petitioners have filed an appeal of that ruling. Also in June 2019, with regard to the lawsuit challenging the City Council’s decision on the basis of a violation of the open meetings law, the same state court judge in New Orleans ruled that there was a violation of the open meetings law at the February 2018 meeting of the City Council’s Utilities, Cable, Telecommunications and Technology Committee at which that Committee considered the New Orleans Power Station approval, and further ruled that, although there was no violation of the open meetings law at the March 2018 full City Council meeting at which the New Orleans Power Station was approved, both the approval of the Committee and the approval of the full City Council were void. The City Council and Entergy New Orleans have each filed a suspensive appeal of the open meetings law ruling. A suspensive appeal suspends the effect of the judgment in the open meetings law proceeding while the appeal is being taken. The petitioners sought in the state appellate court, and then at the Louisiana Supreme Court, to terminate the suspension of the effect of the judgment, but both courts declined to do so. Appellate briefing on the merits both in the open meetings law appeal and in the judicial review appeal is scheduled to begin in November 2019. The New Orleans Power Station related settlement that was approved by the full City Council in February 2019 and that allowed Entergy New Orleans to move forward with the construction of the New Orleans Power Station was not affected by the state court judge’s open meetings ruling. Construction of the plant is underway and continuing.

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Renewables

As discussed in the Form 10-K, in July 2018, Entergy New Orleans filed an application with the City Council requesting approval of three utility-scale solar projects totaling 90 MW. In December 2018 the City Council advisors requested that Entergy New Orleans pursue alternative deal structures for the Washington Parish project and attempt to reduce costs for the 20 MW Orleans Parish project. As a result of settlement discussions, in March 2019, Entergy New Orleans revised its application to convert the build-own transfer acquisition of the 50 MW facility in Washington Parish to a power purchase agreement. In June 2019 the parties to the proceeding executed a stipulated settlement term sheet, which recommends that the City Council approve Entergy New Orleans’s revised application as to all three projects. In July 2019 the City Council approved the stipulated settlement.

State and Local Rate Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – State and Local Rate Regulation” in the Form 10-K for a discussion of state and local rate regulation. The following is an update to that discussion.

Retail Rates

See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting.

Reliability Investigation

In August 2017 the City Council established a docket to investigate the reliability of the Entergy New Orleans distribution system and to consider implementing certain reliability standards and possible financial penalties for not meeting any such standards. In April 2018 the City Council adopted a resolution directing Entergy New Orleans to demonstrate that it has been prudent in the management and maintenance of the reliability of its distribution system. The resolution also called for Entergy New Orleans to file a revised reliability plan addressing the current state of its distribution system and proposing remedial measures for increasing reliability. In June 2018, Entergy New Orleans filed its response to the City Council’s resolution regarding the prudence of its management and maintenance of the reliability of its distribution system.  In July 2018, Entergy New Orleans filed its revised reliability plan discussing the various reliability programs that it uses to improve distribution system reliability and discussing generally the positive effect that advanced meter deployment and grid modernization can have on future reliability.  Entergy New Orleans retained a national consulting firm with expertise in distribution system reliability to conduct a review of Entergy New Orleans’s distribution system reliability-related practices and procedures and to provide recommendations for improving distribution system reliability. The report was filed with the City Council in October 2018. The City Council also approved a resolution that opens a prudence investigation into whether Entergy New Orleans was imprudent for not acting sooner to address outages in New Orleans and whether fines should be imposed. In January 2019, Entergy New Orleans filed testimony in response to the prudence investigation and asserting that it had been prudent in managing

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system reliability. In April 2019 the City Council advisors filed comments and testimony asserting that Entergy New Orleans did not act prudently in maintaining and improving its distribution system reliability in recent years and recommending that a financial penalty in the range of $1.5 million to $2 million should be assessed.  Entergy New Orleans disagrees with the recommendation and submitted rebuttal testimony and rebuttal comments in June 2019. In October 2019 the City Council’s Utility Committee passed a resolution recommending that the City Council fines Entergy New Orleans $1 million for alleged imprudence in the maintenance of its distribution system. The City Council is expected to consider the resolution at its November 7, 2019 meeting.

Renewable Portfolio Standard Rulemaking

In March 2019 the City Council initiated a rulemaking proceeding to consider whether to establish a renewable portfolio standard. The rulemaking will consider, among other issues, whether to adopt a renewable portfolio standard, whether such standard should be voluntary or mandatory, what kinds of technologies should qualify for inclusion in the rules, what level, if any, of renewable generation should be required, and whether penalties are an appropriate component of the proposed rules. Parties to the proceeding submitted initial comments in June 2019 and reply comments in July 2019. Entergy New Orleans recommends that the City Council adopt a voluntary clean energy standard of 70% of generation being clean energy by 2030, as so defined, which, in addition to renewable generation, would include nuclear, beneficial electrification, and demand-side management as compliant technologies. Several other industry leaders, academic researchers, and environmental advocates filed comments also supporting a clean energy standard. Other parties, including many representatives of the solar and wind industry, are recommending mandatory, renewables-only requirements of up to 100% renewable resources by 2040. In September 2019 the City Council advisors issued a report and recommendations, which also put forth three alternative rules for comment from the parties. Comments were submitted in October 2019 with replies to be filed in November 2019.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for further discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in Entergy New Orleans’s accounting for utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$176,738				$184,164				$464,773				$499,584
Natural gas		17,466				16,018				68,418				67,319
TOTAL		194,204				200,182				533,191				566,903
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		27,013				54,754				84,963				93,859
Purchased power		68,091				57,828				195,721				214,773
Other operation and maintenance		32,755				30,593				95,305				87,312
Taxes other than income taxes		15,142				15,551				41,819				43,534
Depreciation and amortization		14,756				14,059				43,146				41,756
Other regulatory charges - net		7,571				5,853				9,716				18,313
TOTAL		165,328				178,638				470,670				499,547
OPERATING INCOME		28,876				21,544				62,521				67,356
OTHER INCOME
Allowance for equity funds used during construction		2,793				1,694				7,769				3,762
Interest and investment income		109				30				352				330
Miscellaneous - net		(1,019		)		(660		)		(3,467		)		(2,401		)
TOTAL		1,883				1,064				4,654				1,691
INTEREST EXPENSE
Interest expense		6,046				5,388				18,001				15,936
Allowance for borrowed funds used during construction		(1,115		)		(626		)		(3,102		)		(1,390		)
TOTAL		4,931				4,762				14,899				14,546
INCOME BEFORE INCOME TAXES		25,828				17,846				52,276				54,501
Income taxes		920				(3,561		)		5,342				3,943
NET INCOME			$24,908				$21,407				$46,934				$50,558
See Notes to Financial Statements.

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CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$46,934				$50,558
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		43,146				41,756
Deferred income taxes, investment tax credits, and non-current taxes accrued		20,427				25,605
Changes in assets and liabilities:
Receivables		(14,741		)		(15,310		)
Fuel inventory		(374		)		495
Accounts payable		(11,654		)		8,868
Prepaid taxes and taxes accrued		242				(8,743		)
Interest accrued		14				564
Deferred fuel costs		8,328				(59		)
Other working capital accounts		(8,737		)		(5,062		)
Provisions for estimated losses		1,423				417
Other regulatory assets		(14,435		)		19,068
Other regulatory liabilities		(15,371		)		(5,353		)
Pension and other postretirement liabilities		(5,784		)		(12,956		)
Other assets and liabilities		28,015				479
Net cash flow provided by operating activities		77,433				100,327
INVESTING ACTIVITIES
Construction expenditures		(162,177		)		(142,585		)
Allowance for equity funds used during construction		7,769				3,762
Changes in money pool receivable - net		22,016				10,607
Receipts from storm reserve escrow account		—				3
Payments to storm reserve escrow account		(1,382		)		(905		)
Changes in securitization account		(3,043		)		(4,115		)
Net cash flow used in investing activities		(136,817		)		(133,233		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		—				59,590
Retirement of long-term debt		(5,420		)		(5,342		)
Change in money pool payable - net		46,318				—
Distributions paid:
Common equity		—				(23,750		)
Other		(1,165		)		2,587
Net cash flow provided by financing activities		39,733				33,085
Net increase (decrease) in cash and cash equivalents		(19,651		)		179
Cash and cash equivalents at beginning of period		19,677				32,741
Cash and cash equivalents at end of period			$26				$32,920
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized			$17,211				$14,584
Income taxes			($4,899	)			$—
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents
Cash			$26				$26
Temporary cash investments		—				19,651
Total cash and cash equivalents		26				19,677
Securitization recovery trust account		5,268				2,224
Accounts receivable:
Customer		57,173				43,890
Allowance for doubtful accounts		(3,116		)		(3,222		)
Associated companies		2,541				27,938
Other		4,954				4,090
Accrued unbilled revenues		22,776				18,907
Total accounts receivable		84,328				91,603
Fuel inventory - at average cost		1,907				1,533
Materials and supplies - at average cost		12,865				12,133
Prepayments and other		10,655				6,905
TOTAL		115,049				134,075
OTHER PROPERTY AND INVESTMENTS
Non-utility property at cost (less accumulated depreciation)		1,016				1,016
Storm reserve escrow account		82,236				80,853
TOTAL		83,252				81,869
UTILITY PLANT
Electric		1,430,352				1,364,091
Natural gas		302,801				284,728
Construction work in progress		196,842				146,668
TOTAL UTILITY PLANT		1,929,995				1,795,487
Less - accumulated depreciation and amortization		699,525				670,135
UTILITY PLANT - NET		1,230,470				1,125,352
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Deferred fuel costs		4,080				4,080
Other regulatory assets (includes securitization property of $52,085 as of September 30, 2019 and $60,453 as of December 31, 2018)		244,231				229,796
Other		1,749				1,416
TOTAL		250,060				235,292
TOTAL ASSETS			$1,678,831				$1,576,588
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Payable due to associated company			$1,979				$1,979
Accounts payable:
Associated companies		85,485				43,416
Other		37,394				36,686
Customer deposits		28,515				28,667
Taxes accrued		4,310				4,068
Interest accrued		6,380				6,366
Deferred fuel costs		9,616				1,288
Current portion of unprotected excess accumulated deferred income taxes		15,439				25,301
Other		7,182				9,521
TOTAL CURRENT LIABILITIES		196,300				157,292
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		349,600				323,595
Accumulated deferred investment tax credits		2,153				2,219
Regulatory liability for income taxes - net		52,705				60,249
Asset retirement cost liabilities		3,463				3,291
Accumulated provisions		88,017				86,594
Long-term debt (includes securitization bonds of $58,382 as of September 30, 2019 and $63,620 as of December 31, 2018)		462,273				467,358
Long-term payable due to associated company		14,367				14,367
Other		18,069				16,673
TOTAL NON-CURRENT LIABILITIES		990,647				974,346
Commitments and Contingencies
EQUITY
Member's equity		491,884				444,950
TOTAL		491,884				444,950
TOTAL LIABILITIES AND EQUITY			$1,678,831				$1,576,588
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Member’s Equity
	(In Thousands)
Balance at December 31, 2017		$415,548
Net income	10,882
Common equity distributions	(6,250		)
Balance at March 31, 2018	420,180
Net income	18,269
Common equity distributions	(8,250		)
Balance at June 30, 2018	430,199
Net income	21,407
Common equity distributions	(9,250		)
Balance at September 30, 2018		$442,356
Balance at December 31, 2018		$444,950
Net income	9,023
Balance at March 31, 2019	453,973
Net income	13,003
Balance at June 30, 2019	466,976
Net income	24,908
Balance at September 30, 2019		$491,884
See Notes to Financial Statements.

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ENTERGY NEW ORLEANS, LLC AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$82				$86				($4	)		(5	)
Commercial		56				62				(6		)		(10	)
Industrial		9				10				(1		)		(10	)
Governmental		19				20				(1		)		(5	)
Total billed retail		166				178				(12		)		(7	)
Sales for resale:
Non-associated companies		7				5				2				40
Other		4				1				3				300
Total			$177				$184				($7	)		(4	)
Billed Electric Energy Sales (GWh):
Residential		793				779				14				2
Commercial		645				660				(15		)		(2	)
Industrial		124				128				(4		)		(3	)
Governmental		228				225				3				1
Total retail		1,790				1,792				(2		)		—
Sales for resale:
Non-associated companies		364				281				83				30
Total		2,154				2,073				81				4
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$192				$209				($17	)		(8	)
Commercial		156				171				(15		)		(9	)
Industrial		24				26				(2		)		(8	)
Governmental		54				57				(3		)		(5	)
Total billed retail		426				463				(37		)		(8	)
Sales for resale:
Non-associated companies		26				24				2				8
Other		13				12				1				8
Total			$465				$499				($34	)		(7	)
Billed Electric Energy Sales (GWh):
Residential		1,821				1,846				(25		)		(1	)
Commercial		1,686				1,711				(25		)		(1	)
Industrial		326				338				(12		)		(4	)
Governmental		607				591				16				3
Total retail		4,440				4,486				(46		)		(1	)
Sales for resale:
Non-associated companies		1,353				1,218				135				11
Total		5,793				5,704				89				2

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ENTERGY TEXAS, INC. AND SUBSIDIARIES

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

Net Income

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $7.4 million primarily due to higher retail electric price, higher volume/weather, and higher other income, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income increased $19.5 million primarily due to higher retail electric price, higher volume/weather, higher other income, lower interest expense, and a lower effective income tax rate, partially offset by higher other operation and maintenance expenses and higher depreciation and amortization expenses.

Operating Revenues

Third Quarter 2019 Compared to Third Quarter 2018

Following is an analysis of the change in operating revenues comparing the third quarter 2019 to the third quarter 2018:

	Amount
	(In Millions)
2018 operating revenues		$477.2
Fuel, rider, and other revenues that do not significantly affect net income	(29.0		)
Return of unprotected excess accumulated deferred income taxes to customers	(30.9		)
Volume/weather	8.6
Retail electric price	17.0
2019 operating revenues		$442.9

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a rider effective October 2018. There is no effect on net income as the reduction in operating revenues is offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase in industrial demand charges and an increase in usage during the unbilled sales period.

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Management's Financial Discussion and Analysis

The retail electric price variance is primarily due to a base rate increase effective October 2018 as approved by the PUCT. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case filing.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Following is an analysis of the change in operating revenues comparing the nine months ended September 30, 2019 to the nine months ended September 30, 2018:

	Amount
	(In Millions)
2018 operating revenues		$1,229.7
Fuel, rider, and other revenues that do not significantly affect net income	(52.1		)
Return of unprotected excess accumulated deferred income taxes to customers	(73.5		)
Volume/weather	9.3
Retail electric price	33.5
2019 operating revenues		$1,146.9

Entergy Texas’s results include revenues from rate mechanisms designed to recover fuel, purchased power, and other costs such that the revenues and expenses associated with these items generally offset and do not affect net income. “Fuel, rider, and other revenues that do not significantly affect net income” includes the revenue variance associated with these items.

The return of unprotected excess accumulated deferred income taxes to customers resulted from the return of unprotected excess accumulated deferred income taxes through a rider effective October 2018. There is no effect on net income as the reduction in operating revenues is offset by a reduction in income tax expense. See Note 2 to the financial statements in the Form 10-K for further discussion of regulatory activity regarding the Tax Cuts and Jobs Act.

The volume/weather variance is primarily due to an increase in usage during the unbilled sales period.

The retail electric price variance is primarily due to a base rate increase effective October 2018 as approved by the PUCT. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case filing.

Other Income Statement Variances

Third Quarter 2019 Compared to Third Quarter 2018

Other operation and maintenance expenses increased primarily due to:

•	a loss on the sale of assets in 2019 of $0.2 million as compared to a gain on the sale of assets of $2.1 million in 2018;

•	an increase of $1.7 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2019 as compared to 2018;

•	an increase of $1.6 million in costs related to customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $1.4 million in vegetation maintenance costs;

•	an increase of $1.3 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance; and

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•	an increase of $1.2 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services.

Depreciation and amortization expenses increased primarily as a result of new depreciation rates established in the settlement of the 2018 base rate case and additions to plant in service.

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the Montgomery County Power Station project.

Interest expense decreased primarily due to an increase in the allowance for borrowed funds used during construction due to higher construction work in progress in 2019, including the Montgomery County Power Station project.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Other operation and maintenance expenses increased primarily due to:

•	an increase of $4.7 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2019 as compared to the same period in 2018;

•	an increase of $4.0 million in costs related to customer initiatives to explore new technologies and services and continuous customer improvement;

•	an increase of $3.2 million in information technology costs primarily due to higher costs related to improved infrastructure, enhanced security, and upgrades and maintenance;

•	an increase of $3.2 million in distribution operations and asset management costs primarily due to higher advanced metering customer education costs and higher contract costs for meter reading services; and

•	a loss on the sale of assets in 2019 of $0.3 million as compared to a gain on the sale of assets of $2.1 million in 2018.

Depreciation and amortization expenses increased primarily as a result of new depreciation rates established in the settlement of the 2018 base rate case and additions to plant in service.

Other income increased primarily due to an increase in the allowance for equity funds used during construction due to higher construction work in progress in 2019, including the Montgomery County Power Station project.

Interest expense decreased primarily due to an increase in the allowance for borrowed funds used during construction due to higher construction work in progress in 2019, including the Montgomery County Power Station project.

Income Taxes

The effective income tax rates were (22.6%) for the third quarter 2019 and (48.1%) for the nine months ended September 30, 2019. The differences in the effective income tax rates for the third quarter 2019 and the nine months ended September 30, 2019 versus the federal statutory rate of 21% were primarily due to the amortization of excess accumulated deferred income taxes and book and tax differences related to the allowance for equity funds used during construction. See Note 10 to the financial statements herein and Notes 2 and 3 to the financial statements in the Form 10-K for a discussion of the effects and regulatory activity regarding the Tax Cuts and Jobs Act.

The effective income tax rate was 20.4% for the third quarter 2018. The difference in the effective income tax rate for the third quarter 2018 versus the federal statutory rate of 21% was primarily due to book and tax differences related to the allowance for equity funds used during construction and certain book and tax differences related to utility plant items.

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Management's Financial Discussion and Analysis

The effective income tax rate was 21.1% for the nine months ended September 30, 2018. The difference in the effective income tax rate for the nine months ended September 30, 2018 versus the federal statutory rate of 21% was primarily due to the write-off of a stock-based compensation deferred tax asset in 2018 and the provision for uncertain tax positions, partially offset by book and tax differences related to the allowance for equity funds used during construction and certain book and tax differences related to utility plant items.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$56				$115,513
Cash flow provided by (used in):
Operating activities	174,881				197,677
Investing activities	(603,077		)		(233,850		)
Financing activities	520,418				(58,843		)
Net increase (decrease) in cash and cash equivalents	92,222				(95,016		)
Cash and cash equivalents at end of period		$92,278				$20,497

Operating Activities

Net cash flow provided by operating activities decreased $22.8 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to the return of unprotected excess accumulated deferred income taxes to customers. The decrease was partially offset by:

•	the timing of recovery of fuel and purchased power costs;

•	the timing of collection of receivables from customers; and

•	a decrease of $8.1 million in pension contributions in 2019. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

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Management's Financial Discussion and Analysis

Investing Activities

Net cash flow used in investing activities increased $369.2 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to:

•	an increase of $197.5 million in fossil-fueled generation construction expenditures primarily due to increased spending on the Montgomery County Power Station;

•	an increase of $100.9 million in transmission construction expenditures primarily due to a higher scope of work performed in 2019 as compared to 2018; and

•	money pool activity.

Increases in Entergy Texas’s receivable from the money pool are a use of cash flow, and Entergy Texas’s receivable from the money pool increased by $8.3 million for the nine months ended September 30, 2019 compared to decreasing $43.7 million for the nine months ended September 30, 2018. The money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ need for external short-term borrowings.

Financing Activities

Entergy Texas’s financing activities provided $520.4 million of cash for the nine months ended September 30, 2019 compared to using $58.8 million of cash for the nine months ended September 30, 2018 primarily due to:

•	the issuance of $300 million of 4.0% Series mortgage bonds and $400 million of 4.5% Series mortgage bonds in January 2019;

•	the issuance of $300 million of 3.55% Series mortgage bonds in September 2019;

•	a capital contribution of $87.5 million received from Entergy Corporation in August 2019 in anticipation of upcoming construction expenditures, including Montgomery County Power Station; and

•	the issuance of $35 million aggregate liquidation value 5.375% Series A preferred stock in September 2019.

The increase was partially offset by the repayment, at maturity, of $500 million of 7.125% Series mortgage bonds in February 2019 and money pool activity. See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt. See Note 3 to the financial statements herein for more details on the issuance of preferred stock.

Decreases in Entergy Texas’s payable to the money pool are a use of cash flow, and Entergy Texas’s payable to the money pool decreased by $22.4 million for the nine months ended September 30, 2019.

Capital Structure

Entergy Texas’s debt to capital ratio is shown in the following table. The increase in the debt to capital ratio for Entergy Texas is primarily due to the net issuance of $500 million of mortgage bonds in 2019, partially offset by an increase in equity.

	September 30, 2019			December 31, 2018
Debt to capital	53.7	%		51.6	%
Effect of excluding the securitization bonds	(3.0	%)		(5.2	%)
Debt to capital, excluding securitization bonds (a)	50.7	%		46.4	%
Effect of subtracting cash	(1.4	%)		—	%
Net debt to net capital, excluding securitization bonds (a)	49.3	%		46.4	%

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Texas.

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Management's Financial Discussion and Analysis

Net debt consists of debt less cash and cash equivalents.  Debt consists of financing lease obligations and long-term debt, including the currently maturing portion.  Capital consists of debt and equity.  Net capital consists of capital less cash and cash equivalents.  Entergy Texas uses the debt to capital ratios excluding securitization bonds in analyzing its financial condition and believes they provide useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because the securitization bonds are non-recourse to Entergy Texas, as more fully described in Note 5 to the financial statements in the Form 10-K.  Entergy Texas also uses the net debt to net capital ratio excluding securitization bonds in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating Entergy Texas’s financial condition because net debt indicates Entergy Texas’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of Entergy Texas’s uses and sources of capital. Following are updates to information provided in the Form 10-K.

Entergy Texas is developing its capital investment plan for 2020 through 2022 and currently anticipates making $1.8 billion in capital investments during that period.  The preliminary estimate includes specific investments such as the Montgomery County Power Station; transmission projects to enhance reliability, reduce congestion, and enable economic growth; distribution spending to enhance reliability and improve service to customers, including advanced meters and related investments; system improvements; software and security; and other investments. Estimated capital expenditures are subject to periodic review and modification and may vary based on the ongoing effects of regulatory constraints and requirements, environmental compliance, business opportunities, market volatility, economic trends, business restructuring, changes in project plans, and the ability to access capital.

Entergy Texas’s receivables from or (payables to) the money pool were as follows:

September 30, 2019		December 31, 2018		September 30, 2018		December 31, 2017
(In Thousands)
$8,299		($22,389)		$1,217		$44,903

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

Entergy Texas has a credit facility in the amount of $150 million scheduled to expire in September 2024.  The credit facility includes fronting commitments for the issuance of letters of credit against $30 million of the borrowing capacity of the facility. As of September 30, 2019, there were no cash borrowings and $1.3 million of letters of credit outstanding under the credit facility.  In addition, Entergy Texas is a party to an uncommitted letter of credit facility as a means to post collateral to support its obligations to MISO. As of September 30, 2019, a $26.2 million letter of credit was outstanding under Entergy Texas’s uncommitted letter of credit facility. See Note 4 to the financial statements herein for additional discussion of the credit facilities.

State and Local Rate Regulation and Fuel-Cost Recovery

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - State and Local Rate Regulation and Fuel-Cost Recovery” in the Form 10-K for a discussion of state and local rate regulation and fuel-cost recovery. The following are updates to that discussion.

Fuel and Purchased Power Cost Recovery

In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately

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Management's Financial Discussion and Analysis

$1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending.

Base Rate Case

In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT.

  

Distribution Cost Recovery Factor (DCRF) Rider

In March 2019, Entergy Texas filed with the PUCT a request to set a new DCRF rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application.

Transmission Cost Recovery Factor (TCRF) Rider

In December 2018, Entergy Texas filed with the PUCT a request to set a new TCRF rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT.

In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending.

Federal Regulation

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Federal Regulation” in the Form 10-K for a discussion of federal regulation. 

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Industrial and Commercial Customers

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Industrial and Commercial Customers” in the Form 10-K for a discussion of industrial and commercial customers.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Nuclear Matters” in the Form 10-K for discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$442,877				$477,231				$1,146,931				$1,229,657
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		64,211				79,130				129,285				154,925
Purchased power		151,965				153,673				463,966				463,933
Other operation and maintenance		69,937				58,795				190,989				171,317
Taxes other than income taxes		20,870				20,752				60,773				61,461
Depreciation and amortization		38,722				31,365				113,071				93,272
Other regulatory charges - net		27,662				33,550				66,574				85,064
TOTAL		373,367				377,265				1,024,658				1,029,972
OPERATING INCOME		69,510				99,966				122,273				199,685
OTHER INCOME
Allowance for equity funds used during construction		7,454				2,222				18,948				5,716
Interest and investment income		486				601				2,542				1,698
Miscellaneous - net		115				468				980				(154		)
TOTAL		8,055				3,291				22,470				7,260
INTEREST EXPENSE
Interest expense		21,379				21,760				63,992				65,646
Allowance for borrowed funds used during construction		(3,534		)		(1,253		)		(9,370		)		(3,224		)
TOTAL		17,845				20,507				54,622				62,422
INCOME BEFORE INCOME TAXES		59,720				82,750				90,121				144,523
Income taxes		(13,504		)		16,904				(43,381		)		30,538
NET INCOME		73,224				65,846				133,502				113,985
Preferred dividend requirements		110				—				110				—
EARNINGS APPLICABLE TO COMMON STOCK			$73,114				$65,846				$133,392				$113,985
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$133,502				$113,985
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation and amortization		113,071				93,272
Deferred income taxes, investment tax credits, and non-current taxes accrued		21,898				640
Changes in assets and liabilities:
Receivables		21,578				(40,287		)
Fuel inventory		(1,476		)		1,045
Accounts payable		(58,792		)		(12,864		)
Taxes accrued		3,545				24,476
Interest accrued		(11,478		)		(6,084		)
Deferred fuel costs		(6,588		)		(33,734		)
Other working capital accounts		(13,740		)		891
Provisions for estimated losses		(3,470		)		1,006
Other regulatory assets		63,793				64,311
Other regulatory liabilities		(83,674		)		15,313
Pension and other postretirement liabilities		(7,209		)		(20,999		)
Other assets and liabilities		3,921				(3,294		)
Net cash flow provided by operating activities		174,881				197,677
INVESTING ACTIVITIES
Construction expenditures		(622,342		)		(291,118		)
Allowance for equity funds used during construction		19,029				5,820
Proceeds from sale of assets		—				3,753
Changes in money pool receivable - net		(8,299		)		43,686
Changes in securitization account		8,535				4,009
Net cash flow used in investing activities		(603,077		)		(233,850		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		986,477				—
Retirement of long-term debt		(563,246		)		(60,500		)
Capital contribution from parent		87,500				—
Proceeds from issuance of preferred stock		33,486				—
Change in money pool payable - net		(22,389		)		—
Other		(1,410		)		1,657
Net cash flow provided by (used in) financing activities		520,418				(58,843		)
Net increase (decrease) in cash and cash equivalents		92,222				(95,016		)
Cash and cash equivalents at beginning of period		56				115,513
Cash and cash equivalents at end of period			$92,278				$20,497
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized			$73,752				$69,669
Income taxes			$2,292				($624	)
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$25				$26
Temporary cash investments		92,253				30
Total cash and cash equivalents		92,278				56
Securitization recovery trust account		31,649				40,185
Accounts receivable:
Customer		88,557				69,714
Allowance for doubtful accounts		(680		)		(461		)
Associated companies		24,124				64,441
Other		6,770				12,275
Accrued unbilled revenues		65,207				51,288
Total accounts receivable		183,978				197,257
Fuel inventory - at average cost		44,143				42,667
Materials and supplies - at average cost		43,774				41,883
Prepayments and other		22,266				15,903
TOTAL		418,088				337,951
OTHER PROPERTY AND INVESTMENTS
Investments in affiliates - at equity		413				448
Non-utility property - at cost (less accumulated depreciation)		376				376
Other		19,863				19,218
TOTAL		20,652				20,042
UTILITY PLANT
Electric		5,028,850				4,773,984
Construction work in progress		663,465				325,193
TOTAL UTILITY PLANT		5,692,315				5,099,177
Less - accumulated depreciation and amortization		1,745,046				1,684,569
UTILITY PLANT - NET		3,947,269				3,414,608
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets (includes securitization property of $178,558 as of September 30, 2019 and $236,336 as of December 31, 2018)		534,255				598,048
Other		32,861				29,371
TOTAL		567,116				627,419
TOTAL ASSETS			$4,953,125				$4,400,020
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt			$—				$500,000
Accounts payable:
Associated companies		45,090				119,371
Other		169,788				150,679
Customer deposits		40,304				43,387
Taxes accrued		57,058				53,513
Interest accrued		12,877				24,355
Current portion of unprotected excess accumulated deferred income taxes		35,213				87,627
Deferred fuel costs		13,109				19,697
Other		8,786				6,353
TOTAL		382,225				1,004,982
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		581,310				552,535
Accumulated deferred investment tax credits		10,713				11,176
Regulatory liability for income taxes - net		236,463				264,623
Other regulatory liabilities		44,784				47,884
Asset retirement cost liabilities		7,526				7,222
Accumulated provisions		10,386				13,856
Long-term debt (includes securitization bonds of $220,625 as of September 30, 2019 and $283,659 as of December 31, 2018)		1,938,303				1,013,735
Other		64,635				61,605
TOTAL		2,894,120				1,972,636
Commitments and Contingencies
EQUITY
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding 46,525,000 shares in 2019 and 2018		49,452				49,452
Paid-in capital		682,980				596,994
Retained earnings		909,348				775,956
Total common shareholder's equity		1,641,780				1,422,402
Preferred stock without sinking fund		35,000				—
TOTAL		1,676,780				1,422,402
TOTAL LIABILITIES AND EQUITY			$4,953,125				$4,400,020
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
					Common Equity
	Preferred Stock				Common Stock				Paid-in Capital				Retained Earnings				Total
					(In Thousands)
Balance at December 31, 2017		$—				$49,452				$596,994				$613,721				$1,260,167
Net income	—				—				—				17,350				17,350
Balance at March 31, 2018	—				49,452				596,994				631,071				1,277,517
Net income	—				—				—				30,789				30,789
Balance at June 30, 2018	—				49,452				596,994				661,860				1,308,306
Net income	—				—				—				65,846				65,846
Balance at September 30, 2018		$—				$49,452				$596,994				$727,706				$1,374,152
Balance at December 31, 2018		$—				$49,452				$596,994				$775,956				$1,422,402
Net income	—				—				—				21,342				21,342
Balance at March 31, 2019	—				49,452				596,994				797,298				1,443,744
Net income	—				—				—				38,936				38,936
Balance at June 30, 2019	—				49,452				596,994				836,234				1,482,680
Net income	—				—				—				73,224				73,224
Capital contribution from parent	—				—				87,500				—				87,500
Preferred stock issuance	35,000				—				(1,514		)		—				33,486
Preferred stock dividends	—				—				—				(110		)		(110		)
Balance at September 30, 2019		$35,000				$49,452				$682,980				$909,348				$1,676,780
See Notes to Financial Statements.

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ENTERGY TEXAS, INC. AND SUBSIDIARIES
SELECTED OPERATING RESULTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$216				$224				($8	)		(4	)
Commercial		95				111				(16		)		(14	)
Industrial		101				109				(8		)		(7	)
Governmental		5				7				(2		)		(29	)
Total billed retail		417				451				(34		)		(8	)
Sales for resale:
Associated companies		14				18				(4		)		(22	)
Non-associated companies		2				5				(3		)		(60	)
Other		10				3				7				233
Total			$443				$477				($34	)		(7	)
Billed Electric Energy Sales (GWh):
Residential		1,994				2,003				(9		)		—
Commercial		1,365				1,392				(27		)		(2	)
Industrial		2,219				2,156				63				3
Governmental		69				78				(9		)		(12	)
Total retail		5,647				5,629				18				—
Sales for resale:
Associated companies		372				446				(74		)		(17	)
Non-associated companies		148				208				(60		)		(29	)
Total		6,167				6,283				(116		)		(2	)
		Nine Months Ended								Increase/
		2019				2018				(Decrease)				%
		(Dollars In Millions)
Electric Operating Revenues:
Residential			$510				$523				($13	)		(2	)
Commercial		255				291				(36		)		(12	)
Industrial		279				295				(16		)		(5	)
Governmental		16				19				(3		)		(16	)
Total billed retail		1,060				1,128				(68		)		(6	)
Sales for resale:
Associated companies		42				46				(4		)		(9	)
Non-associated companies		6				26				(20		)		(77	)
Other		39				30				9				30
Total			$1,147				$1,230				($83	)		(7	)
Billed Electric Energy Sales (GWh):
Residential		4,662				4,789				(127		)		(3	)
Commercial		3,533				3,610				(77		)		(2	)
Industrial		5,999				6,024				(25		)		—
Governmental		194				220				(26		)		(12	)
Total retail		14,388				14,643				(255		)		(2	)
Sales for resale:
Associated companies		1,157				1,199				(42		)		(4	)
Non-associated companies		300				725				(425		)		(59	)
Total		15,845				16,567				(722		)		(4	)

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SYSTEM ENERGY RESOURCES, INC.

MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS

Results of Operations

System Energy’s principal asset currently consists of an ownership interest and a leasehold interest in Grand Gulf.  The capacity and energy from its 90% interest is sold under the Unit Power Sales Agreement to its only four customers, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.  System Energy’s operating revenues are derived from the allocation of the capacity, energy, and related costs associated with its 90% interest in Grand Gulf pursuant to the Unit Power Sales Agreement.  Payments under the Unit Power Sales Agreement are System Energy’s only source of operating revenues.

Third Quarter 2019 Compared to Third Quarter 2018

Net income increased $2.1 million primarily due to a lower effective income tax rate.

Nine Months Ended September 30, 2019 Compared to Nine Months Ended September 30, 2018

Net income increased $4.4 million primarily due to the increase in operating revenues resulting from changes in rate base as compared to the prior year and a lower effective income tax rate.

Income Tax Legislation

See the “Income Tax Legislation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K for a discussion of the Tax Cuts and Jobs Act, the federal income tax legislation enacted in December 2017. Note 3 to the financial statements in the Form 10-K contains additional discussion of the effect of the Tax Act on 2018 results of operations and financial position, the provisions of the Tax Act, and the uncertainties associated with accounting for the Tax Act, and Note 10 to the financial statements herein contains updates to that discussion. Note 2 to the financial statements in the Form 10-K contains a discussion of the regulatory proceedings that have considered the effects of the Tax Act.

Liquidity and Capital Resources

Cash Flow

Cash flows for the nine months ended September 30, 2019 and 2018 were as follows:

	2019				2018
	(In Thousands)
Cash and cash equivalents at beginning of period		$95,685				$287,187
Cash flow provided by (used in):
Operating activities	224,675				131,556
Investing activities	15,896				(169,573		)
Financing activities	(171,931		)		5,371
Net increase (decrease) in cash and cash equivalents	68,640				(32,646		)
Cash and cash equivalents at end of period		$164,325				$254,541

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Management's Financial Discussion and Analysis

Operating Activities

Net cash flow provided by operating activities increased by $93.1 million for the nine months ended September 30, 2019 compared to the nine months ended September 30, 2018 primarily due to a decrease in spending of $47.9 million on nuclear refueling outages in 2019 as compared to the same period in 2018 and the return of the unprotected excess accumulated deferred income taxes in 2018.

Investing Activities

System Energy’s investing activities provided $15.9 million of cash for the nine months ended September 30, 2019 compared to using $169.6 million of cash for the nine months ended September 30, 2018 primarily due to the following activity:

•	an increase of $121.8 million as a result of fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

•	a decrease of $75.5 million in nuclear construction expenditures as a result of spending in 2018 on Grand Gulf outage projects.

Financing Activities

System Energy’s financing activities used $171.9 million of cash for the nine months ended September 30, 2019 compared to providing $5.4 million of cash for the nine months ended September 30, 2018 primarily due to the following activity:

•	the issuance in March 2018 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity;

•	an increase of $46 million in common stock dividends and distributions in 2019. Common stock dividends and distributions were lower in 2018 in anticipation of the excess accumulated deferred income taxes being returned to customers as a result of the Tax Cuts and Jobs Act;

•	an increase of $48 million in net repayments of long-term borrowings in 2019 on the nuclear fuel company variable interest entity’s credit facility; and

•	net repayments of short-term borrowings of $17.8 million in 2018 on the nuclear fuel company variable interest entity’s credit facility.

In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. See Note 4 to the financial statements herein and Note 5 to the financial statements in the Form 10-K for more details on long-term debt.

Capital Structure

System Energy’s debt to capital ratio is shown in the following table. The decrease in the debt to capital ratio is primarily due to a decrease in retained earnings.

	September 30, 2019			December 31, 2018
Debt to capital	44.9	%		46.1	%
Effect of subtracting cash	(8.2	%)		(4.0	%)
Net debt to net capital	36.7	%		42.1	%

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Management's Financial Discussion and Analysis

Net debt consists of debt less cash and cash equivalents.  Debt consists of short-term borrowings and long-term debt, including the currently maturing portion.  Capital consists of debt and common equity.  Net capital consists of capital less cash and cash equivalents.  System Energy uses the debt to capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition.  System Energy uses the net debt to net capital ratio in analyzing its financial condition and believes it provides useful information to its investors and creditors in evaluating System Energy’s financial condition because net debt indicates System Energy’s outstanding debt position that could not be readily satisfied by cash and cash equivalents on hand.

Uses and Sources of Capital

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Liquidity and Capital Resources” in the Form 10-K for a discussion of System Energy’s uses and sources of capital. Following are updates to the information provided in the Form 10-K.

System Energy is developing its capital investment plan for 2020 through 2022 and currently anticipates making $435 million in capital investments during that period. The preliminary estimate includes amounts associated with specific investments and initiatives such as investments in Grand Gulf.

System Energy’s receivables from the money pool were as follows:

September 30, 2019		December 31, 2018		September 30, 2018		December 31, 2017
(In Thousands)
$14,775		$107,122		$16,365		$111,667

See Note 4 to the financial statements in the Form 10-K for a description of the money pool.

The System Energy nuclear fuel company variable interest entity has a credit facility in the amount of $120 million scheduled to expire in September 2021. As of September 30, 2019, $53.6 million in loans were outstanding under the System Energy nuclear fuel company variable interest entity credit facility. See Note 4 to the financial statements herein for additional discussion of the variable interest entity credit facility.

Capital Funds Agreement

Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.

Federal Regulation

See the “Rate, Cost-recovery, and Other Regulation - Federal Regulation” section of Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis in the Form 10-K and Note 2 to the financial statements herein and in the Form 10-K for a discussion of federal regulation.

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Management's Financial Discussion and Analysis

Complaints Against System Energy

Return on Equity and Capital Structure Complaints

See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding.

In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint).

In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period.

In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding.

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Management's Financial Discussion and Analysis

Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020.

In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for SERI for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommended that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC proposed that System Energy’s common equity be set based on the median equity ratio of the proxy group for setting the return on equity. The median equity ratio of the proxy group proposed by the APSC and MPSC is 46.75%.

In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt.

In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable.

Grand Gulf Sale-leaseback Renewal Complaint

As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1.

In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019.

In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy

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Management's Financial Discussion and Analysis

argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties.

In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more in depreciation expense for capital additions than it should have. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only.

Nuclear Matters

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of nuclear matters.

Environmental Risks

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Environmental Risks” in the Form 10-K for a discussion of environmental risks.

Critical Accounting Estimates

See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K for a discussion of the estimates and judgments necessary in System Energy’s accounting for nuclear decommissioning costs, utility regulatory accounting, impairment of long-lived assets and trust fund investments, taxation and uncertain tax positions, qualified pension and other postretirement benefits, and other contingencies.

New Accounting Pronouncements

See “New Accounting Pronouncements” section of Note 1 to the financial statements in the Form 10-K for a discussion of new accounting pronouncements.

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SYSTEM ENERGY RESOURCES, INC.
INCOME STATEMENTS
For the Three and Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		Three Months Ended								Nine Months Ended
		2019				2018				2019				2018
		(In Thousands)								(In Thousands)
OPERATING REVENUES
Electric			$145,472				$78,965				$424,585				$339,864
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		23,748				14,484				66,335				44,939
Nuclear refueling outage expenses		8,412				5,906				25,013				12,698
Other operation and maintenance		49,533				48,969				147,283				143,003
Decommissioning		8,976				8,626				26,663				25,624
Taxes other than income taxes		7,120				7,106				21,835				21,069
Depreciation and amortization		26,613				4,355				79,761				71,143
Other regulatory charges (credits) - net		(8,016		)		7,398				(27,059		)		(15,080		)
TOTAL		116,386				96,844				339,831				303,396
OPERATING INCOME (LOSS)		29,086				(17,879		)		84,754				36,468
OTHER INCOME
Allowance for equity funds used during construction		2,251				2,028				5,518				7,032
Interest and investment income		8,215				23,738				21,577				33,567
Miscellaneous - net		(1,300		)		(1,421		)		(4,018		)		(4,391		)
TOTAL		9,166				24,345				23,077				36,208
INTEREST EXPENSE
Interest expense		8,546				9,753				26,467				28,734
Allowance for borrowed funds used during construction		(551		)		(515		)		(1,350		)		(1,783		)
TOTAL		7,995				9,238				25,117				26,951
INCOME (LOSS) BEFORE INCOME TAXES		30,257				(2,772		)		82,714				45,725
Income taxes		5,226				(25,744		)		9,633				(22,942		)
NET INCOME			$25,031				$22,972				$73,081				$68,667
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CASH FLOWS
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
		2019				2018
		(In Thousands)
OPERATING ACTIVITIES
Net income			$73,081				$68,667
Adjustments to reconcile net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		163,069				133,877
Deferred income taxes, investment tax credits, and non-current taxes accrued		(2,426		)		14,159
Changes in assets and liabilities:
Receivables		(7,456		)		20,806
Accounts payable		2,935				22,637
Prepaid taxes and taxes accrued		14,579				(1,017		)
Interest accrued		(1,478		)		2,311
Other working capital accounts		3,411				(52,524		)
Other regulatory assets		(9,121		)		(4,773		)
Other regulatory liabilities		90,118				(36,119		)
Pension and other postretirement liabilities		(5,013		)		(11,629		)
Other assets and liabilities		(97,024		)		(24,839		)
Net cash flow provided by operating activities		224,675				131,556
INVESTING ACTIVITIES
Construction expenditures		(92,228		)		(166,458		)
Allowance for equity funds used during construction		5,518				7,032
Nuclear fuel purchases		(2,046		)		(110,485		)
Proceeds from the sale of nuclear fuel		26,272				12,867
Proceeds from nuclear decommissioning trust fund sales		348,606				357,209
Investment in nuclear decommissioning trust funds		(362,573		)		(365,040		)
Changes in money pool receivable - net		92,347				95,302
Net cash flow provided by (used in) investing activities		15,896				(169,573		)
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt		1,007,775				211,985
Retirement of long-term debt		(1,069,206		)		(124,304		)
Changes in short-term borrowings - net		—				(17,830		)
Common stock dividends and distributions		(110,500		)		(64,480		)
Net cash flow provided by (used in) financing activities		(171,931		)		5,371
Net increase (decrease) in cash and cash equivalents		68,640				(32,646		)
Cash and cash equivalents at beginning of period		95,685				287,187
Cash and cash equivalents at end of period			$164,325				$254,541
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid during the period for:
Interest - net of amount capitalized			$21,052				$10,308
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
ASSETS
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash			$79				$68
Temporary cash investments		164,246				95,617
Total cash and cash equivalents		164,325				95,685
Accounts receivable:
Associated companies		62,740				148,571
Other		6,330				5,390
Total accounts receivable		69,070				153,961
Materials and supplies - at average cost		111,927				97,225
Deferred nuclear refueling outage costs		20,253				44,424
Prepaid taxes		—				5,415
Prepayments and other		9,040				2,985
TOTAL		374,615				399,695
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds		1,002,261				869,543
TOTAL		1,002,261				869,543
UTILITY PLANT
Electric		5,036,030				5,036,116
Construction work in progress		141,858				70,156
Nuclear fuel		158,745				234,889
TOTAL UTILITY PLANT		5,336,633				5,341,161
Less - accumulated depreciation and amortization		3,273,504				3,212,080
UTILITY PLANT - NET		2,063,129				2,129,081
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Other regulatory assets		455,492				446,371
Other		3,759				4,124
TOTAL		459,251				450,495
TOTAL ASSETS			$3,899,256				$3,848,814
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
BALANCE SHEETS
LIABILITIES AND EQUITY
September 30, 2019 and December 31, 2018
(Unaudited)
		2019				2018
		(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt			$10				$6
Accounts payable:
Associated companies		11,475				11,031
Other		61,391				47,565
Taxes accrued		9,164				—
Interest accrued		11,817				13,295
Current portion of unprotected excess accumulated deferred income taxes		—				4,426
Other		2,829				2,832
TOTAL		96,686				79,155
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued		811,875				805,296
Accumulated deferred investment tax credits		37,714				38,673
Regulatory liability for income taxes - net		144,639				158,998
Other regulatory liabilities		490,790				381,887
Decommissioning		922,663				896,000
Pension and other postretirement liabilities		93,626				98,639
Long-term debt		569,991				630,744
Other		31,493				22,224
TOTAL		3,102,791				3,032,461
Commitments and Contingencies
COMMON EQUITY
Common stock, no par value, authorized 1,000,000 shares; issued and outstanding 789,350 shares in 2019 and 2018		601,850				601,850
Retained earnings		97,929				135,348
TOTAL		699,779				737,198
TOTAL LIABILITIES AND EQUITY			$3,899,256				$3,848,814
See Notes to Financial Statements.

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SYSTEM ENERGY RESOURCES, INC.
STATEMENTS OF CHANGES IN COMMON EQUITY
For the Nine Months Ended September 30, 2019 and 2018
(Unaudited)
	Common Equity
	Common Stock				Retained Earnings				Total
	(In Thousands)
Balance at December 31, 2017		$658,350				$52,459				$710,809
Net income	—				22,308				22,308
Common stock dividends and distributions	(56,500		)		(6,740		)		(63,240		)
Balance at March 31, 2018	601,850				68,027				669,877
Net income	—				23,387				23,387
Balance at June 30, 2018	601,850				91,414				693,264
Net income	—				22,972				22,972
Common stock dividends and distributions	—				(1,240		)		(1,240		)
Balance at September 30, 2018		$601,850				$113,146				$714,996
Balance at December 31, 2018		$601,850				$135,348				$737,198
Net income	—				23,578				23,578
Common stock dividends	—				(45,500		)		(45,500		)
Balance at March 31, 2019	601,850				113,426				715,276
Net income	—				24,472				24,472
Common stock dividends	—				(42,500		)		(42,500		)
Balance at June 30, 2019	601,850				95,398				697,248
Net income	—				25,031				25,031
Common stock dividends	—				(22,500		)		(22,500		)
Balance at September 30, 2019		$601,850				$97,929				$699,779
See Notes to Financial Statements.

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ENTERGY CORPORATION AND SUBSIDIARIES

PART II. OTHER INFORMATION

Item 1.  Legal Proceedings

See “PART I, Item 1, Litigation” in the Form 10-K for a discussion of legal, administrative, and other regulatory proceedings affecting Entergy.  Also see Notes 1 and 2 to the financial statements herein and “Item 5, Other Information, Environmental Regulation” below for updates regarding environmental proceedings and regulation.

Item 1A.  Risk Factors

There have been no material changes to the risk factors discussed in “PART I, Item 1A, Risk Factors” in the Form 10-K.

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities (a)

Period		Total Number of Shares Purchased			Average Price Paid per Share				Total Number of Shares Purchased as Part of a Publicly Announced Plan			Maximum $ Amount of Shares that May Yet be Purchased Under a Plan (b)
7/01/2019-7/31/2019		—				$—			—				$350,052,918
8/01/2019-8/31/2019		—				$—			—				$350,052,918
9/01/2019-9/30/2019		—				$—			—				$350,052,918
Total		—				$—			—

In accordance with Entergy’s stock-based compensation plans, Entergy periodically grants stock options to key employees, which may be exercised to obtain shares of Entergy’s common stock.  According to the plans, these shares can be newly issued shares, treasury stock, or shares purchased on the open market.  Entergy’s management has been authorized by the Board to repurchase on the open market shares up to an amount sufficient to fund the exercise of grants under the plans.  In addition to this authority, the Board has authorized share repurchase programs to enable opportunistic purchases in response to market conditions. In October 2010 the Board granted authority for a $500 million share repurchase program. The amount of share repurchases under these programs may vary as a result of material changes in business results or capital spending or new investment opportunities.  In addition, in the first quarter 2019, Entergy withheld 76,735 shares of its common stock at $86.03 per share, 82,550 shares of its common stock at $86.51 per share, 38,326 shares of its common stock at $87.10 per share, 932 shares of its common stock at $89.19 per share, and 2,280 shares of its common stock at $93.25 per share to pay income taxes due upon vesting of restricted stock granted and payout of performance units as part of its long-term incentive program.

(a)	See Note 12 to the financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.

(b)	Maximum amount of shares that may yet be repurchased relates only to the $500 million plan and does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

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Item 5.  Other Information

Regulation of the Nuclear Power Industry

Following is an update to the “Regulation of the Nuclear Power Industry” section of Part I, Item 1 of the Form 10-K.

Nuclear Waste Policy Act of 1982

Nuclear Plant Decommissioning

In March 2019 filings with the NRC were made reporting on decommissioning funding for all of Entergy subsidiaries’ nuclear plants.  Those reports showed that decommissioning funding for each of the nuclear plants met the NRC’s financial assurance requirements.

Environmental Regulation

Following are updates to the “Environmental Regulation” section of Part I, Item 1 of the Form 10-K.

Clean Air Act and Subsequent Amendments

Potential Legislative, Regulatory, and Judicial Developments

As discussed in the Form 10-K, Entergy continues to support national legislation that would increase planning certainty for electric utilities while addressing carbon dioxide emissions in a responsible and flexible manner. Entergy voluntarily conducted a climate scenario analysis and published a comprehensive report in March 2019. The report follows the framework and recommendations of the Task Force on Climate-related Disclosures, describing climate-related governance, strategy, risk management, and metrics and targets. Scenario analysis resulted in Entergy developing and publishing a new goal of reducing the Utility’s emission rate by 50 percent from 2000 levels by 2030.

Cross-State Air Pollution

In September 2016 the EPA finalized the Cross State Air Pollution Rule Update Rule to address interstate transport for the 2008 ozone NAAQS. Starting in 2017 the final rule requires reductions in summer nitrogen oxides (NO_x) emissions. Several states, including Arkansas and Texas, filed a challenge to the Update Rule. In September 2019 the D.C. Circuit upheld the EPA’s underlying approach to the Update Rule but determined that it was inconsistent with the Clean Air Act because it failed to include deadlines consistent with downwind states’ deadlines for attainment. The court remanded the rule to the EPA for further consideration but did not vacate, so the rule remains in effect pending the EPA’s further review. Several petitions for reconsideration are still pending with the EPA, including one concerning whether the emissions budget for Mississippi should be increased.

New and Existing Source Performance Standards for Greenhouse Gas Emissions

As a part of a climate plan announced in June 2013, the EPA was directed to (i) reissue proposed carbon pollution standards for new power plants by September 20, 2013, with finalization of the rules to occur in a timely manner; (ii) issue proposed carbon pollution standards, regulations, or guidelines, as appropriate, for modified, reconstructed, and existing power plants no later than June 1, 2014; (iii) finalize those rules by no later than June 1, 2015; and (iv) include in the guidelines addressing existing power plants a requirement that states submit to the EPA the implementation plans required under Section 111(d) of the Clean Air Act and its implementing regulations by no later than June 30, 2016. In January 2014 the EPA issued the proposed New Source Performance Standards rule for new sources. In June 2014 the EPA issued proposed standards for existing power plants.  Entergy was actively engaged in the rulemaking process and submitted comments to the EPA in December 2014. The EPA issued the final rules for both new and existing sources in August 2015, and they were published in the Federal Register in October

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2015. The existing source rule, also called the Clean Power Plan, required states to develop plans for compliance with the EPA’s emission standards. In February 2016 the U.S. Supreme Court issued a stay halting the effectiveness of the rule pending review by the D.C. Circuit and, if applicable, by the U.S. Supreme Court. In March 2017 the current administration issued an executive order entitled “Promoting Energy Independence and Economic Growth” instructing the EPA to review and then to suspend, revise, or rescind the Clean Power Plan, if appropriate. The EPA subsequently asked the D.C. Circuit to hold the challenges to the Clean Power Plan and the greenhouse gas new source performance standards in abeyance and signed a notice of withdrawal of the proposed federal plan, model trading rules, and the Clean Energy Incentive Program. The court placed the litigation in abeyance in April 2017. The EPA Administrator also sent a letter to the affected governors explaining that states are not currently required to meet Clean Power Plan deadlines, some of which have passed. In October 2017 the EPA proposed a new rule that would repeal the Clean Power Plan on the grounds that it exceeds the EPA’s statutory authority under the Clean Air Act. In December 2017 the EPA issued an advanced notice of proposed rulemaking regarding section 111(d), seeking comment on the form and content of a replacement for the Clean Power Plan, if one is promulgated. In July 2019 the EPA released its repeal and replacement of the Clean Power Plan. The Affordable Clean Energy Rule, which applies only to existing coal-fired electric generating units, determines that heat rate improvements are the best system of emission reductions and lists six candidate technologies for consideration by states at each coal unit. The rule provides states discretion in determining how the best system for emission reductions applies to individual units, including through the consideration of technical feasibility and the remaining useful life of the facility. In September 2019 the D.C. Circuit dismissed all of the litigation concerning the Clean Power Plan because that rule has been repealed and replaced by the Affordable Clean Energy Rule. Entergy is evaluating the final Affordable Clean Energy Rule’s impacts on its coal units and will monitor litigation challenging the rule. The EPA also has proposed a revision to the new source performance standard on greenhouse gas emissions that primarily impacts new coal units and, therefore, should not impact Entergy.

Groundwater at Certain Nuclear Sites

As discussed in the Form 10-K, in February 2016, Entergy disclosed that elevated tritium levels had been detected in samples from several monitoring wells that are part of Indian Point’s groundwater monitoring program.  Investigation of the source of elevated tritium determined that the source was related to a temporary system to process water in preparation for the regularly scheduled refueling outage at Indian Point 2. The NRC had issued a notice of violation related to the adequacy of Entergy’s controls to prevent the introduction of radioactivity into the site groundwater. Entergy completed corrective actions and, in February 2019, the NRC concluded that Entergy had achieved full compliance and closed the violation.

Steam Electric Effluent Guidelines

The 2015 Steam Electric Effluent Limitations Guidelines (ELG) rule requires, among other things, that there be no discharge of bottom ash transport water. The no-discharge requirement contains no exceptions and could cause compliance problems for Entergy’s coal facilities during heavy storm events and under certain non-routine operational conditions. The ELG rule’s compliance dates currently are delayed while the EPA reconsiders the rule. Additionally, the Fifth Circuit Court of Appeals recently vacated and remanded the provisions of the rule related to legacy wastewater and leachate. A proposed rule revision on bottom ash transport water is expected in the third quarter 2019 which may allow some flexibility for storm events and non-routine operations, with a final rule expected by the end of the year. A separate rulemaking is expected to address the legacy wastewater and leachate issues. Despite the impending rulemaking, Entergy is implementing projects at its White Bluff and Independence plants to convert to zero-discharge systems to comply with the ELG rule and the coal combustion residuals restrictions on impoundments. Additionally, the Nelson 6 facility is implementing operational and maintenance measures to ensure its original zero-discharge design is maintained for compliance.

Item 6.  Exhibits

	3(a) -	Amended and Restated Certificate of Formation of Entergy Texas effective August 21, 2019 (3.1 to Form 8-K filed August 21, 2019 in 1-34360).

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	3(b) -	Statement of Resolution Establishing the Entergy Texas 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share) (3.3 to Form 8-A filed September 4, 2019 in 1-34360).
	3(c) -	Amended and Restated Bylaws of Entergy Texas effective August 19, 2019 (3.2 to Form 8-K filed August 21, 2019 in 1-34360).
	*4(a) -	Extension Agreement, dated September 13, 2019, to Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy Corporation, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent and LC Issuing Bank, MUFG Bank, Ltd., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto.
	*4(b) -	Extension Agreement, dated September 13, 2019, to Second Amended and Restated Credit Agreement dated as of September 14, 2018, as supplemented by the Borrower Assumption Agreement of Entergy Arkansas Power, LLC dated as of November 30, 2018, among Entergy Arkansas, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., as LC Issuing Bank, and the other LC Issuing Banks from time to time parties thereto.
	*4(c) -	Extension Agreement, dated September 13, 2019, to Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy Louisiana, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, Wells Fargo Bank, National Association and BNP Paribas, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto.
	*4(d) -	Extension Agreement, dated September 13, 2019, to Second Amended and Restated Credit Agreement dated as of September 14, 2018, among Entergy Texas, as Borrower, the banks and other financial institutions listed on the signature pages thereof, as Lenders, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., BNP Paribas, Mizuho Bank, Ltd., and The Bank of Nova Scotia, as LC Issuing Banks, and the other LC Issuing Banks from time to time parties thereto.
	4(e) -	First Supplemental Indenture dated as of September 1, 2019, to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas and The Bank of New York Mellon, as trustee (4.61 to Form 8-K filed September 20, 2019 in 1-34360).
	4(f) -	Officer’s Certificate No. 13-B-11 dated September 16, 2019, supplemental to Indenture, Deed of Trust and Security Agreement dated as of October 1, 2008, between Entergy Texas and The Bank of New York Mellon, as trustee (4.57 to Form 8-K filed September 20, 2019 in 1-34360).
	4(g) -	Statement of Resolution Establishing the Entergy Texas 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share) (3.3 to Form 8-A filed September 4, 2019 in 1-34360).
	*31(a) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
	*31(b) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Corporation.
	*31(c) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
	*31(d) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Arkansas.
	*31(e) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
	*31(f) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Louisiana.
	*31(g) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
	*31(h) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Mississippi.
	*31(i) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
	*31(j) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy New Orleans.
	*31(k) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.

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	*31(l) -	Rule 13a-14(a)/15d-14(a) Certification for Entergy Texas.
	*31(m) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
	*31(n) -	Rule 13a-14(a)/15d-14(a) Certification for System Energy.
	**32(a) -	Section 1350 Certification for Entergy Corporation.
	**32(b) -	Section 1350 Certification for Entergy Corporation.
	**32(c) -	Section 1350 Certification for Entergy Arkansas.
	**32(d) -	Section 1350 Certification for Entergy Arkansas.
	**32(e) -	Section 1350 Certification for Entergy Louisiana.
	**32(f) -	Section 1350 Certification for Entergy Louisiana.
	**32(g) -	Section 1350 Certification for Entergy Mississippi.
	**32(h) -	Section 1350 Certification for Entergy Mississippi.
	**32(i) -	Section 1350 Certification for Entergy New Orleans.
	**32(j) -	Section 1350 Certification for Entergy New Orleans.
	**32(k) -	Section 1350 Certification for Entergy Texas.
	**32(l) -	Section 1350 Certification for Entergy Texas.
	**32(m) -	Section 1350 Certification for System Energy.
	**32(n) -	Section 1350 Certification for System Energy.
	*101 INS -	Inline XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
	*101 SCH -	Inline XBRL Schema Document.
	*101 PRE -	Inline XBRL Presentation Linkbase Document.
	*101 LAB -	Inline XBRL Label Linkbase Document.
	*101 CAL -	Inline XBRL Calculation Linkbase Document.
	*101 DEF -	Inline XBRL Definition Linkbase Document.
	*104 -	Cover Page Interactive Data File (formatted in Inline XBRL and contained in Exhibits 101).

___________________________

Pursuant to Item 601(b)(4)(iii) of Regulation S-K, Entergy Corporation agrees to furnish to the Commission upon request any instrument with respect to long-term debt that is not registered or listed herein as an Exhibit because the total amount of securities authorized under such agreement does not exceed ten percent of the total assets of Entergy Corporation and its subsidiaries on a consolidated basis.

*	Filed herewith.
**	Furnished, not filed, herewith.

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, each registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.  The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

ENTERGY CORPORATION ENTERGY ARKANSAS, LLC ENTERGY LOUISIANA, LLC ENTERGY MISSISSIPPI, LLC ENTERGY NEW ORLEANS, LLC ENTERGY TEXAS, INC. SYSTEM ENERGY RESOURCES, INC.

/s/ Kimberly A. Fontan

Kimberly A. Fontan Senior Vice President and Chief Accounting Officer (For each Registrant and for each as Principal Accounting Officer)

Date:    November 5, 2019

204

Exhibit 4(a)

Execution Version

EXTENSION AGREEMENT

September 13, 2019

Citibank, N.A., as Administrative Agent under the Credit Agreement

referred to below

Citibank, N.A.

1615 Brett Road, Ops III

New Castle, Delaware 19720

Ladies and Gentlemen:

Reference is made to (i) the Second Amended and Restated Credit Agreement, dated as of September 14, 2018 (as amended, restated, modified or otherwise supplemented from time to time prior to the date hereof, the “Credit Agreement”), among Entergy Corporation, as the Borrower, the banks and other financial institutions party thereto as Lenders, Citibank, N.A., as Administrative Agent and an LC Issuing Bank, MUFG Bank, Ltd., as an LC Issuing Bank, and the other LC Issuing Banks party thereto, and (ii) the Borrower’s request, dated July 17, 2019, for an extension of the Termination Date to September 14, 2024 (the “Extension Request”). Unless otherwise indicated, capitalized terms used herein and not otherwise defined herein have the meanings given such terms in the Credit Agreement.

In connection with the “Extension” (as defined in the Extension Request), each undersigned Lender agrees, subject to the Administrative Agent’s receipt of the documents described in Section 2.18(c) of the Credit Agreement, to extend the Termination Date applicable to such Lender’s Commitment to September 14, 2024, such that the reference to “September 14, 2023” contained in the definition of “Termination Date” in the Credit Agreement shall hereafter be deemed to be a reference to “September 14, 2024,” such extension to be effective on September 13, 2019.

This Extension Agreement shall be construed in accordance with and governed by the law of the State of New York. Except as specifically provided above, (i) the Credit Agreement and the other Loan Documents shall remain in full force and effect and are hereby ratified and confirmed in all respects by the parties hereto, and (ii) the execution and delivery of this Extension Agreement shall not operate as a waiver of any right, power or remedy of the Administrative Agent or any Lender under the Credit Agreement or any Loan Documents, nor constitute a waiver of any provision of the Credit Agreement or any Loan Documents. This Extension Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature pages follow]

Citibank, N.A., as a Lender and LC Issuing Bank

---

By: /s/ Richard Rivera        

Name: Richard Rivera

Title: Vice President

JP Morgan Chase Bank N.A., as a Lender and LC Issuing Bank

By: /s/ Amit Gaur            

Name: Amit Gaur

Title: Vice President

Wells Fargo Bank, N.A.

By: /s/ Keith Luettel        

Name: Keith Luettel

Title: Managing Director

BNP Paribas, as a Lender

By: /s/ Denis O’Meara        

Name: Denis O’Meara

Title: Managing Director

By: /s/ Theodore Sheen        

Name: Theodore Sheen

Title: Director

MIZUHO BANK, LTD.

By: /s/ Tracy Rahn        

Name: Tracy Rahn

Title: Authorized Signatory

MUFG Bank, Ltd., as a Lender and LC Issuing Bank

By: /s/ Chi-Cheng Chen        

Name: Chi-Cheng Chen

Title: Director

---

The Bank of Nova Scotia, as a Lender and LC Issuing Bank

By: /s/ Jason Rinne        

Name: Jason Rinne

Title: Director

BANK OF AMERICA, N.A.

By: /s/ Jennifer Cochrane        

Name: Jennifer Cochrane

Title: Vice President

GOLDMAN SACHS BANK USA, as a Lender

By: /s/ Ryan Durkin        

Name: Ryan Durkin

Title: Authorized Signatory

Morgan Stanley Bank, N.A.

By: /s/ Michael King        

Name: Michael King

Title: Authorized Signatory

KeyBank National Association

By: /s/ Sukanya V. Raj        

Name: Sukanya V. Raj

Title: Senior Vice President

BARCLAYS BANK PLC, as a Lender

By: /s/ Sydney G. Dennis        

Name: Sydney G. Dennis

Title: Director

CoBank, ACB

By: /s/ Matthew Leatherman    

---

Name: Matthew Leatherman

Title: Vice President

THE BANK OF NEW YORK MELLON

By: /s/ Molly H. Ross        

Name: Molly H. Ross

Title: Vice President

REGIONS BANK

By: /s/ Tedrick Tarver        

Name: Tedrick Tarver

Title: Director

Sumitomo Mitsui Banking Corporation

By: /s/ Michael Maguire        

Name: Michael Maguire

Title: Executive Director

U.S. Bank National Association

By: /s/ Michael T. Sagges        

Name: Michael T. Sagges

Title: Vice President

The Northern Trust Company

By: /s/ Keith L. Burson        

Name: Keith L. Burson

Title: Senior Vice President

[Hancock Whitney Bank]

By: /s/ Nancy Moragas        

Name: Nancy Moragas

Title: Senior Vice President

Capital One, National Association

---

By: /s/ Katherine G. Kay        

Name: Katherine G. Kay

Title: Senior Vice President

Taiwan Cooperative Bank, Los Angeles Branch

By: /s/ Lin, Tao-Lun        

Name: Lin, Tao-Lun

Title: V.P. & General Manager

CHANG HWA COMMERCIAL BANK, LTD., LOS ANGELES BRANCH

By: /s/ Hung-Chieh Chou        

Name: Hung-Chieh Chou

Title: A.V.P. & A.G.M.

AGREED AND ACCEPTED:

ENTERGY CORPORATION

By: /s/ Steven C. McNeal        

Name: Steven C. McNeal

Title: Vice President and Treasurer

 

Exhibit 4(b)

Execution Version

EXTENSION AGREEMENT

September 13, 2019

Citibank, N.A., as Administrative Agent under the Credit Agreement

referred to below

Citibank, N.A.

1615 Brett Road, Ops III

New Castle, Delaware 19720

Ladies and Gentlemen:

Reference is made to (i) the Second Amended and Restated Credit Agreement, dated as of September 14, 2018 (as amended, restated, modified or otherwise supplemented from time to time prior to the date hereof, the “Credit Agreement”), among Entergy Corporation, as the Borrower, the banks and other financial institutions party thereto as Lenders, Citibank, N.A., as Administrative Agent and an LC Issuing Bank, MUFG Bank, Ltd., as an LC Issuing Bank, and the other LC Issuing Banks party thereto, and (ii) the Borrower’s request, dated July 17, 2019, for an extension of the Termination Date to September 14, 2024 (the “Extension Request”). Unless otherwise indicated, capitalized terms used herein and not otherwise defined herein have the meanings given such terms in the Credit Agreement.

In connection with the “Extension” (as defined in the Extension Request), each undersigned Lender agrees, subject to the Administrative Agent’s receipt of the documents described in Section 2.18(c) of the Credit Agreement, to extend the Termination Date applicable to such Lender’s Commitment to September 14, 2024, such that the reference to “September 14, 2023” contained in the definition of “Termination Date” in the Credit Agreement shall hereafter be deemed to be a reference to “September 14, 2024,” such extension to be effective on September 13, 2019.

This Extension Agreement shall be construed in accordance with and governed by the law of the State of New York. Except as specifically provided above, (i) the Credit Agreement and the other Loan Documents shall remain in full force and effect and are hereby ratified and confirmed in all respects by the parties hereto, and (ii) the execution and delivery of this Extension Agreement shall not operate as a waiver of any right, power or remedy of the Administrative Agent or any Lender under the Credit Agreement or any Loan Documents, nor constitute a waiver of any provision of the Credit Agreement or any Loan Documents. This Extension Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature pages follow]

---

Citibank, N.A., as a Lender and LC Issuing Bank

By: /s/ Richard Rivera        

Name: Richard Rivera

Title: Vice President

JP Morgan Chase Bank N.A., as a Lender and LC Issuing Bank

By: /s/ Amit Gaur            

Name: Amit Gaur

Title: Vice President

Wells Fargo Bank, N.A.

By: /s/ Keith Luettel        

Name: Keith Luettel

Title: Managing Director

BNP Paribas, as a Lender

By: /s/ Denis O’Meara        

Name: Denis O’Meara

Title: Managing Director

By: /s/ Theodore Sheen        

Name: Theodore Sheen

Title: Director

MIZUHO BANK, LTD.

By: /s/ Tracy Rahn        

Name: Tracy Rahn

Title: Authorized Signatory

MUFG Bank, Ltd., as a Lender and LC Issuing Bank

By: /s/ Chi-Cheng Chen        

Name: Chi-Cheng Chen

Title: Director

---

The Bank of Nova Scotia, as a Lender and LC Issuing Bank

By: /s/ Jason Rinne        

Name: Jason Rinne

Title: Director

BANK OF AMERICA, N.A.

By: /s/ Jennifer Cochrane        

Name: Jennifer Cochrane

Title: Vice President

GOLDMAN SACHS BANK USA, as a Lender

By: /s/ Ryan Durkin        

Name: Ryan Durkin

Title: Authorized Signatory

Morgan Stanley Bank, N.A.

By: /s/ Michael King        

Name: Michael King

Title: Authorized Signatory

KeyBank National Association

By: /s/ Sukanya V. Raj        

Name: Sukanya V. Raj

Title: Senior Vice President

BARCLAYS BANK PLC, as a Lender

By: /s/ Sydney G. Dennis        

Name: Sydney G. Dennis

Title: Director

CoBank, ACB

By: /s/ Matthew Leatherman    

---

Name: Matthew Leatherman

Title: Vice President

THE BANK OF NEW YORK MELLON

By: /s/ Molly H. Ross        

Name: Molly H. Ross

Title: Vice President

REGIONS BANK

By: /s/ Tedrick Tarver        

Name: Tedrick Tarver

Title: Director

Sumitomo Mitsui Banking Corporation

By: /s/ Michael Maguire        

Name: Michael Maguire

Title: Executive Director

U.S. Bank National Association

By: /s/ Michael T. Sagges        

Name: Michael T. Sagges

Title: Vice President

The Northern Trust Company

By: /s/ Keith L. Burson        

Name: Keith L. Burson

Title: Senior Vice President

[Hancock Whitney Bank]

By: /s/ Nancy Moragas        

Name: Nancy Moragas

Title: Senior Vice President

Capital One, National Association

---

By: /s/ Katherine G. Kay        

Name: Katherine G. Kay

Title: Senior Vice President

Taiwan Cooperative Bank, Los Angeles Branch

By: /s/ Lin, Tao-Lun        

Name: Lin, Tao-Lun

Title: V.P. & General Manager

CHANG HWA COMMERCIAL BANK, LTD., LOS ANGELES BRANCH

By: /s/ Hung-Chieh Chou        

Name: Hung-Chieh Chou

Title: A.V.P. & A.G.M.

AGREED AND ACCEPTED:

ENTERGY CORPORATION

By: /s/ Steven C. McNeal        

Name: Steven C. McNeal

Title: Vice President and Treasurer

 

Execution Version

Exhibit 4(c)

EXTENSION AGREEMENT

September 13, 2019

Citibank, N.A., as Administrative Agent under the Credit Agreement

referred to below

Citibank, N.A.

1615 Brett Road, Ops III

New Castle, Delaware 19720

Ladies and Gentlemen:

Reference is made to (i) the Second Amended and Restated Credit Agreement, dated as of September 14, 2018 (as amended, restated, modified or otherwise supplemented from time to time prior to the date hereof, the “Credit Agreement”), among Entergy Louisiana, LLC, as the Borrower, the banks and other financial institutions party thereto as Lenders, Citibank, N.A., as Administrative Agent, Wells Fargo, National Association and BNP Paribas, as LC Issuing Banks, and the other LC Issuing Banks party thereto, and (ii) the Borrower’s request, dated July 17, 2019, for an extension of the Termination Date to September 14, 2024 (the “Extension Request”). Unless otherwise indicated, capitalized terms used herein and not otherwise defined herein have the meanings given such terms in the Credit Agreement.

In connection with the “Extension” (as defined in the Extension Request), each undersigned Lender agrees, subject to the Administrative Agent’s receipt of the documents described in Section 2.18(c) of the Credit Agreement, to extend the Termination Date applicable to such Lender’s Commitment to September 14, 2024, such that the reference to “September 14, 2023” contained in the definition of “Termination Date” in the Credit Agreement shall hereafter be deemed to be a reference to “September 14, 2024,” such extension to be effective on September 13, 2019.

This Extension Agreement shall be construed in accordance with and governed by the law of the State of New York. Except as specifically provided above, (i) the Credit Agreement and the other Loan Documents shall remain in full force and effect and are hereby ratified and confirmed in all respects by the parties hereto, and (ii) the execution and delivery of this Extension Agreement shall not operate as a waiver of any right, power or remedy of the Administrative Agent or any Lender under the Credit Agreement or any Loan Documents, nor constitute a waiver of any provision of the Credit Agreement or any Loan Documents. This Extension Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature pages follow]

JP Morgan Chase Bank N.A., as a Lender and LC Issuing Bank

---

By: /s/ Amit Gaur            

Name: Amit Gaur

Title: Vice President

Citibank, N.A.

By: /s/ Richard Rivera        

Name: Richard Rivera

Title: Vice President

Wells Fargo Bank, N.A., as a Lender and LC Issuing Bank

By: /s/ Keith Luettel        

Name: Keith Luettel

Title: Managing Director

BNP Paribas, as a Lender and LC Issuing Bank

By: /s/ Denis O’Meara        

Name: Denis O’Meara

Title: Managing Director

By: /s/ Theodore Sheen        

Name: Theodore Sheen

Title: Director

MIZUHO BANK, LTD.

By: /s/ Tracy Rahn        

Name: Tracy Rahn

Title: Authorized Signatory

MUFG Bank, Ltd.

By: /s/ Chi-Chieng Chen        

Name: Chi-Chieng Chen

Title: Director

The Bank of Nova Scotia, as a Lender and LC Issuing Bank

---

By: /s/ Jason Rinne        

Name: Jason Rinne

Title: Director

BANK OF AMERICA, N.A.

By: /s/ Jennifer Cochrane        

Name: Jennifer Cochrane

Title: Vice President

GOLDMAN SACHS BANK USA, as a Lender

By: /s/ Ryan Durkin        

Name: Ryan Durkin

Title: Authorized Signatory

Morgan Stanley Bank, N.A.

By: /s/ Michael King        

Name: Michael King

Title: Authorized Signatory

KeyBank National Association

By: /s/ Sukanya V. Raj        

Name: Sukanya V. Raj

Title: Senior Vice President

BARCLAYS BANK PLC, as a Lender

By: /s/ Sydney G. Dennis        

Name: Sydney G. Dennis

Title: Director

CoBank, ACB

By: /s/ Matthew Leatherman    

Name: Matthew Leatherman

Title: Vice President

---

THE BANK OF NEW YORK MELLON

By: /s/ Molly H. Ross        

Name: Molly H. Ross

Title: Vice President

REGIONS BANK

By: /s/ Tedrick Tarver        

Name: Tedrick Tarver

Title: Director

Sumitomo Mitsui Banking Corporation

By: /s/ Michael Maguire        

Name: Michael Maguire

Title: Executive Director

U.S. Bank National Association

By: /s/ Michael T. Sagges        

Name: Michael T. Sagges

Title: Vice President

AGREED AND ACCEPTED:

ENTERGY LOUISIANA, LLC

By: /s/ Kevin J. Marino        

Name: Kevin J. Marino

Title: Assistant Treasurer

Execution Version

Exhibit 4(d)

EXTENSION AGREEMENT

September 13, 2019

Citibank, N.A., as Administrative Agent under the Credit Agreement

referred to below

Citibank, N.A.

1615 Brett Road, Ops III

New Castle, Delaware 19720

Ladies and Gentlemen:

Reference is made to (i) the Second Amended and Restated Credit Agreement, dated as of September 14, 2018 (as amended, restated, modified or otherwise supplemented from time to time prior to the date hereof, the “Credit Agreement”), among Entergy Texas, Inc., as the Borrower, the banks and other financial institutions party thereto as Lenders, Citibank, N.A., as Administrative Agent, JPMorgan Chase Bank, N.A., BNP Paribas, Mizuho Bank, Ltd. and The Bank of Nova Scotia, as LC Issuing Banks, and the other LC Issuing Banks party thereto, and (ii) the Borrower’s request, dated July 17, 2019, for an extension of the Termination Date to September 14, 2024 (the “Extension Request”). Unless otherwise indicated, capitalized terms used herein and not otherwise defined herein have the meanings given such terms in the Credit Agreement.

In connection with the “Extension” (as defined in the Extension Request), each undersigned Lender agrees, subject to the Administrative Agent’s receipt of the documents described in Section 2.18(c) of the Credit Agreement, to extend the Termination Date applicable to such Lender’s Commitment to September 14, 2024, such that the reference to “September 14, 2023” contained in the definition of “Termination Date” in the Credit Agreement shall hereafter be deemed to be a reference to “September 14, 2024,” such extension to be effective on September 13, 2019.

This Extension Agreement shall be construed in accordance with and governed by the law of the State of New York. Except as specifically provided above, (i) the Credit Agreement and the other Loan Documents shall remain in full force and effect and are hereby ratified and confirmed in all respects by the parties hereto, and (ii) the execution and delivery of this Extension Agreement shall not operate as a waiver of any right, power or remedy of the Administrative Agent or any Lender under the Credit Agreement or any Loan Documents, nor constitute a waiver of any provision of the Credit Agreement or any Loan Documents. This Extension Agreement may be signed in any number of counterparts, each of which shall be an original, with the same effect as if the signatures thereto and hereto were upon the same instrument.

[Signature pages follow]

JP Morgan Chase Bank N.A., as a Lender and LC Issuing Bank

---

By: /s/ Amit Gaur            

Name: Amit Gaur

Title: Vice President

Citibank, N.A.

By: /s/ Richard Rivera        

Name: Richard Rivera

Title: Vice President

Wells Fargo Bank, N.A., as a Lender and LC Issuing Bank

By: /s/ Keith Luettel         

Name: Keith Luettel

Title: Managing Director

BNP Paribas, as a Lender and LC Issuing Bank

By: /s/ Denis O’Meara        

Name: Denis O’Meara

Title: Managing Director

By: /s/ Theodore Sheen        

Name: Theodore Sheen

Title: Director

MIZUHO BANK, LTD., as a Lender and LC Issuing Bank

By: /s/ Tracy Rahn        

Name: Tracy Rahn

Title: Authorized Signatory

MUFG Bank, Ltd.

By: /s/ Chi-Chieng Chen        

Name: Chi-Chieng Chen

Title: Director

---

The Bank of Nova Scotia, as a Lender and LC Issuing Bank

By: /s/ Jason Rinne        

Name: Jason Rinne

Title: Director

BANK OF AMERICA, N.A.

By: /s/ Jennifer Cochrane        

Name: Jennifer Cochrane

Title: Vice President

GOLDMAN SACHS BANK USA, as a Lender

By: /s/ Ryan Durkin        

Name: Ryan Durkin

Title: Authorized Signatory

Morgan Stanley Bank, N.A.

By: /s/ Michael King        

Name: Michael King

Title: Authorized Signatory

KeyBank National Association

By: /s/ Sukanya V. Raj        

Name: Sukanya V. Raj

Title: Senior Vice President

BARCLAYS BANK PLC, as a Lender

By: /s/ Sydney G. Dennis        

Name: Sydney G. Dennis

Title: Director

CoBank, ACB

By: /s/ Matthew Leatherman    

---

Name: Matthew Leatherman

Title: Vice President

THE BANK OF NEW YORK MELLON

By: /s/ Molly H. Ross        

Name: Molly H. Ross

Title: Vice President

REGIONS BANK

By: /s/ Tedrick Tarver        

Name: Tedrick Tarver

Title: Director

Sumitomo Mitsui Banking Corporation

By: /s/ Michael Maguire        

Name: Michael Maguire

Title: Executive Director

U.S. Bank National Association

By: /s/ Michael T. Sagges        

Name: Michael T. Sagges

Title: Vice President

AGREED AND ACCEPTED:

ENTERGY TEXAS, INC.

By: /s/ Kevin J. Marino        

Name: Kevin J. Marino

Title: Assistant Treasurer

Exhibit 31(a)

CERTIFICATIONS

I, Leo P. Denault, certify that:

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

1.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

2.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

3.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

4.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Leo P. Denault
Leo P. Denault
Chairman of the Board and Chief Executive Officer
of Entergy Corporation

Date:  November 5, 2019

Exhibit 31(b)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

I have reviewed this quarterly report on Form 10-Q of Entergy Corporation;

1.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

2.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

3.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

4.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Corporation

Date:  November 5, 2019

Exhibit 31(c)

CERTIFICATIONS

I, Laura R. Landreaux, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Laura R. Landreaux
Laura R. Landreaux
Chair of the Board, President, and
Chief Executive Officer of Entergy Arkansas, LLC

Date:  November 5, 2019

Exhibit 31(d)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Arkansas, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Arkansas, LLC

Date:  November 5, 2019

Exhibit 31(e)

CERTIFICATIONS

I, Phillip R. May, Jr., certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Phillip R. May, Jr.
Phillip R. May, Jr.
Chairman of the Board, President, and Chief Executive
Officer of Entergy Louisiana, LLC

Date:  November 5, 2019

Exhibit 31(f)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Louisiana, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Louisiana, LLC

Date:  November 5, 2019

Exhibit 31(g)

CERTIFICATIONS

I, Haley R. Fisackerly, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Haley R. Fisackerly
Haley R. Fisackerly
Chairman of the Board, President, and Chief Executive Officer
of Entergy Mississippi, LLC

Date:  November 5, 2019

Exhibit 31(h)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Mississippi, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Mississippi, LLC

Date:  November 5, 2019

Exhibit 31(i)

CERTIFICATIONS

I, David D. Ellis, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ David D. Ellis
David D. Ellis
Chairman of the Board, President, and Chief Executive Officer
of Entergy New Orleans, LLC

Date:  November 5, 2019

Exhibit 31(j)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy New Orleans, LLC;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy New Orleans, LLC

Date:  November 5, 2019

Exhibit 31(k)

CERTIFICATIONS

I, Sallie T. Rainer, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Sallie T. Rainer
Sallie T. Rainer
Chair of the Board, President, and Chief Executive Officer
of Entergy Texas, Inc.

Date:  November 5, 2019

Exhibit 31(l)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of Entergy Texas, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Texas, Inc.

Date:  November 5, 2019

Exhibit 31(m)

CERTIFICATIONS

I, Roderick K. West, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Roderick K. West
Roderick K. West
Chairman of the Board, President, and Chief Executive Officer
of System Energy Resources, Inc.

Date:  November 5, 2019

Exhibit 31(n)

CERTIFICATIONS

I, Andrew S. Marsh, certify that:

1.	I have reviewed this quarterly report on Form 10-Q of System Energy Resources, Inc.;

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of System Energy Resources, Inc.

Date:  November 5, 2019

Exhibit 32(a)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Leo P. Denault, Chairman of the Board and Chief Executive Officer of Entergy Corporation (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Leo P. Denault
Leo P. Denault
Chairman of the Board and Chief Executive Officer
of Entergy Corporation

 

Date: November 5, 2019

Exhibit 32(b)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Corporation (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Corporation

Date: November 5, 2019

Exhibit 32(c)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Laura R. Landreaux, Chair of the Board, President, and Chief Executive Officer of Entergy Arkansas, LLC (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Laura R. Landreaux
Laura R. Landreaux
Chair of the Board, President, and Chief Executive
Officer of Entergy Arkansas, LLC

Date: November 5, 2019

Exhibit 32(d)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Arkansas, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Arkansas, LLC

Date: November 5, 2019

Exhibit 32(e)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Phillip R. May, Jr., Chairman of the Board, President, and Chief Executive Officer of Entergy Louisiana, LLC (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Phillip R. May, Jr.
Phillip R. May, Jr.
Chairman of the Board, President, and Chief Executive
Officer of Entergy Louisiana, LLC

Date: November 5, 2019

Exhibit 32(f)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Louisiana, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Louisiana, LLC

Date: November 5, 2019

Exhibit 32(g)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Haley R. Fisackerly, Chairman of the Board, President, and Chief Executive Officer of Entergy Mississippi, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Haley R. Fisackerly
Haley R. Fisackerly
Chairman of the Board, President, and Chief Executive
Officer of Entergy Mississippi, LLC

Date: November 5, 2019

Exhibit 32(h)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Mississippi, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Mississippi, LLC

Date: November 5, 2019

Exhibit 32(i)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, David D. Ellis, Chairman of the Board, President, and Chief Executive Officer of Entergy New Orleans, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ David D. Ellis
David D. Ellis
Chairman of the Board, President, and Chief Executive
Officer of Entergy New Orleans, LLC

Date: November 5, 2019

Exhibit 32(j)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy New Orleans, LLC (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy New Orleans, LLC

Date: November 5, 2019

Exhibit 32(k)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Sallie T. Rainer, Chair of the Board, President, and Chief Executive Officer of Entergy Texas, Inc. (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Sallie T. Rainer
Sallie T. Rainer
Chair of the Board, President, and Chief Executive Officer
of Entergy Texas, Inc.

Date: November 5, 2019

Exhibit 32(l)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of Entergy Texas, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial Officer
of Entergy Texas, Inc.

Date: November 5, 2019

Exhibit 32(m)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Roderick K. West, Chairman of the Board, President, and Chief Executive Officer of System Energy Resources, Inc. (the “Company”), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Roderick K. West
Roderick K. West
Chairman of the Board, President, and Chief Executive Officer
of System Energy Resources, Inc.

Date: November 5, 2019

Exhibit 32(n)

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

I, Andrew S. Marsh, Executive Vice President and Chief Financial Officer of System Energy Resources, Inc. (the "Company"), certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)	The Quarterly Report on Form 10-Q of the Company for the quarter ended September 30, 2019 (the "Report") fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods presented in the Report.

/s/ Andrew S. Marsh
Andrew S. Marsh
Executive Vice President and Chief Financial
Officer of System Energy Resources, Inc.

Date: November 5, 2019

v3.19.3

Risk Management and Fair Values (Schedules Of Valuation Techniques) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 48
Maximum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.75%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 5
Minimum [Member]
Range from Average Percentage for Fair Value of Electricity Swaps	4.00%
Effect of Significant Unobservable Inputs on Fair Value of Electricity Swaps	$ 4
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	4 years 6 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Maximum Length of Time Hedged in Cash Flow Hedge	6 months

X

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- Definition Maximum length of time over which the entity is hedging its exposure to the variability in future cash flows for forecasted transactions, excluding those forecasted transactions related to the payment of variable interest on existing financial instruments, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents the reported fact of one year, five months, and thirteen days. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=112277219&loc=d3e80748-113994 + Details Name: us-gaap_MaximumLengthOfTimeHedgedInCashFlowHedge1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: duration

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v3.19.3

Risk Management and Fair Values (Derivative Instruments Designated as Cash Flow Hedges On Consolidated Statements Of Income) (Details) - Competitive Businesses Operating Revenues [Member] - Electricity Swaps And Options [Member] - Cash Flow Hedging [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Effect of Derivative instruments designated as cash flow hedges on consolidated statements of income
Amount of gain (loss) recognized in AOCI (effective portion)	$ (7)	$ (51)	$ 145	$ (40)
Amount of gain reclassified from accumulated OCI into income (effective portion)	$ 19	$ (11)	$ 76	$ (38)

X

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Notes Payable By Variable Interest Entities) (Details) $ in Millions	Sep. 30, 2019 USD ($)
Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.65%
Amount	$ 90
Three Point One Seven Percent Series M Notes Due December Two Thousand Twenty Three [Member] | Entergy Arkansas VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.17%
Amount	$ 40
Three Point Three Eight Percent Series R Notes Due August Two Thousand Twenty [Member] | Entergy Louisiana River Bend VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.38%
Amount	$ 70
Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.92%
Amount	$ 40
Three Point Two Two Percent Series I Notes Due December Two Thousand Twenty Three [Domain] | Entergy Louisiana Waterford VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.22%
Amount	$ 20
Three Point Four Two Percent Series J Notes Due April Two Thousand Twenty One [Member] | System Energy VIE [Member]
Notes payable by variable interest entities
Stated interest rate (percentage)	3.42%
Amount	$ 100

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v3.19.3

Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Incremental Weighted Average Shares Attributable to Dilutive Effect [Abstract]
Stock options, Shares	700,000	400,000	500,000	300,000
Stock options $/share	$ (0.01)	$ (0.01)	$ (0.01)	$ (0.01)
Restricted stock, Shares	900,000	800,000	700,000	700,000
Restricted stock $/share	$ (0.01)	$ (0.01)	$ (0.02)	$ (0.01)
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements	0	1,500,000	600,000	900,000
Average Dilutive Effect Of Equity Forwards	$ 0	$ (0.02)	$ (0.01)	$ (0.03)
Basic earnings per share
Net Income (Loss) Available to Common Stockholders, Basic	$ 365,240	$ 536,379	$ 856,201	$ 914,560
Net Income (Loss) Available to Common Stockholders, Diluted	$ 365,200	$ 536,400	$ 856,200	$ 914,600
Net Income Attributable to Entergy Corporation, Shares	198,932,387	181,002,303	193,876,557	180,845,440
Net Income Attributable to Entergy Corporation, $/share	$ 1.84	$ 2.96	$ 4.42	$ 5.06
Diluted earnings per share, Shares	200,492,935	183,664,583	195,685,851	182,692,325
Diluted earnings per share $/share	$ 1.82	$ 2.92	$ 4.38	$ 5.01

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- Definition Amount, after deduction of tax, noncontrolling interests, dividends on preferred stock and participating securities, and addition from assumption of issuance of common shares for dilutive potential common shares; of income (loss) available to common shareholders. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 260 -SubTopic 10 -Section 45 -Paragraph 16 -URI http://asc.fasb.org/extlink&oid=109260490&loc=d3e1505-109256 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 260 -SubTopic 10 -Section 45 -Paragraph 11 -URI http://asc.fasb.org/extlink&oid=109260490&loc=d3e1377-109256 + Details Name: us-gaap_NetIncomeLossAvailableToCommonStockholdersDiluted Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Summary Of The Borrowings Outstanding And Capacity Available Under The Facility) (Details) $ in Millions	Sep. 30, 2019 USD ($)
Summary of the borrowings outstanding and capacity available under the facility
Capacity	$ 3,500
Amount Drawn/ Outstanding	155
Letters of Credit	6
Capacity Available	$ 3,339

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- Definition The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(16)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_LineOfCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Maximum borrowing capacity under the credit facility without consideration of any current restrictions on the amount that could be borrowed or the amounts currently outstanding under the facility. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityMaximumBorrowingCapacity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of borrowing capacity currently available under the credit facility (current borrowing capacity less the amount of borrowings outstanding). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityRemainingBorrowingCapacity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

v3.19.3

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
Entergy Arkansas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
Entergy Louisiana [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
Entergy Mississippi [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
Entergy New Orleans [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
Entergy Texas [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.
System Energy [Member]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES  (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein. Vidalia Purchased Power Agreement See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement. ANO Damage, Outage, and NRC Reviews See Note 8 to the financial statements in the Form 10-K for a discussion of the ANO stator incident, subsequent NRC reviews, and the deferral of replacement power costs. Pilgrim NRC Oversight and Shutdown See Note 8 to the financial statements in the Form 10-K for a discussion of the NRC’s enhanced inspections of Pilgrim and Entergy’s shutdown of Pilgrim. In March 2019 the NRC moved Pilgrim from its “multiple/repetitive degraded cornerstone column,” or Column 4, of its Reactor Oversight Process Action Matrix to its “licensee response column,” or Column 1. Pilgrim ceased operations in May 2019. In June 2019, following permanent defueling of the reactor,     Pilgrim was removed from the NRC’s Reactor Oversight Process and is now subject to the NRC’s normal decommissioning inspection program. In August 2019 the NRC approved the transfer of the Pilgrim operating license from Entergy to Holtec and the transaction closed on August 26, 2019. See Note 16 to the financial statements herein for further discussion of the sale of Pilgrim. Spent Nuclear Fuel Litigation See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion. In August 2019 the U.S. Court of Federal Claims issued a final judgment in the amount of $19 million in favor of Entergy Louisiana against the DOE in the second round River Bend damages case. Entergy Louisiana received payment from the U.S. Treasury in September 2019. The effects of recording the judgment were reductions to plant, nuclear fuel expense, and other operation and maintenance expense. The River Bend damages awarded included $12 million related to costs previously recorded as nuclear fuel expense, $5 million related to costs previously recorded as other operation and maintenance expense, and $2 million in costs previously capitalized. Nuclear Insurance See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.   Non-Nuclear Property Insurance See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program. Employment and Labor-related Proceedings See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings. Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas) See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation. Grand Gulf-Related Agreements See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements. The following is an update to that discussion. Capital Funds Agreement (Entergy Corporation and System Energy) Pursuant to the terms of the Capital Funds Agreement, Entergy Corporation had agreed to supply System Energy with sufficient capital to (i) maintain System Energy’s equity capital at an amount equal to a minimum of 35% of its total capitalization (excluding short-term debt), (ii) permit the continued commercial operation of Grand Gulf, and (iii) pay in full when due all indebtedness for borrowed money of System Energy. Effective July 19, 2019, the Capital Funds Agreement was terminated.

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v3.19.3

Rate And Regulatory Matters Rate and Regulatory Matters (Tables)	9 Months Ended
	Sep. 30, 2019
Entergy Arkansas [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Arkansas [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Louisiana [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Louisiana [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Mississippi [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Mississippi [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy New Orleans [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy New Orleans [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6
Entergy Texas [Member] | FERC December 2015 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)
Entergy Texas [Member] | FERC May 2018 Order [Member]
Payments Or Receipts Among Utility Operating Companies Related to System Agreement Proceedings [Table Text Block]	The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6

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v3.19.3

Revenue Recognition	9 Months Ended
	Sep. 30, 2019
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Arkansas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Louisiana [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Mississippi [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy New Orleans [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Texas [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
System Energy [Member]
Revenue Recognition	REVENUE RECOGNITION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970 The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

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- Definition The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 606 -URI http://asc.fasb.org/topic&trid=49130388 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -URI http://asc.fasb.org/topic&trid=2122369 + Details Name: us-gaap_RevenueFromContractWithCustomerTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Retirement And Other Postretirement Benefits (Tables)	9 Months Ended
	Sep. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813
Entergy Arkansas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Arkansas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )
Entergy Arkansas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Reclassification out of Accumulated Other Comprehensive Income, amortization	Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032
Entergy Louisiana [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Louisiana [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )
Entergy Louisiana [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
Entergy Mississippi [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Mississippi [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )
Entergy Mississippi [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
Entergy New Orleans [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy New Orleans [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )
Entergy New Orleans [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
Entergy Texas [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Texas [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )
Entergy Texas [Member] | Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan.
System Energy [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181
Expected Employer Contributions	Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
System Energy [Member] | Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Components Of Net Pension Cost	The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 )

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v3.19.3

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Securitization property	$ 268,177	$ 360,790
Securitization bonds	$ 338,408	$ 423,858
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	500,000,000	500,000,000
Common stock, shares issued	270,035,180	261,587,009
Treasury stock, shares	70,947,950	72,530,866
Entergy Arkansas [Member]
Securitization property	$ 4,596	$ 14,329
Securitization bonds	14,016	20,898
Entergy Louisiana [Member]
Securitization property	32,939	49,753
Securitization bonds	45,386	55,682
Entergy New Orleans [Member]
Securitization property	52,085	60,453
Securitization bonds	58,382	63,620
Entergy Texas [Member]
Securitization property	178,558	236,336
Securitization bonds	$ 220,625	$ 283,659
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares issued	46,525,000	46,525,000
Common stock, shares outstanding	46,525,000	46,525,000
System Energy [Member]
Common stock, shares authorized	1,000,000	1,000,000
Common stock, shares issued	789,350	789,350
Common stock, shares outstanding	789,350	789,350

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v3.19.3

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 31, 2019
Entity Registrant Name	ENTERGY CORPORATION
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	72-1229752
Entity File Number	1-11299
Entity Central Index Key	0000065984
Document Type	10-Q
Document Period End Date	Sep. 30, 2019
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Incorporation, State or Country Code	DE
Entity Address, State or Province	639 Loyola Avenue
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Country	US
Entity Address, Postal Zip Code	70113
Entity Common Stock, Shares Outstanding		199,102,083
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Document Quarterly Report	true
Document Transition Report	false
NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETR
Security Exchange Name	NYSE
Title of 12(b) Security	Common Stock, $0.01 Par Value
CHICAGO STOCK EXCHANGE, INC [Member]
Trading Symbol	ETR
Security Exchange Name	CHX
Title of 12(b) Security	Common Stock, $0.01 Par Value
Entergy Arkansas [Member]
Entity Registrant Name	ENTERGY ARKANSAS, LLC
City Area Code	501
Local Phone Number	377-4000
Entity Tax Identification Number	83-1918668
Entity File Number	1-10764
Entity Central Index Key	0000007323
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	425 West Capitol Avenue
Entity Address, City or Town	Little Rock
Entity Address, State or Province	AR
Entity Address, Country	US
Entity Address, Postal Zip Code	72201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Louisiana [Member]
Entity Registrant Name	ENTERGY LOUISIANA, LLC
City Area Code	504
Local Phone Number	576-4000
Entity Tax Identification Number	47-4469646
Entity File Number	1-32718
Entity Central Index Key	0001348952
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	4809 Jefferson Highway
Entity Address, City or Town	Jefferson
Entity Address, State or Province	LA
Entity Address, Country	US
Entity Address, Postal Zip Code	70121
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Mississippi [Member]
Entity Registrant Name	ENTERGY MISSISSIPPI, LLC
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	83-1950019
Entity File Number	1-31508
Entity Central Index Key	0000066901
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	308 East Pearl Street
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Country	US
Entity Address, Postal Zip Code	39201
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy New Orleans [Member]
Entity Registrant Name	ENTERGY NEW ORLEANS, LLC
City Area Code	504
Local Phone Number	670-3700
Entity Tax Identification Number	82-2212934
Entity File Number	1-35747
Entity Central Index Key	0000071508
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	1600 Perdido Street
Entity Address, City or Town	New Orleans
Entity Address, State or Province	LA
Entity Address, Country	US
Entity Address, Postal Zip Code	70112
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entergy Texas [Member]
Entity Registrant Name	ENTERGY TEXAS, INC.
City Area Code	409
Local Phone Number	981-2000
Entity Tax Identification Number	61-1435798
Entity File Number	1-34360
Entity Central Index Key	0001427437
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	TX
Entity Address, State or Province	10055 Grogans Mill Road
Entity Address, City or Town	The Woodlands
Entity Address, State or Province	TX
Entity Address, Country	US
Entity Address, Postal Zip Code	77380
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
System Energy [Member]
Entity Registrant Name	SYSTEM ENERGY RESOURCES, INC.
City Area Code	601
Local Phone Number	368-5000
Entity Tax Identification Number	72-0752777
Entity File Number	1-09067
Entity Central Index Key	0000202584
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Incorporation, State or Country Code	AR
Entity Address, State or Province	1340 Echelon Parkway
Entity Address, City or Town	Jackson
Entity Address, State or Province	MS
Entity Address, Country	US
Entity Address, Postal Zip Code	39213
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Shell Company	false
Entity Interactive Data Current	Yes
Five Point Six Two Five Percent Series First Mortgage Bonds Due June Two Thousand Sixty Four [Member] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EZT
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.625% Series due June 2064
Mortgage Bonds, Five Point Five Percent Series, Due April Two Thousand Sixty Six [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENO
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.50% Series due April 2066
Mortgage Bonds 5.0 Series Due December Two Thousand Fifty Two [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ENJ
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.0% Series due December 2052
Mortgage Bonds, Four Point Nine Zero Percent Series, Due October Two Thousand Sixty Six [Member] | Entergy Mississippi [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EMP
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due October 2066
Mortgage Bonds Four Point Seven Percent Series Due June Two Thousand Sixty Three [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELU
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.70% Series due June 2063
Mortgage Bonds Five Point Two Five Percent Series Due July Two Thousand Fifty Two [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELJ
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 5.25% Series due July 2052
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAI
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Four Point Eight Seven Five Percent Series First Mortgage Bonds Due September Two Thousand Sixty Six [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ELC
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.875% Series due September 2066
Mortgage Bonds Four Point Seven Five Percent Series Due June Two Thousand Sixty Three [Member] [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAE
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.75% Series due June 2063
Mortgage Bonds Four Point Nine Percent Series Due Decembertwenty Fifty Two [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	EAB
Security Exchange Name	NYSE
Title of 12(b) Security	Mortgage Bonds, 4.90% Series due December 2052
5.375% Series A Preferred Stock, Cumulative, No Par Value [Domain] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]
Trading Symbol	ETI/PR
Security Exchange Name	NYSE
Title of 12(b) Security	5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)

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v3.19.3

Rate And Regulatory Matters Rate and Regulatory Matters (Payments/Receipts Among The Utility Operating Companies) (Details) - USD ($) $ in Millions	1 Months Ended
	Jul. 31, 2018	Feb. 29, 2016
Entergy Arkansas [Member]
Receipts from utility operating companies pursuant to FERC order	$ (4.2)
FERC May 2018 Order [Member] | Entergy Arkansas [Member]
Receipts from utility operating companies pursuant to FERC order	(4.0)
FERC May 2018 Order [Member] | Entergy Louisiana [Member]
Receipts from utility operating companies pursuant to FERC order	(23.0)
FERC May 2018 Order [Member] | Entergy Mississippi [Member]
Payments to utility operating companies pursuant to FERC order	16.0
FERC May 2018 Order [Member] | Entergy New Orleans [Member]
Payments to utility operating companies pursuant to FERC order	5.0
FERC May 2018 Order [Member] | Entergy Texas [Member]
Payments to utility operating companies pursuant to FERC order	$ 6.0
FERC December 2015 Order [Member] | Entergy Arkansas [Member]
Payments to utility operating companies pursuant to FERC order		$ 2.0
FERC December 2015 Order [Member] | Entergy Louisiana [Member]
Payments to utility operating companies pursuant to FERC order		6.0
FERC December 2015 Order [Member] | Entergy Mississippi [Member]
Receipts from utility operating companies pursuant to FERC order		(4.0)
FERC December 2015 Order [Member] | Entergy New Orleans [Member]
Receipts from utility operating companies pursuant to FERC order		(1.0)
FERC December 2015 Order [Member] | Entergy Texas [Member]
Receipts from utility operating companies pursuant to FERC order		$ (3.0)

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v3.19.3

Business Segment Information (Tables) - Entergy Corporation [Member]	9 Months Ended
	Sep. 30, 2019
Segment Financial Information	Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.
Restructuring and Related Costs [Table Text Block]	Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions.

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v3.19.3

Revenue Recognition Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2019
Disaggregation of Revenue [Table Text Block]	Entergy’s total revenues for the three months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $1,154,455   $1,138,744 Commercial   722,334   693,760 Industrial   686,122   682,823 Governmental   61,697   60,647     Total billed retail   2,624,608   2,575,974           Sales for resale (a)   63,082   76,247 Other electric revenues (b)   115,352   42,847 Non-customer revenues (c)   9,892   2,819     Total electric revenues   2,812,934   2,697,887           Natural gas   27,269   26,352           Entergy Wholesale Commodities:         Competitive businesses sales (a)   282,420   407,763 Non-customer revenues (c)   17,952   (27,683 )     Total competitive businesses   300,372   380,080               Total operating revenues   $3,140,575   $3,104,319 Entergy’s total revenues for the nine months ended September 30, 2019 and 2018 are as follows:     2019   2018     (In Thousands) Utility:         Residential   $2,727,367   $2,799,539 Commercial   1,871,416   1,871,380 Industrial   1,928,857   1,904,828 Governmental   172,280   173,949     Total billed retail   6,699,920   6,749,696           Sales for resale (a)   222,834   214,984 Other electric revenues (b)   326,771   289,668 Non-customer revenues (c)   30,158   22,026     Total electric revenues   7,279,683   7,276,374           Natural gas   112,916   112,990           Entergy Wholesale Commodities:         Competitive businesses sales (a)   923,288   1,148,460 Non-customer revenues (c)   100,480   (40,854 )     Total competitive businesses   1,023,768   1,107,606               Total operating revenues   $8,416,367   $8,496,970
Entergy Arkansas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Louisiana [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Mississippi [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy New Orleans [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
Entergy Texas [Member]
Disaggregation of Revenue [Table Text Block]	The Registrant Subsidiaries’ total revenues for the three months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $253,627   $426,012   $177,785   $81,468   $215,563 Commercial   162,564   277,071   131,596   56,430   94,673 Industrial   156,024   376,595   44,054   8,613   100,836 Governmental   5,907   18,731   12,551   19,030   5,478     Total billed retail   578,122 1,098,409 365,986 165,541 416,550                       Sales for resale (a)   58,953   81,664   9,569   6,876   16,704 Other electric revenues (b)   47,085   37,521   20,499   2,537   9,177 Non-customer revenues (c)   3,366   4,280   2,678   1,784   446     Total electric revenues   687,526 1,221,874 398,732 176,738 442,877                       Natural gas   —   9,803   —   17,466   —                           Total operating revenues   $687,526 $1,231,677 $398,732 $194,204 $442,877 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $250,081   $408,680   $170,258   $86,014   $223,711 Commercial   119,950   272,985   126,987   62,428   111,409 Industrial   126,079   393,884   44,383   9,655   108,823 Governmental   4,445   17,566   11,488   20,364   6,785     Total billed retail   500,555   1,093,115   353,116   178,461   450,728                       Sales for resale (a)   60,338   71,634   7,876   4,863   23,290 Other electric revenues (b)   4,446   34,220   4,079   (1,107 )   2,735 Non-customer revenues (c)   3,060   (2,691 )   2,663   1,947   478     Total electric revenues   568,399   1,196,278   367,734   184,164   477,231                       Natural gas   —   10,334   —   16,018   —                           Total operating revenues   $568,399   $1,206,612   $367,734   $200,182   $477,231 The Registrant Subsidiaries’ total revenues for the nine months ended September 30, 2019 and 2018 were as follows: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $621,208   $980,443   $423,395   $192,165   $510,156 Commercial   412,697   715,983   331,785   156,152   254,799 Industrial   396,515   1,108,193   120,490   24,353   279,306 Governmental   15,776   53,547   33,108   53,916   15,933     Total billed retail   1,446,196   2,858,166   908,778   426,586   1,060,194                       Sales for resale (a)   213,038   248,827   19,377   25,680   48,251 Other electric revenues (b)   107,599   130,269   47,887   8,093   37,329 Non-customer revenues (c)   9,434   15,564   7,671   4,414   1,157     Total electric revenues   1,776,267   3,252,826   983,713   464,773   1,146,931                       Natural gas   —   44,498   —   68,418   —                           Total operating revenues   $1,776,267   $3,297,324   $983,713   $533,191   $1,146,931      2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Residential   $644,735   $972,113   $451,331   $208,821   $522,539 Commercial   334,325   719,652   354,799   171,224   291,380 Industrial   335,529   1,114,898   133,012   26,493   294,896 Governmental   12,859   51,581   33,788   56,503   19,218     Total billed retail   1,327,448   2,858,244   972,930   463,041   1,128,033                       Sales for resale (a)   179,637   272,690   21,645   24,390   71,828 Other electric revenues (b)   98,571   124,749   35,055   7,404   28,468 Non-customer revenues (c)   8,372   7,390   7,536   4,749   1,328     Total electric revenues   1,614,028   3,263,073   1,037,166   499,584   1,229,657                       Natural gas   —   45,671   —   67,319   —                           Total operating revenues   $1,614,028   $3,308,744   $1,037,166   $566,903   $1,229,657 (a) Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments, and includes them as part of customer revenues. (b) Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue. (c) Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

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v3.19.3

Decommissioning Trust Funds	9 Months Ended
	Sep. 30, 2019
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million. As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 million. Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for Indian Point 1, Indian Point 2, Indian Point 3, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities (a)   $2,462   $114   $2               2018             Debt Securities (a)   $2,495   $19   $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.15%, an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $236   $2 More than 12 months   67   — Total   $303   $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $652   $9 More than 12 months 782   26 Total $1,434   $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $165   $199 1 year - 5 years 870   1,066 5 years - 10 years 636   544 10 years - 15 years 89   77 15 years - 20 years 98   78 20 years+ 604   531 Total $2,462   $2,495 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $11 million and $4 million, respectively, and gross losses of $0.4 million and $15 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $20 million and $6 million, respectively, and gross losses of $3 million and $37 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $407.7   $11.8   $0.9               2018             Debt Securities   $381.3   $0.6   $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 2.78%, an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $51.5   $0.8 More than 12 months   21.0   0.1 Total   $72.5   $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $65.8   $0.5 More than 12 months 231.1   7.7 Total $296.9   $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $50.3   $32.5 1 year - 5 years 120.4   170.3 5 years - 10 years 144.5   114.0 10 years - 15 years 24.3   10.3 15 years - 20 years 14.2   8.1 20 years+ 54.0   46.1 Total $407.7   $381.3 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2 million and $0.01 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $2.1 million and $0.1 million, respectively, and gross losses of $0.1 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $593.4   $32.6   $0.3               2018             Debt Securities   $532.9   $4.1   $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018.  As of September 30, 2019, the available-for-sale debt securities have an average coupon rate of approximately 3.85%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $49.3   $0.3 More than 12 months   12.9   — Total   $62.2   $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $170.1   $2.1 More than 12 months 145.8   3.9 Total $315.9   $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $56.6   $31.1 1 year - 5 years 138.2   130.5 5 years - 10 years 118.4   111.0 10 years - 15 years 34.7   29.0 15 years - 20 years 45.0   37.1 20 years+ 200.5   194.2 Total $593.4   $532.9 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2.5 million and $1.9 million, respectively, and gross losses of $29 thousand and $3.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $4.2 million and $2.5 million, respectively, and gross losses of $0.2 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $395.3   $19.7   $0.1               2018             Debt Securities   $364.2   $2.9   $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.09%, an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months   $38.8   $0.1 More than 12 months   4.3   — Total   $43.1   $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $89.7   $2.4 More than 12 months 79.8   3.4 Total $169.5   $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $11.2   $22.8 1 year - 5 years 187.7   188.0 5 years - 10 years 92.7   73.4 10 years - 15 years 3.0   5.2 15 years - 20 years 5.9   10.2 20 years+ 94.8   64.6 Total $395.3   $364.2 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $1.7 million and $6.5 thousand, respectively, and gross losses of $0.2 million and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $3.6 million and $0.3 million, respectively, and gross losses of $0.6 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
Entergy Arkansas [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million. As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 million. Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for Indian Point 1, Indian Point 2, Indian Point 3, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities (a)   $2,462   $114   $2               2018             Debt Securities (a)   $2,495   $19   $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.15%, an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $236   $2 More than 12 months   67   — Total   $303   $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $652   $9 More than 12 months 782   26 Total $1,434   $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $165   $199 1 year - 5 years 870   1,066 5 years - 10 years 636   544 10 years - 15 years 89   77 15 years - 20 years 98   78 20 years+ 604   531 Total $2,462   $2,495 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $11 million and $4 million, respectively, and gross losses of $0.4 million and $15 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $20 million and $6 million, respectively, and gross losses of $3 million and $37 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $407.7   $11.8   $0.9               2018             Debt Securities   $381.3   $0.6   $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 2.78%, an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $51.5   $0.8 More than 12 months   21.0   0.1 Total   $72.5   $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $65.8   $0.5 More than 12 months 231.1   7.7 Total $296.9   $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $50.3   $32.5 1 year - 5 years 120.4   170.3 5 years - 10 years 144.5   114.0 10 years - 15 years 24.3   10.3 15 years - 20 years 14.2   8.1 20 years+ 54.0   46.1 Total $407.7   $381.3 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2 million and $0.01 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $2.1 million and $0.1 million, respectively, and gross losses of $0.1 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $593.4   $32.6   $0.3               2018             Debt Securities   $532.9   $4.1   $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018.  As of September 30, 2019, the available-for-sale debt securities have an average coupon rate of approximately 3.85%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $49.3   $0.3 More than 12 months   12.9   — Total   $62.2   $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $170.1   $2.1 More than 12 months 145.8   3.9 Total $315.9   $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $56.6   $31.1 1 year - 5 years 138.2   130.5 5 years - 10 years 118.4   111.0 10 years - 15 years 34.7   29.0 15 years - 20 years 45.0   37.1 20 years+ 200.5   194.2 Total $593.4   $532.9 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2.5 million and $1.9 million, respectively, and gross losses of $29 thousand and $3.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $4.2 million and $2.5 million, respectively, and gross losses of $0.2 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $395.3   $19.7   $0.1               2018             Debt Securities   $364.2   $2.9   $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.09%, an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months   $38.8   $0.1 More than 12 months   4.3   — Total   $43.1   $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $89.7   $2.4 More than 12 months 79.8   3.4 Total $169.5   $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $11.2   $22.8 1 year - 5 years 187.7   188.0 5 years - 10 years 92.7   73.4 10 years - 15 years 3.0   5.2 15 years - 20 years 5.9   10.2 20 years+ 94.8   64.6 Total $395.3   $364.2 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $1.7 million and $6.5 thousand, respectively, and gross losses of $0.2 million and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $3.6 million and $0.3 million, respectively, and gross losses of $0.6 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
Entergy Louisiana [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million. As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 million. Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for Indian Point 1, Indian Point 2, Indian Point 3, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities (a)   $2,462   $114   $2               2018             Debt Securities (a)   $2,495   $19   $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.15%, an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $236   $2 More than 12 months   67   — Total   $303   $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $652   $9 More than 12 months 782   26 Total $1,434   $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $165   $199 1 year - 5 years 870   1,066 5 years - 10 years 636   544 10 years - 15 years 89   77 15 years - 20 years 98   78 20 years+ 604   531 Total $2,462   $2,495 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $11 million and $4 million, respectively, and gross losses of $0.4 million and $15 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $20 million and $6 million, respectively, and gross losses of $3 million and $37 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $407.7   $11.8   $0.9               2018             Debt Securities   $381.3   $0.6   $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 2.78%, an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $51.5   $0.8 More than 12 months   21.0   0.1 Total   $72.5   $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $65.8   $0.5 More than 12 months 231.1   7.7 Total $296.9   $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $50.3   $32.5 1 year - 5 years 120.4   170.3 5 years - 10 years 144.5   114.0 10 years - 15 years 24.3   10.3 15 years - 20 years 14.2   8.1 20 years+ 54.0   46.1 Total $407.7   $381.3 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2 million and $0.01 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $2.1 million and $0.1 million, respectively, and gross losses of $0.1 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $593.4   $32.6   $0.3               2018             Debt Securities   $532.9   $4.1   $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018.  As of September 30, 2019, the available-for-sale debt securities have an average coupon rate of approximately 3.85%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $49.3   $0.3 More than 12 months   12.9   — Total   $62.2   $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $170.1   $2.1 More than 12 months 145.8   3.9 Total $315.9   $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $56.6   $31.1 1 year - 5 years 138.2   130.5 5 years - 10 years 118.4   111.0 10 years - 15 years 34.7   29.0 15 years - 20 years 45.0   37.1 20 years+ 200.5   194.2 Total $593.4   $532.9 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2.5 million and $1.9 million, respectively, and gross losses of $29 thousand and $3.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $4.2 million and $2.5 million, respectively, and gross losses of $0.2 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $395.3   $19.7   $0.1               2018             Debt Securities   $364.2   $2.9   $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.09%, an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months   $38.8   $0.1 More than 12 months   4.3   — Total   $43.1   $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $89.7   $2.4 More than 12 months 79.8   3.4 Total $169.5   $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $11.2   $22.8 1 year - 5 years 187.7   188.0 5 years - 10 years 92.7   73.4 10 years - 15 years 3.0   5.2 15 years - 20 years 5.9   10.2 20 years+ 94.8   64.6 Total $395.3   $364.2 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $1.7 million and $6.5 thousand, respectively, and gross losses of $0.2 million and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $3.6 million and $0.3 million, respectively, and gross losses of $0.6 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.
System Energy [Member]
Decommissioning Trust Funds	DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) The NRC requires Entergy subsidiaries to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1, ANO 2, River Bend, Waterford 3, Grand Gulf, Indian Point 1, Indian Point 2, Indian Point 3, and Palisades. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents. As discussed in Note 16 to the financial statements herein and Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy completed the transfer of the Vermont Yankee plant to NorthStar. As part of the transaction, Entergy transferred the Vermont Yankee decommissioning trust fund to NorthStar. As of December 31, 2018, the fair value of the decommissioning trust fund was $532 million. As discussed in Note 16 to the financial statements herein, in August 2019, Entergy completed the transfer of the Pilgrim plant to Holtec. As part of the transaction, Entergy transferred the Pilgrim decommissioning trust fund to Holtec. The disposition-date fair value of the decommissioning trust fund was approximately $1,030 million. Entergy records decommissioning trust funds on the balance sheet at their fair value.  Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) on investment securities in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other deferred credits for the unrealized trust earnings not currently expected to be needed to decommission the plant.  Decommissioning trust funds for Indian Point 1, Indian Point 2, Indian Point 3, and Palisades do not meet the criteria for regulatory accounting treatment.  Accordingly, unrealized gains/(losses) recorded on the equity securities in the trust funds are recognized in earnings. Unrealized gains recorded on the available-for-sale debt securities in the trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity.  Unrealized losses (where cost exceeds fair market value) on the available-for-sale debt securities in the trust funds are also recorded in the accumulated other comprehensive income component of shareholders’ equity unless the unrealized loss is other than temporary and therefore recorded in earnings. A portion of Entergy’s decommissioning trust funds are held in a wholly-owned registered investment company, and unrealized gains and losses on both the equity and debt securities held in the registered investment company are recognized in earnings. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $17 million and $491 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index or the Russell 3000 Index. The debt securities are generally held in individual government and credit issuances. The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities (a)   $2,462   $114   $2               2018             Debt Securities (a)   $2,495   $19   $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale. The unrealized gains/(losses) above are reported before deferred taxes of $16 million as of September 30, 2019 and ($1) million as of December 31, 2018 for debt securities. The amortized cost of available-for-sale debt securities was $2,362 million as of September 30, 2019 and $2,511 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.15%, an average duration of approximately 5.63 years, and an average maturity of approximately 9.02 years. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $236   $2 More than 12 months   67   — Total   $303   $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $652   $9 More than 12 months 782   26 Total $1,434   $35 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $165   $199 1 year - 5 years 870   1,066 5 years - 10 years 636   544 10 years - 15 years 89   77 15 years - 20 years 98   78 20 years+ 604   531 Total $2,462   $2,495 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $407 million and $2,377 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $11 million and $4 million, respectively, and gross losses of $0.4 million and $15 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $1,133 million and $4,178 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $20 million and $6 million, respectively, and gross losses of $3 million and $37 million, respectively, related to available-for-sale securities were reclassified out of other comprehensive income or other regulatory liabilities/assets into earnings. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of September 30, 2019 are $534 million for Indian Point 1, $676 million for Indian Point 2, $893 million for Indian Point 3, and $492 million for Palisades. The fair values of the decommissioning trust funds related to the Entergy Wholesale Commodities nuclear plants as of December 31, 2018 are $471 million for Indian Point 1, $598 million for Indian Point 2, $781 million for Indian Point 3, $444 million for Palisades, $1,028 million for Pilgrim, and $532 million for Vermont Yankee. The fair values of the decommissioning trust funds for the Registrant Subsidiaries’ nuclear plants are detailed below. Entergy Arkansas Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $407.7   $11.8   $0.9               2018             Debt Securities   $381.3   $0.6   $8.2 The amortized cost of available-for-sale debt securities was $396.8 million as of September 30, 2019 and $389 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 2.78%, an average duration of approximately 5.57 years, and an average maturity of approximately 8.13 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.6 million and $96.5 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $51.5   $0.8 More than 12 months   21.0   0.1 Total   $72.5   $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $65.8   $0.5 More than 12 months 231.1   7.7 Total $296.9   $8.2 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $50.3   $32.5 1 year - 5 years 120.4   170.3 5 years - 10 years 144.5   114.0 10 years - 15 years 24.3   10.3 15 years - 20 years 14.2   8.1 20 years+ 54.0   46.1 Total $407.7   $381.3 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $45.5 million and $137.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2 million and $0.01 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2018, gross losses of $0.6 million related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the three months ended September 30, 2019, there were no gross losses. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $78.7 million and $259.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $2.1 million and $0.1 million, respectively, and gross losses of $0.1 million and $3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Entergy Louisiana Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $593.4   $32.6   $0.3               2018             Debt Securities   $532.9   $4.1   $6.0 The amortized cost of available-for-sale debt securities was $561 million as of September 30, 2019 and $534.8 million as of December 31, 2018.  As of September 30, 2019, the available-for-sale debt securities have an average coupon rate of approximately 3.85%, an average duration of approximately 6.53 years, and an average maturity of approximately 13.11 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $6 million and $137.2 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $49.3   $0.3 More than 12 months   12.9   — Total   $62.2   $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $170.1   $2.1 More than 12 months 145.8   3.9 Total $315.9   $6.0 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $56.6   $31.1 1 year - 5 years 138.2   130.5 5 years - 10 years 118.4   111.0 10 years - 15 years 34.7   29.0 15 years - 20 years 45.0   37.1 20 years+ 200.5   194.2 Total $593.4   $532.9 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $59.7 million and $773.9 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $2.5 million and $1.9 million, respectively, and gross losses of $29 thousand and $3.6 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $155.4 million and $943.3 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $4.2 million and $2.5 million, respectively, and gross losses of $0.2 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. System Energy System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $395.3   $19.7   $0.1               2018             Debt Securities   $364.2   $2.9   $5.8 The amortized cost of available-for-sale debt securities was $375.6 million as of September 30, 2019 and $367.1 million as of December 31, 2018.  As of September 30, 2019, available-for-sale debt securities have an average coupon rate of approximately 3.09%, an average duration of approximately 6.84 years, and an average maturity of approximately 9.88 years. The unrealized gains/(losses) recognized during the three and nine months ended September 30, 2019 on equity securities still held as of September 30, 2019 were $2.5 million and $91.8 million, respectively. The equity securities are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index. The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months   $38.8   $0.1 More than 12 months   4.3   — Total   $43.1   $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $89.7   $2.4 More than 12 months 79.8   3.4 Total $169.5   $5.8 The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $11.2   $22.8 1 year - 5 years 187.7   188.0 5 years - 10 years 92.7   73.4 10 years - 15 years 3.0   5.2 15 years - 20 years 5.9   10.2 20 years+ 94.8   64.6 Total $395.3   $364.2 During the three months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $108.6 million and $157.8 million, respectively.  During the three months ended September 30, 2019 and 2018, gross gains of $1.7 million and $6.5 thousand, respectively, and gross losses of $0.2 million and $0.3 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. During the nine months ended September 30, 2019 and 2018, proceeds from the dispositions of available-for-sale securities amounted to $238.4 million and $357.2 million, respectively.  During the nine months ended September 30, 2019 and 2018, gross gains of $3.6 million and $0.3 million, respectively, and gross losses of $0.6 million and $4.8 million, respectively, related to available-for-sale securities were reclassified out of other regulatory liabilities/assets into earnings. Other-than-temporary impairments and unrealized gains and losses Entergy evaluates the available-for-sale debt securities in the Entergy Wholesale Commodities’ nuclear decommissioning trust funds with unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred.  The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs.  Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash flows expected to be collected less the amortized cost basis (credit loss).  Entergy did not have any material other-than-temporary impairments relating to credit losses on debt securities for the three and nine months ended September 30, 2019 and 2018.  Entergy’s trusts are managed by third parties who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases and sales of investments.

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- Definition Describes decommissioning trust assets. May include disclosures such as the purpose of the funds, funding requirements, regulatory authorities and related cost recovery aspects. + References No definition available. + Details Name: etr_DecommissioningTrustFundTextBlock Namespace Prefix: etr_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2019
Entergy Corporation [Member]
Stock-Based Compensation	STOCK-BASED COMPENSATION (Entergy Corporation) Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years. Stock Options Entergy granted options on 693,161 shares of its common stock under the 2015 Equity Ownership Plan during the first quarter 2019 with a fair value of $8.32 per option.  As of September 30, 2019, there were options on 2,515,896 shares of common stock outstanding with a weighted-average exercise price of $78.53.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted average exercise price of the stock options granted and Entergy Corporation’s common stock price as of September 30, 2019.  The aggregate intrinsic value of the stock options outstanding as of September 30, 2019 was $97.7 million. The following table includes financial information for outstanding stock options for the three months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $0.9   $1.1 Tax benefit recognized in Entergy’s net income $0.2   $0.2 Compensation cost capitalized as part of fixed assets and materials and supplies $0.4   $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $2.9   $3.3 Tax benefit recognized in Entergy’s net income $0.7   $0.8 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0   $0.5 Other Equity Awards In January 2019, the Board approved and Entergy granted 355,537 restricted stock awards and 180,824 long-term incentive awards under the 2015 Equity Ownership Plan.  The restricted stock awards were made effective as of January 31, 2019 and were valued at $89.19 per share, which was the closing price of Entergy’s common stock on that date.  One-third of the restricted stock awards will vest upon each anniversary of the grant date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. In addition, long-term incentive awards were also granted in the form of performance units that represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. For the 2019-2021 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on a cumulative adjusted earnings per share metric.  The performance units were granted as of January 31, 2019 and eighty percent were valued at $102.07 per share based on various factors, primarily market conditions; and twenty percent were valued at $89.19 per share, the closing price of Entergy’s common stock on that date.  Performance units have the same dividend rights as shares of Entergy common stock and are considered issued and outstanding shares of Entergy upon vesting. Performance units are expensed ratably over the three-year vesting period and compensation cost for the portion of the award based on cumulative adjusted earnings per share will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program. The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $8.4   $8.5 Tax benefit recognized in Entergy’s net income $2.1   $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $3.0   $2.5 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $25.6   $26.0 Tax benefit recognized in Entergy’s net income $6.5   $6.6 Compensation cost capitalized as part of fixed assets and materials and supplies $8.8   $7.3

X

- Definition The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -URI http://asc.fasb.org/topic&trid=2228938 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 50 -URI http://asc.fasb.org/subtopic&trid=2208855 + Details Name: us-gaap_DisclosureOfCompensationRelatedCostsShareBasedPaymentsTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Income Taxes Income Taxes (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Mar. 31, 2019	Sep. 30, 2019	Dec. 31, 2022	Dec. 31, 2021	Oct. 15, 2024
Discontinued Operation, Tax Effect of Discontinued Operation		$ 29
Entergy Arkansas [Member]
State Effective Income Tax Rate, Percent			6.50%
Regulatory Liability For Income Taxes - Current and Non Current	$ 25		$ 25
Entergy Arkansas [Member] | Subsequent Event [Member]
State Effective Income Tax Rate, Percent				5.90%	6.20%
Reduction to Effective Income Tax Rate At Combined Federal and State Income Tax Rate				0.50%
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Preferred Stock, Dividend Rate, Percentage	5.375%		5.375%
Preferred Stock, Liquidation Preference Per Share	$ 25		$ 25
Proceeds from Issuance of Preferred Stock and Preference Stock	$ 35		$ 35
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member] | Subsequent Event [Member]
Preferred Stock, Liquidation Preference Per Share						$ 25

X

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X

- Definition Amount of tax expense (benefit) related to a discontinued operation. Includes, but is not limited to, tax expense (benefit) related to income (loss) from operations during the phase-out period, tax expense (benefit) related to gain (loss) on disposal, tax expense (benefit) related to gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and tax expense (benefit) related to adjustments of a prior period gain (loss) on disposal. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 3B -URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721525-107759 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 20 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109238882&loc=d3e38679-109324 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 50 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=84230637&loc=d3e32672-109319 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109222160&loc=d3e1012-107759 Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1361-107760 Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 3A -URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721523-107759 Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 5C -Subparagraph (b)(2) -URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721675-107760 Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 5B -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721673-107760 + Details Name: us-gaap_DiscontinuedOperationTaxEffectOfDiscontinuedOperation Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Aggregate par or stated value of issued nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable preferred shares, par value and other disclosure concepts are in another section within stockholders' equity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(28)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_PreferredStockValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Leases Leases (Lease, Terms and Discount Rate) (Details)	Sep. 30, 2019
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 6 days
Finance Lease, Weighted Average Remaining Lease Term	6 years 9 months 14 days
Operating Lease, Weighted Average Discount Rate, Percent	3.91%
Finance Lease, Weighted Average Discount Rate, Percent	4.67%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 1 month 2 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.75%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 10 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.74%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.77%
Finance Lease, Weighted Average Discount Rate, Percent	3.71%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 8 months 19 days
Operating Lease, Weighted Average Discount Rate, Percent	3.94%
Finance Lease, Weighted Average Discount Rate, Percent	3.93%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 26 days
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months
Operating Lease, Weighted Average Discount Rate, Percent	3.86%
Finance Lease, Weighted Average Discount Rate, Percent	3.84%

X

- Definition Weighted average discount rate for finance lease calculated at point in time. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(4) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseWeightedAverageDiscountRatePercent Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

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- Definition Weighted average remaining lease term for finance lease, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents reported fact of one year, five months, and thirteen days. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(3) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseWeightedAverageRemainingLeaseTerm1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: instant

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- Definition Weighted average discount rate for operating lease calculated at point in time. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(4) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_OperatingLeaseWeightedAverageDiscountRatePercent Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

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- Definition Weighted average remaining lease term for operating lease, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents reported fact of one year, five months, and thirteen days. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(3) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 + Details Name: us-gaap_OperatingLeaseWeightedAverageRemainingLeaseTerm1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: instant

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v3.19.3

Leases Leases (Purchase Power Agreement Minimum Lease Payments) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		$ 31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	$ 59,965	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	53,791	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	45,391	10,180
Lessee, Operating Lease, Liability, Payments, Due	267,191	105,824
Entergy Texas [Member]
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months		31,159
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,014	31,876
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,279	32,609
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,338	10,180
Lessee, Operating Lease, Liability, Payments, Due	14,840	$ 105,824
Entergy Louisiana [Member]
Lessee, Operating Lease, Liability, Payments, Due Year Two	10,518
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,787
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,068
Lessee, Operating Lease, Liability, Payments, Due	$ 37,017

X

- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in fourth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearFour Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in third fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearThree Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575	$ 3,104,319	$ 8,416,367	$ 8,496,970
Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,812,934	2,697,887	7,279,683	7,276,374
Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	27,269	26,352	112,916	112,990
Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	300,372	380,080	1,023,768	1,107,606
Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,154,455	1,138,744	2,727,367	2,799,539
Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	722,334	693,760	1,871,416	1,871,380
Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	686,122	682,823	1,928,857	1,904,828
Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	61,697	60,647	172,280	173,949
Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	63,082	76,247	222,834	214,984
Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	115,352	42,847	326,771	289,668
Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,892	2,819	30,158	22,026
Non-Customer [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,952	(27,683)	100,480	(40,854)
Competitive Business Sales [Member] | Competitive Businesses [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	282,420	407,763	923,288	1,148,460
Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,624,608	2,575,974	6,699,920	6,749,696
Entergy Arkansas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Entergy Arkansas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Arkansas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	253,627	250,081	621,208	644,735
Entergy Arkansas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	162,564	119,950	412,697	334,325
Entergy Arkansas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	156,024	126,079	396,515	335,529
Entergy Arkansas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,907	4,445	15,776	12,859
Entergy Arkansas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	58,953	60,338	213,038	179,637
Entergy Arkansas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	47,085	4,446	107,599	98,571
Entergy Arkansas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	3,366	3,060	9,434	8,372
Entergy Arkansas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	578,122	500,555	1,446,196	1,327,448
Entergy Louisiana [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677	1,206,612	3,297,324	3,308,744
Entergy Louisiana [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,221,874	1,196,278	3,252,826	3,263,073
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,803	10,334	44,498	45,671
Entergy Louisiana [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	426,012	408,680	980,443	972,113
Entergy Louisiana [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	277,071	272,985	715,983	719,652
Entergy Louisiana [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	376,595	393,884	1,108,193	1,114,898
Entergy Louisiana [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	18,731	17,566	53,547	51,581
Entergy Louisiana [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	81,664	71,634	248,827	272,690
Entergy Louisiana [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	37,521	34,220	130,269	124,749
Entergy Louisiana [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	4,280	(2,691)	15,564	7,390
Entergy Louisiana [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,098,409	1,093,115	2,858,166	2,858,244
Entergy Mississippi [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Entergy Mississippi [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Mississippi [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	177,785	170,258	423,395	451,331
Entergy Mississippi [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	131,596	126,987	331,785	354,799
Entergy Mississippi [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	44,054	44,383	120,490	133,012
Entergy Mississippi [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	12,551	11,488	33,108	33,788
Entergy Mississippi [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,569	7,876	19,377	21,645
Entergy Mississippi [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	20,499	4,079	47,887	35,055
Entergy Mississippi [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,678	2,663	7,671	7,536
Entergy Mississippi [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	365,986	353,116	908,778	972,930
Entergy New Orleans [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	194,204	200,182	533,191	566,903
Entergy New Orleans [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	176,738	184,164	464,773	499,584
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	17,466	16,018	68,418	67,319
Entergy New Orleans [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	81,468	86,014	192,165	208,821
Entergy New Orleans [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	56,430	62,428	156,152	171,224
Entergy New Orleans [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	8,613	9,655	24,353	26,493
Entergy New Orleans [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	19,030	20,364	53,916	56,503
Entergy New Orleans [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	6,876	4,863	25,680	24,390
Entergy New Orleans [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	2,537	(1,107)	8,093	7,404
Entergy New Orleans [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	1,784	1,947	4,414	4,749
Entergy New Orleans [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	165,541	178,461	426,586	463,041
Entergy Texas [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Entergy Texas [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Texas [Member] | Residential [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	215,563	223,711	510,156	522,539
Entergy Texas [Member] | Commercial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	94,673	111,409	254,799	291,380
Entergy Texas [Member] | Industrial [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	100,836	108,823	279,306	294,896
Entergy Texas [Member] | Governmental [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	5,478	6,785	15,933	19,218
Entergy Texas [Member] | Sales for Resale [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	16,704	23,290	48,251	71,828
Entergy Texas [Member] | Other Electric [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	9,177	2,735	37,329	28,468
Entergy Texas [Member] | Non-Customer [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	446	478	1,157	1,328
Entergy Texas [Member] | Billed Retail [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	416,550	450,728	1,060,194	1,128,033
System Energy [Member] | Electricity [Member]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 145,472	$ 78,965	$ 424,585	$ 339,864

X

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v3.19.3

Retirement And Other Postretirement Benefits (Components Of Qualified Net Pension Cost) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	$ 33,553	$ 38,752	$ 100,766	$ 116,256
Interest cost on projected benefit obligation	73,261	66,854	221,114	200,562
Expected return on assets	(103,751)	(110,535)	(311,494)	(331,605)
Amortization of prior service cost (credit)	0	99	0	297
Amortization of loss	60,395	68,526	177,233	205,578
Net other postretirement benefit cost	79,749	63,696	205,210	191,088
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment	16,291	0	17,591	0
Pension Plans Defined Benefit [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	5,260	6,189	15,782	18,567
Interest cost on projected benefit obligation	14,175	13,004	42,525	39,012
Expected return on assets	(20,177)	(21,851)	(60,529)	(65,553)
Amortization of loss	11,840	13,412	35,522	40,236
Net other postretirement benefit cost	11,098	10,754	33,300	32,262
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	7,284	8,446	21,852	25,338
Interest cost on projected benefit obligation	15,882	14,940	47,646	44,820
Expected return on assets	(22,651)	(24,809)	(67,955)	(74,427)
Amortization of loss	11,643	14,450	34,929	43,350
Net other postretirement benefit cost	12,158	13,027	36,472	39,081
Pension Plans Defined Benefit [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,629	1,822	4,887	5,466
Interest cost on projected benefit obligation	4,068	3,769	12,204	11,307
Expected return on assets	(5,969)	(6,502)	(17,905)	(19,506)
Amortization of loss	3,104	3,610	9,313	10,830
Net other postretirement benefit cost	2,832	2,699	8,499	8,097
Pension Plans Defined Benefit [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	568	673	1,706	2,019
Interest cost on projected benefit obligation	1,873	1,813	5,621	5,439
Expected return on assets	(2,696)	(2,993)	(8,089)	(8,979)
Amortization of loss	1,529	1,954	4,588	5,862
Net other postretirement benefit cost	1,274	1,447	3,826	4,341
Pension Plans Defined Benefit [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,350	1,589	4,050	4,767
Interest cost on projected benefit obligation	3,613	3,348	10,837	10,044
Expected return on assets	(5,862)	(6,523)	(17,586)	(19,569)
Amortization of loss	2,334	2,626	7,002	7,878
Net other postretirement benefit cost	1,435	1,040	4,303	3,120
Pension Plans Defined Benefit [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,549	1,776	4,649	5,328
Interest cost on projected benefit obligation	3,364	3,227	10,091	9,681
Expected return on assets	(4,678)	(4,991)	(14,032)	(14,973)
Amortization of loss	2,850	3,715	8,550	11,145
Net other postretirement benefit cost	3,085	3,727	9,258	11,181
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	4,675	6,782	14,025	20,346
Interest cost on projected benefit obligation	11,975	12,681	35,925	38,043
Expected return on assets	(9,562)	(10,373)	(28,686)	(31,119)
Amortization of prior service cost (credit)	(8,844)	(9,251)	(26,532)	(27,753)
Amortization of loss	358	3,432	1,074	10,296
Net other postretirement benefit cost	(1,398)	3,271	(4,194)	9,813
Other Postretirement [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	591	793	1,773	2,379
Interest cost on projected benefit obligation	1,807	1,997	5,421	5,991
Expected return on assets	(3,991)	(4,342)	(11,973)	(13,026)
Amortization of prior service cost (credit)	(1,238)	(1,278)	(3,714)	(3,834)
Amortization of loss	144	289	432	867
Net other postretirement benefit cost	(2,687)	(2,541)	(8,061)	(7,623)
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	1,160	1,556	3,480	4,668
Interest cost on projected benefit obligation	2,666	2,789	7,998	8,367
Expected return on assets	0	0	0	0
Amortization of prior service cost (credit)	(1,837)	(1,934)	(5,511)	(5,802)
Amortization of loss	(174)	388	(522)	1,164
Net other postretirement benefit cost	1,815	2,799	5,445	8,397
Other Postretirement [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	262	321	786	963
Interest cost on projected benefit obligation	670	683	2,010	2,049
Expected return on assets	(1,199)	(1,303)	(3,597)	(3,909)
Amortization of prior service cost (credit)	(439)	(456)	(1,317)	(1,368)
Amortization of loss	181	377	543	1,131
Net other postretirement benefit cost	(525)	(378)	(1,575)	(1,134)
Other Postretirement [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	92	129	276	387
Interest cost on projected benefit obligation	395	417	1,185	1,251
Expected return on assets	(1,237)	(1,313)	(3,711)	(3,939)
Amortization of prior service cost (credit)	(171)	(186)	(513)	(558)
Amortization of loss	58	34	174	102
Net other postretirement benefit cost	(863)	(919)	(2,589)	(2,757)
Other Postretirement [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	236	330	708	990
Interest cost on projected benefit obligation	854	939	2,562	2,817
Expected return on assets	(2,276)	(2,446)	(6,828)	(7,338)
Amortization of prior service cost (credit)	(561)	(579)	(1,683)	(1,737)
Amortization of loss	121	206	363	618
Net other postretirement benefit cost	(1,626)	(1,550)	(4,878)	(4,650)
Other Postretirement [Member] | System Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost - benefits earned during the period	243	306	729	918
Interest cost on projected benefit obligation	476	500	1,428	1,500
Expected return on assets	(697)	(783)	(2,091)	(2,349)
Amortization of prior service cost (credit)	(363)	(378)	(1,089)	(1,134)
Amortization of loss	89	233	267	699
Net other postretirement benefit cost	(252)	(122)	(756)	(366)
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	4,600	4,200	16,300	19,700
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits	955	212	4,600	7,000
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	67	114	211	369
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		7		30
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	38	42	122	138
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	69	73	257	230
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			40
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	5	20	16	62
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan Disclosure [Line Items]
Net other postretirement benefit cost	$ 119	$ 122	$ 365	529
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits				$ 139

X

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- Definition Amount of gain (loss) recognized in net periodic benefit (cost) credit of defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(4) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(4) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanAmortizationOfGainsLosses Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of prior service cost (credit) recognized in net periodic benefit cost (credit) of defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(5) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(5) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanAmortizationOfPriorServiceCostCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_DefinedBenefitPlanDisclosureLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Amount of expected return (loss) recognized in net periodic benefit (cost) credit, calculated based on expected long-term rate of return and market-related value of plan assets of defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(3) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(3) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanExpectedReturnOnPlanAssets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cost recognized for passage of time related to defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(2) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (a)(2) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 4: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(2) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanInterestCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of net periodic benefit cost (credit) for defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 + Details Name: us-gaap_DefinedBenefitPlanNetPeriodicBenefitCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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v3.19.3

Stock Based Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended
	Jan. 31, 2019	Mar. 31, 2019	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock option granted (in shares)		693,161
Weighted-average grant-date fair value of options granted (in dollars per share)		$ 8.32
Stock options outstanding			2,515,896
Weighted-average exercise price of stock options outstanding (in dollars per share)			$ 78.53
Intrinsic value in the money stock options			$ 97.7
Restricted Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Restricted Awards [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted	355,537
Restricted stock awards granted value (in dollars per share)	$ 89.19
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of awards under Entergy's plans, years			3 years
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-term incentive plan awards	180,824
Percent of performance measure based on relative total shareholder return	80.00%		80.00%
Percent of performance measure based on cumulative adjusted EPS metric	20.00%		20.00%
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member] | Performance measure based on relative total shareholder return [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 102.07
Long Term Incentive Plan [Member] | Equity Ownership And Long Term Cash Incentive Plan Two Thousand Fifteen [Member] | Performance measure based on cumulative adjusted earnings per share metric [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock awards granted value (in dollars per share)	$ 89.19

X

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- Definition Period which an employee's right to exercise an award is no longer contingent on satisfaction of either a service condition, market condition or a performance condition, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents the reported fact of one year, five months, and thirteen days. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (a)(1) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_ShareBasedCompensationArrangementByShareBasedPaymentAwardAwardVestingPeriod1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: duration

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- Definition The number of grants made during the period on other than stock (or unit) option plans (for example, phantom stock or unit plan, stock or unit appreciation rights plan, performance target plan). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(2)(iii)(1) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_ShareBasedCompensationArrangementByShareBasedPaymentAwardEquityInstrumentsOtherThanOptionsGrantsInPeriod Namespace Prefix: us-gaap_ Data Type: xbrli:sharesItemType Balance Type: na Period Type: duration

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- Definition The weighted average grant-date fair value of options granted during the reporting period as calculated by applying the disclosed option pricing methodology. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (d)(1) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_ShareBasedCompensationArrangementByShareBasedPaymentAwardOptionsGrantsInPeriodWeightedAverageGrantDateFairValue Namespace Prefix: us-gaap_ Data Type: num:perShareItemType Balance Type: na Period Type: duration

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v3.19.3

Business Segment Information (Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575			$ 3,104,319			$ 8,416,367	$ 8,496,970
Segment Financial Information
Income taxes (benefits)	29,201			(283,006)			73,430	(519,937)
Consolidated net income	369,459	$ 240,533	$ 258,646	539,818	$ 248,860	$ 136,200	868,639	924,877
Assets	50,506,268						50,506,268		$ 48,275,066
Utility [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	2,840,222			2,724,279			7,392,641	7,389,477
Segment Financial Information
Income taxes (benefits)	71,698			(137,035)			81,283	(325,134)
Consolidated net income	581,964			507,745			1,150,863	1,104,078
Assets	48,348,371						48,348,371		44,777,167
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	300,363			380,080			1,023,757	1,107,606
Segment Financial Information
Income taxes (benefits)	(30,855)			(135,659)			25,763	(166,882)
Consolidated net income	(140,501)			105,571			(68,804)	31,456
Assets	4,122,007						4,122,007		5,459,275
All Other [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	9			0			11	0
Segment Financial Information
Income taxes (benefits)	(11,642)			(10,312)			(33,616)	(27,921)
Consolidated net income	(40,105)			(41,601)			(117,725)	(114,962)
Assets	501,983						501,983		733,366
Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	(19)			(40)			(42)	(113)
Segment Financial Information
Income taxes (benefits)	0			0			0	0
Consolidated net income	(31,899)			$ (31,897)			(95,695)	$ (95,695)
Assets	$ (2,466,093)						$ (2,466,093)		$ (2,694,742)

X

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- Definition Sum of the carrying amounts as of the balance sheet date of all assets that are recognized. Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(11)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 22 -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8736-108599 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(12)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_Assets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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v3.19.3

Risk Management And Fair Values (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Values Of Derivative Instruments	The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018.
Derivative Instruments Designated As Cash Flow Hedges On Consolidated Statements Of Income	The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.
Assets and liabilities at fair value on a recurring basis	The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018.
Fair Value Inputs Liabilities Quantitative Information	The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5
Entergy Arkansas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Louisiana [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Mississippi [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy New Orleans [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Texas [Member]
Fair Values Of Derivative Instruments	The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas
Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income	The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Assets and liabilities at fair value on a recurring basis	Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5
Reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy	The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
System Energy [Member]
Assets and liabilities at fair value on a recurring basis	System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1

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v3.19.3

Leases Leases (Tables)	9 Months Ended
	Sep. 30, 2019
Lease, Cost	Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 %
Lease, Maturity	Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997
Purchase Power Agreement Minimum Lease Payments	The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.
Entergy Arkansas [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Entergy Louisiana [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Entergy Mississippi [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Entergy New Orleans [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Entergy Texas [Member]
Lease, Cost	The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019.
Lease, Assets	Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515
Lease, Liabilities	The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221
Lease, Terms and Discount Rate	The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 %
Lease, Maturity	Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473
Operating And Capital Leases Future Minimum Payments Due	As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Purchase Power Agreement Minimum Lease Payments	The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.
System Energy [Member]
Schedule of Rent Expense	Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6
Present Value Of Future Minimum Lease Payments Sale Leaseback Transactions	As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352

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- Definition Tabular disclosure of lessee's lease cost. Includes, but is not limited to, interest expense for finance lease, amortization of right-of-use asset for finance lease, operating lease cost, short-term lease cost, variable lease cost and sublease income. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 + Details Name: us-gaap_LeaseCostTableTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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- Definition Tabular disclosure of rental expense from operating leases for each period for which an income statement is presented with separate amounts for minimum rentals, contingent rentals, and sublease rentals. Rental payments under leases with terms of a month or less that were not renewed need not be included. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41499-112717 + Details Name: us-gaap_ScheduleOfRentExpenseTableTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands		1 Months Ended			3 Months Ended		9 Months Ended
	Oct. 25, 2019	Sep. 30, 2019	May 31, 2019	Dec. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Oct. 15, 2024	Jan. 01, 2019	Jun. 30, 2018	Jan. 01, 2018
Equity [Abstract]
Stock Options Excluded From Diluted Common Shares Outstanding Calculation						1,100,000	200,000	1,100,000
Forward Contract Indexed to Issuer's Equity, Indexed Shares											15,300,000
Proceeds from Issuance of Common Stock			$ 608,000	$ 500,000			$ 607,650	$ 0
Shares, Issued		1,582,916			1,582,916		1,582,916
Common stock dividend (in dollars per share)					$ 0.91	$ 0.89	$ 2.73	$ 2.67
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax										$ 6,806		$ 632,617
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										0		$ (56,360)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								$ 15,505
Accounting Standards Update 2017-12 [Member]
Equity [Abstract]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										8,000
Accounting Standards Update 2017-08 [Member]
Equity [Abstract]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets										$ 1,000
Common Stock [Member]
Equity [Abstract]
Forward Contract Indexed to Issuer's Equity, Shares			8,448,171	6,834,221
Subsequent Event [Member]
Equity [Abstract]
Common stock dividend (in dollars per share)	$ 0.93
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Entergy Texas [Member]
Proceeds from Issuance of Preferred Stock and Preference Stock		$ 35,000			$ 35,000		$ 35,000
Preferred Stock, Dividend Rate, Percentage		5.375%					5.375%
Preferred Stock, Shares Issued		1,400,000			1,400,000		1,400,000
Equity [Abstract]
Preferred Stock, Liquidation Preference Per Share		$ 25			$ 25		$ 25
Preferred Stock, Five Point Three Seven Five Percent, Series A [Member] | Subsequent Event [Member] | Entergy Texas [Member]
Equity [Abstract]
Preferred Stock, Liquidation Preference Per Share									$ 25

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- Definition Amount of cumulative effect of the change in accounting principle or new accounting pronouncement on retained earnings or other components of equity or net assets in the statement of financial position as of the beginning of the earliest period presented. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22499-107794 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22583-107794 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22580-107794 + Details Name: us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1 Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The per share liquidation preference (or restrictions) of nonredeemable preferred stock (or preferred stock redeemable solely at the option of the issuer) that has a preference in involuntary liquidation considerably in excess of the par or stated value of the shares. The liquidation preference is the difference between the preference in liquidation and the par or stated values of the share. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21475-112644 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(d)(1)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(28)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08(d)(1)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21484-112644 + Details Name: us-gaap_PreferredStockLiquidationPreference Namespace Prefix: us-gaap_ Data Type: num:perShareItemType Balance Type: na Period Type: instant

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v3.19.3

Risk Management And Fair Values	9 Months Ended
	Sep. 30, 2019
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Arkansas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Louisiana [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Mississippi [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy New Orleans [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
Entergy Texas [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1
System Energy [Member]
Risk Management And Fair Values	RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Market Risk In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs that are recovered from customers. As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh, to its customers.  Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy and capacity in the day ahead or spot markets.  In addition to its forward physical power and gas contracts, Entergy Wholesale Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate commodity price risk.  When the market price falls, the combination of instruments is expected to settle in gains that offset lower revenue from generation, which results in a more predictable cash flow. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity.  For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk.  A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk.  Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace.  Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies.  Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods.  These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions.  Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements.  Financially-settled cash flow hedges can include natural gas and electricity swaps and options and interest rate swaps.  Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.  Electricity over-the-counter instruments and futures contracts that financially settle against day-ahead power pool prices are used to manage price exposure for Entergy Wholesale Commodities generation.  The maximum length of time over which Entergy Wholesale Commodities is currently hedging the variability in future cash flows with derivatives for forecasted power transactions at September 30, 2019 is approximately 1.5 years.  Planned generation currently under contract from Entergy Wholesale Commodities nuclear power plants is 97% for the remainder of 2019, of which approximately 72% is sold under financial derivatives and the remainder under normal purchase/normal sale contracts.  Total planned generation for the remainder of 2019 is 6.1 TWh. Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and may include collateral requirements. Cash, letters of credit, and parental/affiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit limit, which may be supported by a parental/affiliate guarantee, as determined in accordance with Entergy’s credit policy. In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or inability to post collateral. Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain provisions that require an Entergy subsidiary to provide credit support to secure its obligations depending on the mark-to-market values of the contracts. The primary form of credit support to satisfy these requirements is an Entergy Corporation guarantee.  As of September 30, 2019, there were no derivative contracts with counterparties in a liability position. In addition to the corporate guarantee, $13 million in cash collateral were required to be posted by the Entergy subsidiary to its counterparties and $2 million in cash and $48 million in letters of credit were required to be posted by its counterparties to the Entergy subsidiary. As of December 31, 2018, derivative contracts with six counterparties were in a liability position (approximately $34 million total). In addition to the corporate guarantee, $19 million in cash collateral was required to be posted by the Entergy subsidiary to its counterparties. If the Entergy Corporation credit rating falls below investment grade, Entergy would have to post collateral equal to the estimated outstanding liability under the contract at the applicable date.    Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of September 30, 2019 is 4.5 years for Entergy Louisiana and the maximum length of time over which Entergy has executed natural gas swaps as of September 30, 2019 is 6 months each for Entergy Mississippi and Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of September 30, 2019 is 40,346,000 MMBtu for Entergy, including 32,880,000 MMBtu for Entergy Louisiana, 6,210,000 MMBtu for Entergy Mississippi, and 1,256,000 for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2019, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2019 through May 31, 2020. Financial transmission rights are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of September 30, 2019 is 79,459 GWh for Entergy, including 17,898 GWh for Entergy Arkansas, 36,474 GWh for Entergy Louisiana, 10,087 GWh for Entergy Mississippi, 3,751 GWh for Entergy New Orleans, and 10,931 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy Wholesale Commodities is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for Entergy Wholesale Commodities as of September 30, 2019 and December 31, 2018. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Mississippi as of September 30, 2019 and Entergy Mississippi and Entergy Texas as of December 31, 2018. The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of September 30, 2019 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $35   ($5)   $30   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $14   ($2)   $12   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $5   ($5)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $2   ($2)   $—   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $9   ($3)   $6   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Utility Financial transmission rights   Prepayments and other   $17   ($1)   $16   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $4   ($4)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities (current portion)   $4   $—   $4   Utility Natural gas swaps and options   Other non-current liabilities (non-current portion)   $1   $—   $1   Utility The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2018 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Business         (In Millions)     Derivatives designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $32   ($32)   $—   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $7   ($7)   $—   Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $54   ($33)   $21   Entergy Wholesale Commodities Electricity swaps and options   Other non-current liabilities (non-current portion)   $20   ($7)   $13   Entergy Wholesale Commodities Derivatives not designated as hedging instruments                     Assets:                     Electricity swaps and options   Prepayments and other (current portion)   $4   ($2)   $2   Entergy Wholesale Commodities Electricity swaps and options   Other deferred debits and other assets (non-current portion)   $1   $—   $1   Entergy Wholesale Commodities Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $2   $—   $2   Utility Financial transmission rights   Prepayments and other   $16   ($1)   $15   Utility and Entergy Wholesale Commodities Liabilities:                     Electricity swaps and options   Other current liabilities (current portion)   $1   ($1)   $—   Entergy Wholesale Commodities Natural gas swaps and options   Other current liabilities   $1   $—   $1   Utility (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheet (d) Excludes cash collateral in the amount of $2 million held and $13 million posted as of September 30, 2019 and $19 million posted as of December 31, 2018. Also excludes letters of credit in the amount of $48 million held as of September 30, 2019 and $4 million posted as of December 31, 2018. The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in other comprehensive income   Income Statement location   Amount of gain reclassified from accumulated other comprehensive income into income (a)     (In Millions)       (In Millions) 2019             Electricity swaps and options   ($7)   Competitive businesses operating revenues   $19               2018             Electricity swaps and options   ($51)   Competitive businesses operating revenues   ($11) (a) Before taxes of $4 million and ($2) million for the three months ended September 30, 2019 and 2018, respectively The effects of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain recognized in other comprehensive income   Income Statement location   Amount of gain (loss) reclassified from accumulated other comprehensive income into income (a)   (In Millions)       (In Millions) 2019             Electricity swaps and options   $145   Competitive businesses operating revenues   $76               2018             Electricity swaps and options   ($40)   Competitive businesses operating revenues   ($38)      (a) Before taxes of $16 million and ($8) million for the nine months ended September 30, 2019 and 2018, respectively Prior to the adoption of ASU 2017-12, Entergy measured its hedges for ineffectiveness. Any ineffectiveness was recognized in earnings during the period. The ineffective portion of cash flow hedges was recorded in competitive businesses operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the three months ended September 30, 2018 was ($3.1) million. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness during the nine months ended September 30, 2018 was ($5.2) million. Based on market prices as of September 30, 2019, unrealized gains (losses) recorded in accumulated other comprehensive income on cash flow hedges relating to power sales totaled $42 million of net unrealized losses.  Approximately $30 million is expected to be reclassified from accumulated other comprehensive income to operating revenues in the next twelve months.  The actual amount reclassified from accumulated other comprehensive income, however, could vary due to future changes in market prices.     Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original hedge, and then de-designating the original hedge in this situation.  Gains or losses accumulated in other comprehensive income prior to de-designation continue to be deferred in other comprehensive income until they are included in income as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to earnings. The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Amount of gain (loss) recognized in accumulated other comprehensive income   Income Statement location   Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($2) Financial transmission rights   $—   Purchased power expense (b) $25 Electricity swaps and options   $— (c) Competitive business operating revenues   $1               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $— Financial transmission rights   $—   Purchased power expense (b) $31 Electricity swaps and options   $— (c) Competitive business operating revenues   ($2) The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Amount of gain (loss) recognized in accumulated other comprehensive income Income Statement location Amount of gain (loss) recorded in the income statement     (In Millions)       (In Millions) 2019           Natural gas swaps and options   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) ($9) Financial transmission rights $— Purchased power expense (b) $78 Electricity swaps and options   $— (c) Competitive business operating revenues   $4               2018             Natural gas swaps   $—   Fuel, fuel-related expenses, and gas purchased for resale (a) $5 Financial transmission rights   $—   Purchased power expense (b) $104 Electricity swaps and options   $— (c) Competitive business operating revenues   $— (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. (c) Amount of gain recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items. The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of September 30, 2019 are shown in the table below. Certain investments are subject to master netting agreements and are presented on the balance sheets on a net basis in accordance with accounting guidance for derivatives and hedging. Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.1   $—   $0.1   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets (non-current portion)   $1.0   $—   $1.0   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $4.0   ($0.1)   $3.9   Entergy Arkansas Financial transmission rights   Prepayments and other   $9.1   $—   $9.1   Entergy Louisiana Financial transmission rights   Prepayments and other   $1.5   $—   $1.5   Entergy Mississippi Financial transmission rights   Prepayments and other   $0.7   $—   $0.7   Entergy New Orleans Financial transmission rights   Prepayments and other   $1.7   ($0.4)   $1.3   Entergy Texas                       Liabilities:                     Natural gas swaps and options   Other current liabilities   $2.2   $—   $2.2   Entergy Louisiana Natural gas swaps and options   Other non-current liabilities   $1.4   $—   $1.4   Entergy Louisiana Natural gas swaps   Other current liabilities   $1.1   $—   $1.1   Entergy Mississippi Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their balance sheets as of December 31, 2018 are as follows: Instrument   Balance Sheet Location   Fair Value (a)   Offset (b)   Net (c) (d)   Registrant         (In Millions)     Assets:                     Natural gas swaps and options   Prepayments and other   $0.3   $—   $0.3   Entergy Louisiana Natural gas swaps and options   Other deferred debits and other assets   $1.6   $—   $1.6   Entergy Louisiana                       Financial transmission rights   Prepayments and other   $3.6   ($0.2)   $3.4   Entergy Arkansas Financial transmission rights   Prepayments and other   $8.4   ($0.1)   $8.3   Entergy Louisiana Financial transmission rights   Prepayments and other   $2.2   $—   $2.2   Entergy Mississippi Financial transmission rights   Prepayments and other   $1.3   $—   $1.3   Entergy New Orleans                       Liabilities:                     Financial transmission rights   Other current liabilities   $0.9   ($1.4)   ($0.5)   Entergy Texas                       Natural gas swaps and options   Other current liabilities   $1.1   $—   $1.1   Entergy Louisiana Natural gas swaps   Other current liabilities   $0.1   $—   $0.1   Entergy New Orleans (a) Represents the gross amounts of recognized assets/liabilities (b) Represents the netting of fair value balances with the same counterparty (c) Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets (d) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. As of December 31, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, and $4.1 million for Entergy Texas. The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the three months ended September 30, 2019 and 2018 are as follows: Instrument   Income Statement Location   Amount of gain (loss) recorded in the income statement   Registrant         (In Millions)     2019             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($1.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.3) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.1) (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $3.5 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $14.4 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $1.9 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   ($0.3) (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $5.5 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($0.7) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $10.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $13.8 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.4 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.0 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($0.4) (b) Entergy Texas The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on their income statements for the nine months ended September 30, 2019 and 2018 are as follows: Instrument Income Statement Location Amount of gain (loss) recorded in the income statement Registrant         (In Millions)     2019           Natural gas swaps and options   Fuel, fuel-related expenses, and gas purchased for resale   ($3.6) (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   ($5.5) (a) Entergy Mississippi Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.1 (a) Entergy New Orleans               Financial transmission rights   Purchased power expense   $15.4 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $40.9 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $5.3 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $2.2 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   $13.6 (b) Entergy Texas               2018             Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $4.2 (a) Entergy Louisiana Natural gas swaps   Fuel, fuel-related expenses, and gas purchased for resale   $0.9 (a) Entergy Mississippi               Financial transmission rights   Purchased power expense   $20.1 (b) Entergy Arkansas Financial transmission rights   Purchased power expense   $57.2 (b) Entergy Louisiana Financial transmission rights   Purchased power expense   $23.0 (b) Entergy Mississippi Financial transmission rights   Purchased power expense   $10.5 (b) Entergy New Orleans Financial transmission rights   Purchased power expense   ($5.6) (b) Entergy Texas (a) Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. (b) Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments other than those instruments held by the Entergy Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.   The three levels of the fair value hierarchy are: • Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. • Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following: – quoted prices for similar assets or liabilities in active markets; – quoted prices for identical assets or liabilities in inactive markets; – inputs other than quoted prices that are observable for the asset or liability; or – inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. • Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights and derivative power contracts used as cash flow hedges of power sales at merchant power plants. The values for power contract assets or liabilities are based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group and the Accounting Policy and Entergy Wholesale Commodities Accounting group.  The primary functions of the Business Unit Risk Control group include: gathering, validating and reporting market data, providing market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system.  The Business Unit Risk Control group is also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and analysis.  The Accounting Policy and Entergy Wholesale Commodities Accounting group performs functions related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Business Unit Risk Control group reports to the Vice President and Treasurer while the Accounting Policy and Entergy Wholesale Commodities Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled at that date.  These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of the output from the Entergy Wholesale Commodities business.  The fair values are based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices.  The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate are recorded as derivative contract assets or liabilities.  For contracts that have unit contingent terms, a further discount is applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and are calculated at the end of each month for accounting purposes.  Inputs to the valuation include end of day forward market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate.  As described further below, prices and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair value.   On a daily basis, the Business Unit Risk Control group calculates the mark-to-market for electricity swaps and options.  The Business Unit Risk Control group also validates forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions.  Significant differences are analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions.  Implied volatilities used to value options are also validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available and compared with other sources of market implied volatilities.  Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario analysis.  The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale Commodities.  Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding the proposed derivative to Entergy Wholesale Commodities’ portfolio.  In particular, the credit and liquidity effects are calculated for this analysis.  This analysis is communicated to senior management within Entergy and Entergy Wholesale Commodities. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Business Unit Risk Control group.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting Policy and Entergy Wholesale Commodities Accounting groups review these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Business Unit Risk Control groups report to the Vice President and Treasurer.  The Accounting Policy and Entergy Wholesale Commodities Accounting groups report to the Chief Accounting Officer. The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $885   $—   $—   $885 Decommissioning trust funds (a):                 Equity securities   836   —   —   836 Debt securities   1,214   1,754   —   2,968 Common trusts (b)               2,325 Power contracts   —   —   48   48 Securitization recovery trust account   55   —   —   55 Escrow accounts   410   —   —   410 Gas hedge contracts   —   1   —   1 Financial transmission rights   —   —   16   16     $3,400   $1,755   $64   $7,544                   Liabilities:                 Gas hedge contracts   $4   $1   $—   $5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $424   $—   $—   $424 Decommissioning trust funds (a):                 Equity securities   1,686   —   —   1,686 Debt securities   1,259   1,625   —   2,884 Common trusts (b)               2,350 Power contracts   —   —   3   3 Securitization recovery trust account   51   —   —   51 Escrow accounts   403   —   —   403 Gas hedge contracts   —   2   —   2 Financial transmission rights   —   —   15   15     $3,823   $1,627   $18   $7,818 Liabilities:                 Power contracts   $—   $—   $34   $34 Gas hedge contracts   1   —   —   1     $1   $—   $34   $35 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights   (In Millions) Balance as of July 1, $72   $29   ($25 )   $41 Total gains (losses) for the period (a)               Included in earnings 1   —   (4 )   — Included in other comprehensive income (7 )   —   (51 )   — Included as a regulatory liability/asset —   12   —   19 Settlements (18 )   (25 )   13   (31 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($1.2) million for the three months ended September 30, 2019 and $1.7 million for the three months ended September 30, 2018. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019 and 2018:   2019   2018   Power Contracts   Financial transmission rights   Power Contracts   Financial transmission rights (In Millions) Balance as of January 1, ($31 )   $15   ($65 )   $21 Total gains (losses) for the period (a)               Included in earnings 4   —   (5 )   (1 ) Included in other comprehensive income 145   —   (40 )   — Included as a regulatory liability/asset —   44   —   67 Issuances of financial transmission rights —   35   —   46 Settlements (70 )   (78 )   43   (104 ) Balance as of September 30, $48   $16   ($67 )   $29 (a) Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($4.7) million for the nine months ended September 30, 2019 and $1.1 million for the nine months ended September 30, 2018. The following table sets forth a description of the types of transactions classified as Level 3 in the fair value hierarchy and significant unobservable inputs to each which cause that classification as of September 30, 2019: Transaction Type   Fair Value   Significant Unobservable Inputs   Range from Average %   Effect on Fair Value     (In Millions)             (In Millions) Power contracts - electricity swaps   $48   Unit contingent discount   +/- 4% - 4.75%   $4 - $5 The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs: Significant Unobservable Input   Transaction Type   Position   Change to Input   Effect on Fair Value Unit contingent discount   Electricity swaps   Sell   Increase (Decrease)   Decrease (Increase) The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of September 30, 2019 and December 31, 2018.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect its placement within the fair value hierarchy levels. Entergy Arkansas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $76.7   $—   $—   $76.7 Decommissioning trust funds (a):                 Equity securities   6.2   —   —   6.2 Debt securities   101.4   306.3   —   407.7 Common trusts (b)               631.9 Securitization recovery trust account   7.9   —   —   7.9 Financial transmission rights   —   —   3.9   3.9     $192.2   $306.3   $3.9   $1,134.3 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Decommissioning trust funds (a):                 Equity securities   $4.0   $—   $—   $4.0 Debt securities   94.8   286.5   —   381.3 Common trusts (b)               526.7 Securitization recovery trust account   4.7   —   —   4.7 Financial transmission rights   —   —   3.4   3.4     $103.5   $286.5   $3.4   $920.1 Entergy Louisiana 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $127.8   $—   $—   $127.8 Decommissioning trust funds (a):                 Equity securities   5.3   —   —   5.3 Debt securities   183.7   409.7   —   593.4 Common trusts (b)               886.9 Escrow accounts   294.5   —   —   294.5 Securitization recovery trust account   10.1   —   —   10.1 Gas hedge contracts   0.1   1.0   —   1.1 Financial transmission rights   —   —   9.1   9.1     $621.5   $410.7   $9.1   $1,928.2                   Liabilities:                 Gas hedge contracts   $2.2   $1.4   $—   $3.6 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $43.1   $—   $—   $43.1 Decommissioning trust funds (a):                 Equity securities   13.3   —   —   13.3 Debt securities   162.0   370.9   —   532.9 Common trusts (b)               738.8 Escrow accounts   289.5   —   —   289.5 Securitization recovery trust account   3.6   —   —   3.6 Gas hedge contracts   —   1.9   —   1.9 Financial transmission rights   —   —   8.3   8.3     $511.5   $372.8   $8.3   $1,631.4                   Liabilities:                 Gas hedge contracts   $0.7   $0.4   $—   $1.1 Entergy Mississippi 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $98.9   $—   $—   $98.9 Escrow accounts   33.0   —   —   33.0 Financial transmission rights   —   —   1.5   1.5     $131.9   $—   $1.5   $133.4                   Liabilities:                 Gas hedge contracts   $1.1   $—   $—   $1.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $36.9   $—   $—   $36.9 Escrow accounts   32.4   —   —   32.4 Financial transmission rights   —   —   2.2   2.2     $69.3   $—   $2.2   $71.5 Entergy New Orleans 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $5.3   $—   $—   $5.3 Escrow accounts   82.2   —   —   82.2 Financial transmission rights   —   —   0.7   0.7     $87.5   $—   $0.7   $88.2                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $19.7   $—   $—   $19.7 Securitization recovery trust account   2.2   —   —   2.2 Escrow accounts   80.9   —   —   80.9 Financial transmission rights   —   —   1.3   1.3     $102.8   $—   $1.3   $104.1                   Liabilities:                 Gas hedge contracts   $0.1   $—   $—   $0.1 Entergy Texas 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $92.3   $—   $—   $92.3 Securitization recovery trust account   31.6   —   —   31.6 Financial transmission rights   —   —   1.3   1.3     $123.9   $—   $1.3   $125.2 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Securitization recovery trust account   $40.2   $—   $—   $40.2                   Liabilities:                 Financial transmission rights   $—   $—   $0.5   $0.5 System Energy 2019   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $164.2   $—   $—   $164.2 Decommissioning trust funds (a):                 Equity securities   5.8   —   —   5.8 Debt securities   206.0   189.3   —   395.3 Common trusts (b)               601.2     $376.0   $189.3   $—   $1,166.5 2018   Level 1   Level 2   Level 3   Total     (In Millions) Assets:                 Temporary cash investments   $95.6   $—   $—   $95.6 Decommissioning trust funds (a):                 Equity securities   4.4   —   —   4.4 Debt securities   224.5   139.7   —   364.2 Common trusts (b)               500.9     $324.5   $139.7   $—   $965.1 (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date. The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $8.2   $15.6   $2.8   $2.0   $0.6 Gains (losses) included as a regulatory liability/asset (0.8 )   7.9   0.6   (1.6 )   6.2 Settlements (3.5 )   (14.4 )   (1.9 )   0.3   (5.5 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the three months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of July 1, $10.5   $18.2   $4.4   $3.0   $4.7 Gains (losses) included as a regulatory liability/asset 10.9   7.6   4.7   1.1   (5.0 ) Settlements (10.1 )   (13.8 )   (5.4 )   (2.0 )   0.4 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2019.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.4   $8.3   $2.2   $1.3   ($0.5 ) Issuances of financial transmission rights 9.6   18.7   3.9   2.7   0.1 Gains (losses) included as a regulatory liability/asset 6.3   23.0   0.6   (1.1 )   15.3 Settlements (15.4 )   (40.9 )   (5.2 )   (2.2 )   (13.6 ) Balance as of September 30, $3.9   $9.1   $1.5   $0.7   $1.3 The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the nine months ended September 30, 2018.   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Millions) Balance as of January 1, $3.0   $10.2   $2.1   $2.2   $3.4 Issuances of financial transmission rights 11.8   20.0   4.5   3.7   6.1 Gains (losses) included as a regulatory liability/asset 16.6   39.0   20.1   6.7   (15.0 ) Settlements (20.1 )   (57.2 )   (23.0 )   (10.5 )   5.6 Balance as of September 30, $11.3   $12.0   $3.7   $2.1   $0.1

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	9 Months Ended
	Sep. 30, 2019
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt	REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in September 2024.  The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility.  The commitment fee is currently 0.225% of the undrawn commitment amount.  Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  The weighted average interest rate for the nine months ended September 30, 2019 was 3.94% on the drawn portion of the facility.  Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339 Entergy Corporation’s credit facility requires Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization.  Entergy is in compliance with this covenant.  If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur. Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $2 billion.  At September 30, 2019, Entergy Corporation had approximately $1,918 million of commercial paper outstanding.  The weighted-average interest rate for the nine months ended September 30, 2019 was 2.88%. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. The commitment fees on the credit facilities range from 0.075% to 0.225% of the undrawn commitment amount. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each entered into uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO. Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC.  The current FERC-authorized limits for Entergy New Orleans are effective through October 31, 2021. The current FERC-authorized limits for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy are effective through November 8, 2020. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy System money pool and from other internal short-term borrowing arrangements.  The money pool and the other internal borrowing arrangements are inter-company borrowing arrangements designed to reduce the Utility subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits.  The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $— Vermont Yankee Asset Retirement Management, LLC Credit Facility In January 2019, Entergy Nuclear Vermont Yankee was transferred to NorthStar and its credit facility was assumed by Vermont Yankee Asset Retirement Management, LLC, Entergy Nuclear Vermont Yankee’s parent company that remains an Entergy subsidiary after the transfer. The credit facility has a borrowing capacity of $139 million and expires in November 2020. The commitment fee is currently 0.20% of the undrawn commitment amount.  As of September 30, 2019, $139 million in cash borrowings were outstanding under the credit facility.  The weighted average interest rate for the nine months ended September 30, 2019 was 4.07% on the drawn portion of the facility. See Note 14 to the financial statements in the Form 10-K and Note 16 to the financial statements herein for discussion of the transfer of Entergy Nuclear Vermont Yankee to NorthStar. Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense. Debt Issuances and Retirements (Entergy Arkansas) In March 2019, Entergy Arkansas issued $350 million of 4.20% Series mortgage bonds due April 2049. Entergy Arkansas is using the proceeds for general corporate purposes. (Entergy Louisiana) In March 2019, Entergy Louisiana issued $525 million of 4.20% Series mortgage bonds due April 2050. Entergy Louisiana is using the proceeds, together with other funds, to finance the construction of the Lake Charles Power Station and the St. Charles Power Station, and for general corporate purposes. (Entergy Mississippi) In June 2019, Entergy Mississippi issued $300 million of 3.85% Series mortgage bonds due June 2049. Entergy Mississippi used the proceeds to repay, at maturity, its $150 million of 6.64% Series mortgage bonds due July 2019 and for general corporate purposes. (Entergy Texas) In January 2019, Entergy Texas issued $300 million of 4.0% Series mortgage bonds due March 2029 and $400 million of 4.5% Series mortgage bonds due March 2039. Entergy Texas used the proceeds to repay, at maturity, its $500 million of 7.125% Series mortgage bonds due February 2019 and for general corporate purposes. In September 2019, Entergy Texas issued $300 million of 3.55% Series mortgage bonds due September 2049. Entergy Texas is using the proceeds, together with other funds, to finance the construction of the Montgomery County Power Station, and for general corporate purposes. (System Energy) In March 2019, System Energy issued $134 million of 2.50% Series 2019 revenue refunding bonds due April 2022. The proceeds were used to redeem, prior to maturity, $134 million of 5.875% Series 1998 pollution control revenue refunding bonds due April 2022. Fair Value The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

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- Definition The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -URI http://asc.fasb.org/topic&trid=2208564 + Details Name: us-gaap_DebtDisclosureTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Income Taxes Income Taxes (Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 96	$ 283	$ 219	$ 562
Entergy Arkansas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	41	153	99	260
Entergy Louisiana [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	17	55	31	86
Entergy Mississippi [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	0	32	0	161
Entergy New Orleans [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	7	9	9	9
Entergy Texas [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	31	0	73	0
System Energy [Member]
Reduction to regulatory liability due to return of unprotected excess accumulated deferred income taxes	$ 0	$ 34	$ 7	$ 46

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v3.19.3

Leases Leases (Lease, Maturity) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Operating Lease, Weighted Average Remaining Lease Term	5 years 1 month 6 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 16,088
Finance Lease, Liability, Payments, Remainder of Fiscal Year	3,608
Lessee, Operating Lease, Liability, Payments, Due Year Two	59,965	$ 31,876
Finance Lease, Liability, Payments, Due Year Two	13,521
Lessee, Operating Lease, Liability, Payments, Due Year Three	53,791	32,609
Finance Lease, Liability, Payments, Due Year Three	11,973
Lessee, Operating Lease, Liability, Payments, Due Year Four	45,391	10,180
Finance Lease, Liability, Payments, Due Year Four	10,775
Lessee, Operating Lease, Liability, Payments, Due Year Five	35,050
Finance Lease, Liability, Payments, Due Year Five	9,664
Lessee, Operating Lease, Liability, Payments, Due after Year Five	56,906
Finance Lease, Liability, Payments, Due after Year Five	26,889
Lessee, Operating Lease, Liability, Payments, Due	267,191	105,824
Operating Lease, Cost	30,438
Finance Lease, Liability, Payments, Due	76,430
Finance Lease, Interest Payment on Liability	11,696
Present Value Net Minimum Operating Lease Payments	236,753
Present Value Net Minimum Financing Lease Payments	$ 64,734
Finance Lease, Weighted Average Remaining Lease Term	6 years 9 months 14 days
Operating Lease, Weighted Average Discount Rate, Percent	3.91%
Finance Lease, Weighted Average Discount Rate, Percent	4.67%
Entergy Arkansas [Member]
Operating Lease, Weighted Average Remaining Lease Term	6 years 1 month 2 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 3,168
Finance Lease, Liability, Payments, Remainder of Fiscal Year	713
Lessee, Operating Lease, Liability, Payments, Due Year Two	11,756
Finance Lease, Liability, Payments, Due Year Two	2,654
Lessee, Operating Lease, Liability, Payments, Due Year Three	9,911
Finance Lease, Liability, Payments, Due Year Three	2,258
Lessee, Operating Lease, Liability, Payments, Due Year Four	7,613
Finance Lease, Liability, Payments, Due Year Four	1,969
Lessee, Operating Lease, Liability, Payments, Due Year Five	6,341
Finance Lease, Liability, Payments, Due Year Five	1,728
Lessee, Operating Lease, Liability, Payments, Due after Year Five	16,421
Finance Lease, Liability, Payments, Due after Year Five	2,905
Lessee, Operating Lease, Liability, Payments, Due	55,210
Operating Lease, Cost	5,667
Finance Lease, Liability, Payments, Due	12,227
Finance Lease, Interest Payment on Liability	961
Present Value Net Minimum Operating Lease Payments	49,543
Present Value Net Minimum Financing Lease Payments	$ 11,266
Finance Lease, Weighted Average Remaining Lease Term	5 years 5 months 8 days
Operating Lease, Weighted Average Discount Rate, Percent	3.75%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Louisiana [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 3 months 10 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 2,863
Finance Lease, Liability, Payments, Remainder of Fiscal Year	1,135
Lessee, Operating Lease, Liability, Payments, Due Year Two	10,518
Finance Lease, Liability, Payments, Due Year Two	4,191
Lessee, Operating Lease, Liability, Payments, Due Year Three	8,787
Finance Lease, Liability, Payments, Due Year Three	3,536
Lessee, Operating Lease, Liability, Payments, Due Year Four	6,068
Finance Lease, Liability, Payments, Due Year Four	3,096
Lessee, Operating Lease, Liability, Payments, Due Year Five	4,079
Finance Lease, Liability, Payments, Due Year Five	2,635
Lessee, Operating Lease, Liability, Payments, Due after Year Five	4,702
Finance Lease, Liability, Payments, Due after Year Five	3,818
Lessee, Operating Lease, Liability, Payments, Due	37,017
Operating Lease, Cost	2,759
Finance Lease, Liability, Payments, Due	18,411
Finance Lease, Interest Payment on Liability	1,626
Present Value Net Minimum Operating Lease Payments	34,258
Present Value Net Minimum Financing Lease Payments	$ 16,785
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.74%
Finance Lease, Weighted Average Discount Rate, Percent	3.75%
Entergy Mississippi [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 7 months 24 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1,968
Finance Lease, Liability, Payments, Remainder of Fiscal Year	429
Lessee, Operating Lease, Liability, Payments, Due Year Two	6,066
Finance Lease, Liability, Payments, Due Year Two	1,655
Lessee, Operating Lease, Liability, Payments, Due Year Three	4,937
Finance Lease, Liability, Payments, Due Year Three	1,490
Lessee, Operating Lease, Liability, Payments, Due Year Four	3,503
Finance Lease, Liability, Payments, Due Year Four	1,297
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,376
Finance Lease, Liability, Payments, Due Year Five	1,078
Lessee, Operating Lease, Liability, Payments, Due after Year Five	2,642
Finance Lease, Liability, Payments, Due after Year Five	1,740
Lessee, Operating Lease, Liability, Payments, Due	20,492
Operating Lease, Cost	2,101
Finance Lease, Liability, Payments, Due	7,689
Finance Lease, Interest Payment on Liability	695
Present Value Net Minimum Operating Lease Payments	18,391
Present Value Net Minimum Financing Lease Payments	$ 6,994
Finance Lease, Weighted Average Remaining Lease Term	5 years 4 months 28 days
Operating Lease, Weighted Average Discount Rate, Percent	3.77%
Finance Lease, Weighted Average Discount Rate, Percent	3.71%
Entergy New Orleans [Member]
Operating Lease, Weighted Average Remaining Lease Term	3 years 11 months 26 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 332
Finance Lease, Liability, Payments, Remainder of Fiscal Year	204
Lessee, Operating Lease, Liability, Payments, Due Year Two	1,196
Finance Lease, Liability, Payments, Due Year Two	660
Lessee, Operating Lease, Liability, Payments, Due Year Three	939
Finance Lease, Liability, Payments, Due Year Three	549
Lessee, Operating Lease, Liability, Payments, Due Year Four	659
Finance Lease, Liability, Payments, Due Year Four	499
Lessee, Operating Lease, Liability, Payments, Due Year Five	497
Finance Lease, Liability, Payments, Due Year Five	451
Lessee, Operating Lease, Liability, Payments, Due after Year Five	729
Finance Lease, Liability, Payments, Due after Year Five	881
Lessee, Operating Lease, Liability, Payments, Due	4,352
Operating Lease, Cost	459
Finance Lease, Liability, Payments, Due	3,244
Finance Lease, Interest Payment on Liability	332
Present Value Net Minimum Operating Lease Payments	3,893
Present Value Net Minimum Financing Lease Payments	$ 2,912
Finance Lease, Weighted Average Remaining Lease Term	5 years 8 months 19 days
Operating Lease, Weighted Average Discount Rate, Percent	3.94%
Finance Lease, Weighted Average Discount Rate, Percent	3.93%
Entergy Texas [Member]
Operating Lease, Weighted Average Remaining Lease Term	4 years 5 months 26 days
Lessee, Operating Lease, Liability, Payments, Due Next Twelve Months	$ 1,022
Finance Lease, Liability, Payments, Remainder of Fiscal Year	375
Lessee, Operating Lease, Liability, Payments, Due Year Two	4,014	31,876
Finance Lease, Liability, Payments, Due Year Two	1,364
Lessee, Operating Lease, Liability, Payments, Due Year Three	3,279	32,609
Finance Lease, Liability, Payments, Due Year Three	1,171
Lessee, Operating Lease, Liability, Payments, Due Year Four	2,338	10,180
Finance Lease, Liability, Payments, Due Year Four	965
Lessee, Operating Lease, Liability, Payments, Due Year Five	1,994
Finance Lease, Liability, Payments, Due Year Five	827
Lessee, Operating Lease, Liability, Payments, Due after Year Five	2,193
Finance Lease, Liability, Payments, Due after Year Five	1,316
Lessee, Operating Lease, Liability, Payments, Due	14,840	$ 105,824
Operating Lease, Cost	1,724
Finance Lease, Liability, Payments, Due	6,018
Finance Lease, Interest Payment on Liability	545
Present Value Net Minimum Operating Lease Payments	13,116
Present Value Net Minimum Financing Lease Payments	$ 5,473
Finance Lease, Weighted Average Remaining Lease Term	5 years 3 months
Operating Lease, Weighted Average Discount Rate, Percent	3.86%
Finance Lease, Weighted Average Discount Rate, Percent	3.84%

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- Definition Amount of interest paid on finance lease liability. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(1) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 5 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918643-209977 + Details Name: us-gaap_FinanceLeaseInterestPaymentOnLiability Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due after fifth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDueAfterYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due in fifth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDueYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due in fourth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDueYearFour Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due in third fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDueYearThree Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due in second fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsDueYearTwo Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for finance lease, due in remainder of fiscal year following latest fiscal year ended. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_FinanceLeaseLiabilityPaymentsRemainderOfFiscalYear Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Weighted average discount rate for finance lease calculated at point in time. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(4) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseWeightedAverageDiscountRatePercent Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

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- Definition Weighted average remaining lease term for finance lease, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents reported fact of one year, five months, and thirteen days. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(3) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseWeightedAverageRemainingLeaseTerm1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due after fifth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueAfterYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in fifth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in fourth fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearFour Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in third fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearThree Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease, due in second fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsDueYearTwo Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's undiscounted obligation for lease payments for operating lease having an initial or remaining lease term in excess of one year due in remainder of fiscal year following latest fiscal year. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918701-209980 + Details Name: us-gaap_LesseeOperatingLeaseLiabilityPaymentsRemainderOfFiscalYear Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of single lease cost, calculated by allocation of remaining cost of lease over remaining lease term. Includes, but is not limited to, single lease cost, after impairment of right-of-use asset, calculated by amortization of remaining right-of-use asset and accretion of lease liability. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 + Details Name: us-gaap_OperatingLeaseCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Weighted average discount rate for operating lease calculated at point in time. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(4) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_OperatingLeaseWeightedAverageDiscountRatePercent Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

- Definition Weighted average remaining lease term for operating lease, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents reported fact of one year, five months, and thirteen days. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (g)(3) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 + Details Name: us-gaap_OperatingLeaseWeightedAverageRemainingLeaseTerm1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Leases Leases (Present Value Of future Minimum Lease Payments Sale Leaseback Transactions) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,628,268		$ 18,628,268		$ 15,880,239
Interest Expense, Debt	201,412	$ 195,311	603,517	$ 570,548
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,621,073		3,621,073		3,002,627
Interest Expense, Debt	35,454	31,632	104,664	92,315
Entergy Louisiana [Member]
Long-term Debt, Fair Value	8,038,675		8,038,675		6,834,134
Interest Expense, Debt	78,350	73,084	230,684	216,762
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,586,199		1,586,199		1,276,452
Interest Expense, Debt	15,922	13,950	45,804	41,916
Entergy New Orleans [Member]
Long-term Debt, Fair Value	522,688		522,688		491,569
Interest Expense, Debt	6,046	5,388	18,001	15,936
Entergy Texas [Member]
Long-term Debt, Fair Value	2,128,842		2,128,842		1,528,828
Interest Expense, Debt	21,379	21,760	63,992	65,646
System Energy [Member]
Long-term Debt, Fair Value	554,374		554,374		596,123
Interest Expense, Debt	$ 8,546	$ 9,753	$ 26,467	$ 28,734
Grand Gulf [Member] | System Energy [Member]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Two					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Three					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Four					17,188
Long-term Debt, Maturities, Repayments of Principal in Year Five					17,188
Long-term Debt, Maturities, Repayments of Principal after Year Five					223,437
Long-term Debt, Fair Value					309,377
Interest Expense, Debt					275,025
Long-term Debt					$ 34,352

X

- Definition Amount of the cost of borrowed funds accounted for as interest expense for debt. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109500613&loc=SL6036836-161870 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SX 210.5-03.8) -URI http://asc.fasb.org/extlink&oid=115205541&loc=SL114868664-224227 + Details Name: us-gaap_InterestExpenseDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount, after unamortized (discount) premium and debt issuance costs, of long-term debt. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=109500613&loc=SL6031897-161870 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(16)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LongTermDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The fair value amount of long-term debt whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. + References No definition available. + Details Name: us-gaap_LongTermDebtFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing after the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalAfterYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing in the next fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalInNextTwelveMonths Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing in the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalInYearFive Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing in the fourth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalInYearFour Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing in the third fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalInYearThree Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of long-term debt payable, sinking fund requirements, and other securities issued that are redeemable by holder at fixed or determinable prices and dates maturing in the second fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04.(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 470 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6802200&loc=d3e1835-112601 + Details Name: us-gaap_LongTermDebtMaturitiesRepaymentsOfPrincipalInYearTwo Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_SaleLeasebackTransactionDescriptionAxis=etr_GrandGulfMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Asset Retirement Obligations Asset Retirement Obligations (Narrative) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Mar. 31, 2019
Entergy Louisiana [Member]
Increase in decommissioning liability	$ 147.5
Entergy Arkansas [Member]
Increase in decommissioning liability		$ 126.2

X

- Definition Increase in decommissioning liability. + References No definition available. + Details Name: etr_IncreaseInDecommissioningLiability Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Business Segment Information Business Segment Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended	29 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Jun. 01, 2022
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Asset Write-Offs, Impairments, And Related Charges	$ 8	$ 155	$ 98	$ 297
Restructuring Charges	14	43	70	103
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			70
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Subsequent Event [Member]
Segment Reporting Information [Line Items]
Restructuring Charges					$ 100	$ 135
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member] | Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	$ 14	$ 43	$ 70	$ 103

X

- Definition Asset Write-Offs, Impairments, And Related Charges + References No definition available. + Details Name: etr_AssetWriteOffsImpairmentsAndRelatedCharges Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of expenses associated with exit or disposal activities pursuant to an authorized plan. Excludes expenses related to a discontinued operation or an asset retirement obligation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SAB Topic 5.P.3) -URI http://asc.fasb.org/extlink&oid=115931487&loc=d3e140864-122747 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6394359&loc=d3e17939-110869 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SAB Topic 5.P.4(b)) -URI http://asc.fasb.org/extlink&oid=115931487&loc=d3e140904-122747 + Details Name: us-gaap_RestructuringCharges Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_SegmentReportingInformationLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Details Name: us-gaap_StatementBusinessSegmentsAxis=etr_EntergyWholesaleCommoditiesMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_RestructuringCostAndReserveAxis=etr_EmployeeRetentionandSeverancesExpensesandOtherBenefitsRelatedCostsMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_SubsequentEventTypeAxis=us-gaap_SubsequentEventMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Retirement And Other Postretirement Benefits (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 176,900		$ 176,900
Defined Benefit Plan, Plan Assets, Contributions by Employer				123,100
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		27,112		27,112
Defined Benefit Plan, Plan Assets, Contributions by Employer				18,222
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		26,451		26,451
Defined Benefit Plan, Plan Assets, Contributions by Employer				18,272
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,701		7,701
Defined Benefit Plan, Plan Assets, Contributions by Employer				5,186
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		1,800		1,800
Defined Benefit Plan, Plan Assets, Contributions by Employer				1,237
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		1,645		1,645
Defined Benefit Plan, Plan Assets, Contributions by Employer				1,192
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		8,285		8,285
Defined Benefit Plan, Plan Assets, Contributions by Employer				5,631
Subsequent Event [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 8,890
Subsequent Event [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	8,179
Subsequent Event [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,515
Subsequent Event [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	563
Subsequent Event [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	453
Subsequent Event [Member] | System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 2,654
Non Qualified Pension Plans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		4,600	$ 4,200	16,300	$ 19,700
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits		955	212	4,600	7,000
Non Qualified Pension Plans [Member] | Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		67	114	211	369
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits			7		30
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		38	42	122	138
Non Qualified Pension Plans [Member] | Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		69	73	257	230
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits				40
Non Qualified Pension Plans [Member] | Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		5	20	16	62
Non Qualified Pension Plans [Member] | Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Net periodic benefit costs		$ 119	$ 122	$ 365	529
Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits					$ 139

X

- Definition Settlement Charge Associated With Out Of Plan Payment Of Lump Sum Benefits + References No definition available. + Details Name: etr_SettlementChargeAssociatedWithOutOfPlanPaymentOfLumpSumBenefits Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition A roll forward is a reconciliation of a concept from the beginning of a period to the end of a period. + References No definition available. + Details Name: us-gaap_DefinedBenefitPlanChangeInFairValueOfPlanAssetsRollForward Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Amount of contribution received by defined benefit plan from employer which increases plan assets. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (d)(iv)(01) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 3: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (d)(ii) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 4: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 Reference 5: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 + Details Name: us-gaap_DefinedBenefitPlanContributionsByEmployer Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of contributions expected to be received by defined benefit plan from employer in fiscal year. Excludes contributions paid by employer in current fiscal year. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanExpectedFutureEmployerContributionsRemainderOfFiscalYear Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of net periodic benefit cost (credit) for defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 + Details Name: us-gaap_DefinedBenefitPlanNetPeriodicBenefitCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_SubsequentEventTypeAxis=us-gaap_SubsequentEventMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_RetirementPlanTypeAxis=etr_NonQualifiedPensionPlansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 0.2	$ 0.2
Entergy Texas [Member]
Letters of Credit Outstanding, Amount		$ 4.1
Credit Facility Of Twenty Five Million [Member] | Entergy Arkansas [Member]
Uncommitted Credit Facility	$ 25.0
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 1.0
Credit Facility of Fifty Million [Member] | Entergy Texas [Member]
Uncommitted Credit Facility	$ 50.0
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 26.2
Credit Facility of Fifteen Million [Member] | Entergy New Orleans [Member]
Uncommitted Credit Facility	$ 15.0
Letter of Credit Fee, Percentage	1.00%
Letters of Credit Outstanding, Amount	$ 1.0
Credit Facility Of One Hundred Twenty Five Million [Member] | Entergy Louisiana [Member]
Uncommitted Credit Facility	$ 125.0
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 11.7
Credit Facility of Sixty Five Million [Member] | Entergy Mississippi [Member]
Uncommitted Credit Facility	$ 65.0
Letter of Credit Fee, Percentage	0.70%
Letters of Credit Outstanding, Amount	$ 8.1

X

- Definition Letter of Credit Fee, Percentage + References No definition available. + Details Name: etr_LetterofCreditFeePercentage Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

- Definition Maximum borrowing capacity under the uncommitted credit facility without consideration of any current restrictions on the amount that could be borrowed or the amounts currently outstanding under the facility. + References No definition available. + Details Name: etr_UncommittedCreditFacilityMaximumBorrowingCapacity Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The total amount of the contingent obligation under letters of credit outstanding as of the reporting date. + References No definition available. + Details Name: us-gaap_LettersOfCreditOutstandingAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_CreditFacilityAxis=etr_CreditFacilityOfTwentyFiveMillionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_CreditFacilityAxis=etr_CreditFacilityofFiftyMillionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_CreditFacilityAxis=etr_CreditFacilityofFifteenMillionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_CreditFacilityAxis=etr_CreditFacilityOfOneHundredTwentyFiveMillionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_CreditFacilityAxis=etr_CreditFacilityofSixtyFiveMillionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Risk Management and Fair Values (Reconciliation Of Changes In The Net Assets (Liabilities) For The Fair Value Of Derivatives Classified As Level 3 In The Fair Value Hierarchy) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	$ 48.0		$ 48.0
Issuance of Financial Transmission Rights			0.0	$ 0.0
Electricity Swaps And Options [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	48.0		48.0		$ 72.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value		$ (67.0)		(67.0)		$ (31.0)	$ (25.0)	$ (65.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1.0		4.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings		(4.0)		(5.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)			145.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Other Comprehensive Income (Loss)	(7.0)	(51.0)		(40.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.0	0.0	0.0	0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(18.0)		(70.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		13.0		43.0
Fixed Transmission Rights (FTRs) [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	16.0	29.0	16.0	29.0	29.0	15.0	41.0	21.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	0.0	0.0	0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(1.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Other Comprehensive Income (Loss)	0.0	0.0	0.0	0.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	12.0	19.0	44.0	67.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(25.0)	(31.0)	(78.0)	(104.0)
Issuance of Financial Transmission Rights			35.0	46.0
Fixed Transmission Rights (FTRs) [Member] | Entergy Arkansas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	3.9	11.3	3.9	11.3	8.2	3.4	10.5	3.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				16.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		10.9	6.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(0.8)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(3.5)	(10.1)	(15.4)	(20.1)
Issuance of Financial Transmission Rights			9.6	11.8
Fixed Transmission Rights (FTRs) [Member] | Entergy Louisiana [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	9.1	12.0	9.1	12.0	15.6	8.3	18.2	10.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				39.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	7.9	7.6	23.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(14.4)	(13.8)	(40.9)	(57.2)
Issuance of Financial Transmission Rights			18.7	20.0
Fixed Transmission Rights (FTRs) [Member] | Entergy Mississippi [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	1.5	3.7	1.5	3.7	2.8	2.2	4.4	2.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				20.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	0.6	4.7	0.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	(1.9)	(5.4)	(5.2)	(23.0)
Issuance of Financial Transmission Rights			3.9	4.5
Fixed Transmission Rights (FTRs) [Member] | Entergy New Orleans [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	0.7	2.1	0.7	2.1	2.0	1.3	3.0	2.2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings				6.7
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset		1.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset	(1.6)		(1.1)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements		(2.0)	(2.2)	(10.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	0.3
Issuance of Financial Transmission Rights			2.7	3.7
Fixed Transmission Rights (FTRs) [Member] | Entergy Texas [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value	1.3	0.1	1.3	0.1	$ 0.6		$ 4.7	$ 3.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability Value						$ (0.5)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings				(15.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset	6.2		15.3
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset		(5.0)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements	$ (5.5)		(13.6)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements		$ 0.4		5.6
Issuance of Financial Transmission Rights			$ 0.1	$ 6.1

X

- Definition Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset + References No definition available. + Details Name: etr_FairValueMeasurementwithUnobservableInputsReconciliationRecurringBasisAssetGainLossIncludedasRegulatoryLiabilityAsset Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included as Regulatory Liability/Asset + References No definition available. + Details Name: etr_FairValueMeasurementwithUnobservableInputsReconciliationRecurringBasisLiabilityGainLossIncludedasRegulatoryLiabilityAsset Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Issuance of Financial Transmission Rights + References No definition available. + Details Name: etr_IssuanceofFinancialTransmissionRights Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of gain (loss) recognized in the income statement for financial instrument classified as an asset measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(1) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisAssetGainLossIncludedInEarnings1 Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of gain (loss) recognized in other comprehensive income (loss) for financial instrument classified as an asset measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(1a) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisAssetGainLossIncludedInOtherComprehensiveIncomeLoss Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of settlement of financial instrument classified as an asset measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(2) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisAssetSettlements Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Fair value of financial instrument classified as an asset measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisAssetValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of gain (loss) recognized on the income statement for financial instrument classified as a liability measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(1) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisLiabilityGainLossIncludedInEarnings Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of gain (loss) recognized in other comprehensive income (loss) for financial instrument classified as a liability measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(1a) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisLiabilityGainLossIncludedInOtherComprehensiveIncome Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of settlements of financial instrument classified as a liability measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c)(2) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisLiabilitySettlements Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Fair value of financial instrument classified as a liability measured using unobservable inputs that reflect the entity's own assumption about the assumptions market participants would use in pricing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_FairValueMeasurementWithUnobservableInputsReconciliationsRecurringBasisLiabilityValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition A roll forward is a reconciliation of a concept from the beginning of a period to the end of a period. + References No definition available. + Details Name: us-gaap_FairValueNetDerivativeAssetLiabilityMeasuredOnRecurringBasisUnobservableInputReconciliationRollForward Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Details Name: us-gaap_DerivativeInstrumentRiskAxis=etr_ElectricityFuturesForwardsSwapsAndOptionsMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_DerivativeInstrumentRiskAxis=etr_FinancialTransmissionRightsFTRsMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Risk Management and Fair Values (Fair Values Of Derivative Instruments) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Utility [Member]
Liabilities:
Letters of Credit Outstanding, Amount		$ 4.0
Entergy Wholesale Commodities [Member]
Derivatives, Fair Value [Line Items]
Cash collateral posted	$ 13.0	19.0
Assets:
Derivative, Collateral, Obligation to Return Cash	(2.0)
Liabilities:
Letters of Credit Held	48.0
Other Non-Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	2.0	20.0
Derivative, Collateral, Right to Reclaim Cash	(2.0)	(7.0)
Derivative Liability	0.0	13.0
Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1.0
Derivative, Collateral, Right to Reclaim Cash	0.0
Derivative Liability	1.0
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	12.0	0.0
Derivative Asset, Fair Value, Gross Asset	14.0	7.0
Derivative, Collateral, Obligation to Return Cash	(2.0)	(7.0)
Other Deferred Debits And Other Assets [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset		1.0
Derivative Asset, Fair Value, Gross Asset		1.0
Derivative, Collateral, Obligation to Return Cash		0.0
Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.0	2.0
Derivative Asset, Fair Value, Gross Asset	1.0	2.0
Derivative, Collateral, Obligation to Return Cash		0.0
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	30.0	0.0
Derivative Asset, Fair Value, Gross Asset	35.0	32.0
Derivative, Collateral, Obligation to Return Cash	(5.0)	(32.0)
Prepayments And Other [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	6.0	2.0
Derivative Asset, Fair Value, Gross Asset	9.0	4.0
Derivative, Collateral, Obligation to Return Cash	(3.0)	(2.0)
Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Utility and Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	16.0	15.0
Derivative Asset, Fair Value, Gross Asset	17.0	16.0
Derivative, Collateral, Obligation to Return Cash	(1.0)	(1.0)
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	5.0	54.0
Derivative, Collateral, Right to Reclaim Cash	(5.0)	(33.0)
Derivative Liability	0.0	21.0
Other Current Liabilities [Member] | Electricity Swaps And Options [Member] | Entergy Wholesale Commodities [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	4.0	1.0
Derivative, Collateral, Right to Reclaim Cash	(4.0)	(1.0)
Derivative Liability	0.0	0.0
Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Utility [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	4.0	1.0
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	4.0	1.0
Entergy Louisiana [Member] | Other Non-Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1.4
Derivative, Collateral, Right to Reclaim Cash	0.0
Derivative Liability	1.4
Entergy Louisiana [Member] | Other Deferred Debits And Other Assets [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.0	1.6
Derivative Asset, Fair Value, Gross Asset	1.0	1.6
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.1	0.3
Derivative Asset, Fair Value, Gross Asset	0.1	0.3
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Louisiana [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	9.1	8.3
Derivative Asset, Fair Value, Gross Asset	9.1	8.4
Derivative, Collateral, Obligation to Return Cash	0.0	(0.1)
Entergy Louisiana [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	2.2	1.1
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	2.2	1.1
Entergy Mississippi [Member]
Liabilities:
Letters of Credit Outstanding, Amount	0.2	0.2
Entergy Mississippi [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.5	2.2
Derivative Asset, Fair Value, Gross Asset	1.5	2.2
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy Mississippi [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	1.1
Derivative, Collateral, Right to Reclaim Cash	0.0
Derivative Liability	1.1
Entergy New Orleans [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	0.7	1.3
Derivative Asset, Fair Value, Gross Asset	0.7	1.3
Derivative, Collateral, Obligation to Return Cash	0.0	0.0
Entergy New Orleans [Member] | Other Current Liabilities [Member] | Natural Gas Swaps [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability	0.1	0.1
Derivative, Collateral, Right to Reclaim Cash	0.0	0.0
Derivative Liability	0.1	0.1
Entergy Arkansas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	3.9	3.4
Derivative Asset, Fair Value, Gross Asset	4.0	3.6
Derivative, Collateral, Obligation to Return Cash	(0.1)	(0.2)
Entergy Texas [Member]
Liabilities:
Letters of Credit Outstanding, Amount		4.1
Entergy Texas [Member] | Prepayments And Other [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Assets:
Derivative Asset	1.3
Derivative Asset, Fair Value, Gross Asset	1.7
Derivative, Collateral, Obligation to Return Cash	$ (0.4)
Entergy Texas [Member] | Other Current Liabilities [Member] | Fixed Transmission Rights (FTRs) [Member] | Not Designated As Hedging Instrument [Member]
Liabilities:
Derivative Liability, Fair Value, Gross Liability		0.9
Derivative, Collateral, Right to Reclaim Cash		(1.4)
Derivative Liability		$ (0.5)

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v3.19.3

Equity (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 01, 2019	Dec. 31, 2018	Jan. 01, 2018	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets									$ 0		$ (56,360)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	$ (419,772)	$ (430,404)		$ (632,126)	$ (613,642)		$ (419,772)	$ (632,126)		$ (557,173)		$ (23,531)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									(6,806)		(632,617)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	3,160			(47,574)			160,205	(82,774)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	7,472			29,090			(15,998)	91,291
Other comprehensive income (loss)	10,632	120,748	$ 12,827	(18,484)	(52,144)	$ 79,145	144,207	8,517
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						(16,538)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								15,505
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	32,007	26,736		(10,587)	(8,842)		32,007	(10,587)		(2,116)		545,045
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									879		(632,617)
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	8,350			(7,173)			37,724	(50,958)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(3,079)			5,428			(4,480)	13,716
Other comprehensive income (loss)	5,271			(1,745)			33,244	(37,242)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								114,227
Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets									(6,806)		(632,617)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	10,632	120,748	12,827	(18,484)	(52,144)	79,145
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						15,505
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(483,412)	(508,876)		(574,661)	(589,926)		(483,412)	(574,661)		(531,922)		(531,099)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									0		0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0			0			0	0
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	25,464			15,265			48,510	47,404
Other comprehensive income (loss)	25,464			15,265			48,510	47,404
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								(90,966)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	31,633	51,736		(46,878)	(14,874)		31,633	(46,878)		(23,135)		(37,477)
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax									(7,685)		0
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	(5,190)			(40,401)			122,481	(31,816)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(14,913)			8,397			(60,028)	30,171
Other comprehensive income (loss)	(20,103)			(32,004)			62,453	(1,645)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects								(7,756)
Entergy Louisiana [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(9,060)						(9,060)			(6,153)
Other comprehensive income (loss)	(969)	(969)	(969)	(500)	(501)	(501)	(2,907)	(1,502)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						(3,787)
Entergy Louisiana [Member] | Accumulated Other Comprehensive Income [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive income (loss)	(969)	(969)	$ (969)	(500)	(501)	(501)
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect						$ (10,049)
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss	(9,060)	$ (8,091)		(57,951)	$ (57,451)		(9,060)	(57,951)		$ (6,153)		$ (46,400)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	(969)			(500)			(2,907)	(1,502)
Other comprehensive income (loss)	$ (969)			$ (500)			(2,907)	(1,502)
Tax Cuts and Jobs Act, Reclassification from AOCI resulting from stranded tax effects							$ 0	$ (10,049)
Restatement Adjustment [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(563,979)		(656,148)
Restatement Adjustment [Member] | Accumulated Net Investment Gain (Loss) Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(1,237)		(87,572)
Restatement Adjustment [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									(531,922)		(531,099)
Restatement Adjustment [Member] | Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Accumulated other comprehensive loss									$ (30,820)		$ (37,477)

X

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- Definition Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 11 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e637-108580 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 14A -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669686-108580 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 14 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e681-108580 + Details Name: us-gaap_AccumulatedOtherComprehensiveIncomeLossNetOfTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of cumulative effect of the change in accounting principle or new accounting pronouncement on retained earnings or other components of equity or net assets in the statement of financial position as of the beginning of the earliest period presented. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22499-107794 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22583-107794 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22580-107794 + Details Name: us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1 Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Credit Facilities) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Amount of Facility	$ 3,500,000
Amount Drawn/ Outstanding	155,000
Entergy Arkansas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 5,000
Entergy Arkansas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 150,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Arkansas [Member] | Credit Facility Of Twenty Million [Member]
Expiration Date	Apr. 30, 2020
Amount of Facility	$ 20,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Louisiana [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 15,000
Entergy Louisiana [Member] | Credit Facility Of Three Hundred Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 350,000
Interest Rate	3.17%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy Mississippi [Member]
Letters of Credit Outstanding, Amount	$ 200	$ 200
Entergy Mississippi [Member] | Credit Facility Of Thirty Seven Point Five Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 37,500
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Thirty Five Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 35,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 0
Entergy Mississippi [Member] | Credit Facility Of Ten Million [Member]
Expiration Date	May 31, 2020
Amount of Facility	$ 10,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	0
Entergy New Orleans [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 10,000
Entergy New Orleans [Member] | Credit Facility Of Twenty Five Million [Member]
Expiration Date	Nov. 20, 2021
Amount of Facility	$ 25,000
Interest Rate	3.32%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	800
Entergy Texas [Member]
Amount of total borrowing capacity against which fronting commitments exist	$ 30,000
Letters of Credit Outstanding, Amount		$ 4,100
Entergy Texas [Member] | Credit Facility Of One Hundred And Fifty Million [Member]
Expiration Date	Sep. 14, 2024
Amount of Facility	$ 150,000
Interest Rate	3.54%
Amount Drawn/ Outstanding	$ 0
Letters of Credit Outstanding, Amount	$ 1,300

X

- Definition Amount of total borrowing capacity against which fronting commitments exist + References No definition available. + Details Name: etr_Amountoftotalborrowingcapacityagainstwhichfrontingcommitmentsexist Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The total amount of the contingent obligation under letters of credit outstanding as of the reporting date. + References No definition available. + Details Name: us-gaap_LettersOfCreditOutstandingAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(16)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_LineOfCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Date the credit facility terminates, in CCYY-MM-DD format. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityExpirationDate1 Namespace Prefix: us-gaap_ Data Type: xbrli:dateItemType Balance Type: na Period Type: duration

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- Definition The effective interest rate during the reporting period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityInterestRateDuringPeriod Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

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- Definition Maximum borrowing capacity under the credit facility without consideration of any current restrictions on the amount that could be borrowed or the amounts currently outstanding under the facility. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityMaximumBorrowingCapacity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Book Value And The Fair Value Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Long-term Debt, Fair Value	$ 18,628,268	$ 15,880,239
Long-term Debt, Book Value	17,458,026	16,168,312
Entergy Arkansas [Member]
Long-term Debt, Fair Value	3,621,073	3,002,627
Long-term Debt, Book Value	3,538,384	3,225,759
Long term DOE obligations	190,000	187,000
Entergy Louisiana [Member]
Long-term Debt, Fair Value	8,038,675	6,834,134
Long-term Debt, Book Value	7,344,160	6,805,768
Entergy Mississippi [Member]
Long-term Debt, Fair Value	1,586,199	1,276,452
Long-term Debt, Book Value	1,469,454	1,325,750
Entergy New Orleans [Member]
Long-term Debt, Fair Value	522,688	491,569
Long-term Debt, Book Value	478,619	483,704
Entergy Texas [Member]
Long-term Debt, Fair Value	2,128,842	1,528,828
Long-term Debt, Book Value	1,938,303	1,513,735
System Energy [Member]
Long-term Debt, Fair Value	554,374	596,123
Long-term Debt, Book Value	570,001	630,750
Capital Lease Obligations	$ 34,000	$ 34,000

X

- Definition Long-term Debt, Book Value + References No definition available. + Details Name: etr_LongTermDebtBookValue Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Long term DOE obligations + References No definition available. + Details Name: etr_LongTermDoeObligations Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount equal to the present value (the principal) at the beginning of the lease term of minimum lease payments during the lease term (excluding that portion of the payments representing executory costs such as insurance, maintenance, and taxes to be paid by the lessor, together with any profit thereon) net of payments or other amounts applied to the principal through the balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_CapitalLeaseObligations Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The fair value amount of long-term debt whether such amount is presented as a separate caption or as a parenthetical disclosure. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. The element may be used in both the balance sheet and disclosure in the same submission. + References No definition available. + Details Name: us-gaap_LongTermDebtFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Stock-Based Compensation (Tables) - Entergy Corporation [Member]	9 Months Ended
	Sep. 30, 2019
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Financial Information For Stock Options	The following table includes financial information for outstanding stock options for the three months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $0.9   $1.1 Tax benefit recognized in Entergy’s net income $0.2   $0.2 Compensation cost capitalized as part of fixed assets and materials and supplies $0.4   $0.1 The following table includes financial information for outstanding stock options for the nine months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $2.9   $3.3 Tax benefit recognized in Entergy’s net income $0.7   $0.8 Compensation cost capitalized as part of fixed assets and materials and supplies $1.0   $0.5
Financial Information For Restricted Stock	The following table includes financial information for other outstanding equity awards for the three months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $8.4   $8.5 Tax benefit recognized in Entergy’s net income $2.1   $2.2 Compensation cost capitalized as part of fixed assets and materials and supplies $3.0   $2.5 The following table includes financial information for other outstanding equity awards for the nine months ended September 30, 2019 and 2018:   2019   2018   (In Millions) Compensation expense included in Entergy’s net income $25.6   $26.0 Tax benefit recognized in Entergy’s net income $6.5   $6.6 Compensation cost capitalized as part of fixed assets and materials and supplies $8.8   $7.3

X

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v3.19.3

Consolidated Balance Sheets - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018	Dec. 31, 2017
Cash and cash equivalents:
Cash	$ 70,395	$ 56,690
Temporary cash investments	885,436	424,285
Total cash and cash equivalents	955,831	480,975	$ 987,981	$ 781,273
Securitization recovery trust account	55,000	51,000
Accounts receivable:
Customer	732,763	558,494
Allowance for doubtful accounts	(7,987)	(7,322)
Other	132,547	167,722
Accrued unbilled revenues	481,048	395,511
Total accounts receivable	1,338,371	1,114,405
Deferred fuel costs	0	27,251
Fuel inventory - at average cost	131,703	117,304
Public Utilities, Inventory	803,843	752,843
Deferred nuclear refueling outage costs	173,229	230,960
Prepaid Expense and Other Assets, Current	258,695	234,326
TOTAL	3,661,672	2,958,064
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	6,128,647	6,920,164
Non-utility property - at cost (less accumulated depreciation)	326,704	304,382
Other	448,140	437,265
TOTAL	6,903,491	7,661,811
PROPERTY, PLANT, AND EQUIPMENT
Electric	52,705,142	49,831,486
Natural gas	533,217	496,150
Construction work in progress	2,871,054	2,888,639
Nuclear fuel	707,198	861,272
TOTAL PROPERTY, PLANT, AND EQUIPMENT	56,816,611	54,077,547
Less - accumulated depreciation and amortization	22,695,886	22,103,101
PROPERTY, PLANT, AND EQUIPMENT - NET	34,120,725	31,974,446
Regulatory assets:
Other regulatory assets	4,839,357	4,746,496
Deferred Fuel Cost Non Current	239,793	239,496
Goodwill	377,172	377,172
Deferred Income Tax Assets, Net	67,438	54,593
Other	296,620	262,988
Deferred Costs and Other Assets	5,820,380	5,680,745
TOTAL ASSETS	50,506,268	48,275,066
CURRENT LIABILITIES
Currently maturing long-term debt	520,012	650,009
Short-term borrowings	1,917,788	1,942,339
Accounts payable	1,328,631	1,496,058
Customer deposits	409,090	411,505
Taxes Payable, Current	251,821	254,241
Interest accrued	190,877	193,192
Deferred fuel costs	115,761	52,396
Pension and other postretirement liabilities	57,374	61,240
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	117,575	248,127
Other	194,117	134,437
TOTAL	5,103,046	5,443,544
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	4,552,456	4,107,152
Accumulated deferred investment tax credits	206,837	213,101
Regulatory liability for income taxes - net	1,677,707	1,817,021
Other regulatory liabilities	1,871,005	1,620,254
Decommissioning and asset retirement cost liabilities	6,068,323	6,355,543
Loss Contingency Accrual	528,172	514,107
Pension and other postretirement liabilities	2,487,906	2,616,085
Long-term debt	16,938,014	15,518,303
Deferred Credits and Other Liabilities	783,330	1,006,249
TOTAL	35,113,750	33,767,815
Subsidiaries' preferred stock without sinking fund	219,411	219,402
Common Shareholders' Equity:
Common Stock, Value, Issued	2,700	2,616
Additional Paid in Capital, Common Stock	6,553,009	5,951,431
Accumulated other comprehensive loss	(419,772)	(557,173)	(632,126)	(23,531)
Less - treasury stock, at cost	5,158,625	5,273,719
TOTAL	10,035,061	8,844,305
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	0
Retained Earnings (Accumulated Deficit)	9,057,749	8,721,150
TOTAL	10,070,061	8,844,305	8,412,712	7,992,515
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	50,506,268	48,275,066
Entergy Arkansas [Member]
Cash and cash equivalents:
Cash	410	118
Temporary cash investments	76,659	1
Total cash and cash equivalents	77,069	119	221,782	6,216
Securitization recovery trust account	7,904	4,666
Accounts receivable:
Customer	160,955	94,348
Allowance for doubtful accounts	(1,423)	(1,264)
Associated companies	45,499	48,184
Other	48,569	64,393
Accrued unbilled revenues	137,444	108,092
Total accounts receivable	391,044	313,753
Deferred fuel costs	0	19,235
Fuel inventory - at average cost	28,498	23,148
Public Utilities, Inventory	207,541	196,314
Deferred nuclear refueling outage costs	33,581	78,966
Prepaid Expense and Other Assets, Current	17,447	14,553
TOTAL	763,084	650,754
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,045,826	912,049
Other	5,476	5,480
TOTAL	1,051,302	917,529
PROPERTY, PLANT, AND EQUIPMENT
Electric	12,041,822	11,611,041
Construction work in progress	299,195	243,731
Nuclear fuel	186,731	220,602
TOTAL PROPERTY, PLANT, AND EQUIPMENT	12,527,748	12,075,374
Less - accumulated depreciation and amortization	4,985,276	4,864,818
PROPERTY, PLANT, AND EQUIPMENT - NET	7,542,472	7,210,556
Regulatory assets:
Other regulatory assets	1,590,726	1,534,977
Deferred Fuel Cost Non Current	67,591	67,294
Other	21,441	20,486
Deferred Costs and Other Assets	1,679,758	1,622,757
TOTAL ASSETS	11,036,616	10,401,596
CURRENT LIABILITIES
Associated companies accounts payable	55,971	251,768
Accounts payable	195,783	187,387
Customer deposits	101,349	99,053
Taxes Payable, Current	38,281	56,889
Interest accrued	39,099	18,893
Deferred fuel costs	33,530	0
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	33,692	99,316
Other	48,516	23,943
TOTAL	546,221	737,249
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	1,172,542	1,085,545
Accumulated deferred investment tax credits	32,002	32,903
Regulatory liability for income taxes - net	480,573	505,748
Other regulatory liabilities	526,004	402,668
Decommissioning and asset retirement cost liabilities	1,224,936	1,048,428
Loss Contingency Accrual	57,820	48,979
Pension and other postretirement liabilities	287,086	313,295
Long-term debt	3,538,384	3,225,759
Deferred Credits and Other Liabilities	63,809	17,919
TOTAL	7,383,156	6,681,244
Common Shareholders' Equity:
Members' Equity	3,107,239	2,983,103
TOTAL	3,107,239	2,983,103	2,973,384	2,376,754
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	11,036,616	10,401,596
Entergy Louisiana [Member]
Cash and cash equivalents:
Cash	224	252
Temporary cash investments	127,821	43,112
Total cash and cash equivalents	128,045	43,364	213,585	35,907
Securitization recovery trust account	10,100	3,600
Accounts receivable:
Customer	258,090	199,903
Allowance for doubtful accounts	(2,154)	(1,813)
Associated companies	81,906	123,363
Other	46,282	60,879
Accrued unbilled revenues	194,753	167,052
Total accounts receivable	578,877	549,384
Fuel inventory - at average cost	36,170	34,418
Public Utilities, Inventory	344,207	324,627
Deferred nuclear refueling outage costs	70,456	24,406
Prepaid Expense and Other Assets, Current	47,519	38,715
TOTAL	1,205,274	1,014,914
Investments in and Advances to Affiliates, at Fair Value	1,390,587	1,390,587
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,485,569	1,284,996
Non-utility property - at cost (less accumulated depreciation)	308,095	286,555
Storm Reserve Escrow Account	294,538	289,525
Other	13,923	14,927
TOTAL	3,492,712	3,266,590
PROPERTY, PLANT, AND EQUIPMENT
Electric	22,283,456	20,532,312
Natural gas	230,416	211,421
Construction work in progress	1,325,784	1,864,582
Nuclear fuel	291,404	298,022
TOTAL PROPERTY, PLANT, AND EQUIPMENT	24,131,060	22,906,337
Less - accumulated depreciation and amortization	9,018,154	8,837,596
PROPERTY, PLANT, AND EQUIPMENT - NET	15,112,906	14,068,741
Regulatory assets:
Other regulatory assets	1,208,712	1,105,077
Deferred Fuel Cost Non Current	168,122	168,122
Other	27,297	28,371
Deferred Costs and Other Assets	1,404,131	1,301,570
TOTAL ASSETS	21,215,023	19,651,815
CURRENT LIABILITIES
Currently maturing long-term debt	70,002	2
Associated companies accounts payable	86,781	102,749
Accounts payable	338,724	390,367
Customer deposits	152,627	155,314
Taxes Payable, Current	109,778	30,868
Interest accrued	88,552	83,450
Deferred fuel costs	19,952	31,411
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	33,231	31,457
Other	71,608	49,202
TOTAL	971,255	874,820
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	2,414,508	2,226,721
Accumulated deferred investment tax credits	113,346	116,999
Regulatory liability for income taxes - net	523,697	581,001
Other regulatory liabilities	778,199	748,784
Decommissioning and asset retirement cost liabilities	1,478,951	1,280,272
Loss Contingency Accrual	320,503	310,755
Pension and other postretirement liabilities	627,155	643,171
Long-term debt	7,274,158	6,805,766
Deferred Credits and Other Liabilities	402,296	160,608
TOTAL	13,932,813	12,874,077
Common Shareholders' Equity:
Accumulated other comprehensive loss	(9,060)	(6,153)
Members' Equity	6,320,015	5,909,071
TOTAL	6,310,955	5,902,918	5,761,778	5,308,804
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	21,215,023	19,651,815
Entergy Mississippi [Member]
Cash and cash equivalents:
Cash	11	11
Temporary cash investments	98,925	36,943
Total cash and cash equivalents	98,936	36,954	45	6,096
Accounts receivable:
Customer	98,245	73,205
Allowance for doubtful accounts	(615)	(563)
Associated companies	19,217	51,065
Other	10,173	8,647
Accrued unbilled revenues	60,867	50,171
Total accounts receivable	187,887	182,525
Deferred fuel costs	0	8,016
Fuel inventory - at average cost	15,803	11,931
Public Utilities, Inventory	51,049	47,255
Prepaid Expense and Other Assets, Current	8,694	9,365
TOTAL	362,369	296,046
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	4,564	4,576
Escrow accounts	32,953	32,447
TOTAL	37,517	37,023
PROPERTY, PLANT, AND EQUIPMENT
Electric	4,981,082	4,780,720
Construction work in progress	177,221	128,149
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,158,303	4,908,869
Less - accumulated depreciation and amortization	1,681,597	1,641,821
PROPERTY, PLANT, AND EQUIPMENT - NET	3,476,706	3,267,048
Regulatory assets:
Other regulatory assets	343,972	343,049
Other	12,161	3,638
Deferred Costs and Other Assets	356,133	346,687
TOTAL ASSETS	4,232,725	3,946,804
CURRENT LIABILITIES
Currently maturing long-term debt	0	150,000
Associated companies accounts payable	41,323	42,928
Accounts payable	81,260	79,117
Customer deposits	86,295	85,085
Taxes Payable, Current	50,996	77,552
Interest accrued	22,324	20,231
Deferred fuel costs	39,553	0
Other	17,717	7,526
TOTAL	339,468	462,439
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	591,105	551,869
Accumulated deferred investment tax credits	10,066	10,186
Regulatory liability for income taxes - net	239,630	246,402
Other regulatory liabilities	23,779	33,622
Decommissioning and asset retirement cost liabilities	9,594	9,206
Loss Contingency Accrual	48,043	51,142
Pension and other postretirement liabilities	86,036	93,100
Long-term debt	1,469,454	1,175,750
Deferred Credits and Other Liabilities	25,022	20,862
TOTAL	2,502,729	2,192,139
Common Shareholders' Equity:
Members' Equity	1,390,528	1,292,226
TOTAL	1,390,528	1,292,226	1,288,973	1,177,870
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,232,725	3,946,804
Entergy New Orleans [Member]
Cash and cash equivalents:
Cash	26	26
Temporary cash investments	0	19,651
Total cash and cash equivalents	26	19,677	32,920	32,741
Securitization recovery trust account	5,268	2,224
Accounts receivable:
Customer	57,173	43,890
Allowance for doubtful accounts	(3,116)	(3,222)
Associated companies	2,541	27,938
Other	4,954	4,090
Accrued unbilled revenues	22,776	18,907
Total accounts receivable	84,328	91,603
Fuel inventory - at average cost	1,907	1,533
Public Utilities, Inventory	12,865	12,133
Prepaid Expense and Other Assets, Current	10,655	6,905
TOTAL	115,049	134,075
OTHER PROPERTY AND INVESTMENTS
Non-utility property - at cost (less accumulated depreciation)	1,016	1,016
Storm Reserve Escrow Account	82,236	80,853
TOTAL	83,252	81,869
PROPERTY, PLANT, AND EQUIPMENT
Electric	1,430,352	1,364,091
Natural gas	302,801	284,728
Construction work in progress	196,842	146,668
TOTAL PROPERTY, PLANT, AND EQUIPMENT	1,929,995	1,795,487
Less - accumulated depreciation and amortization	699,525	670,135
PROPERTY, PLANT, AND EQUIPMENT - NET	1,230,470	1,125,352
Regulatory assets:
Other regulatory assets	244,231	229,796
Deferred Fuel Cost Non Current	4,080	4,080
Other	1,749	1,416
Deferred Costs and Other Assets	250,060	235,292
TOTAL ASSETS	1,678,831	1,576,588
CURRENT LIABILITIES
Notes Payable, Related Parties, Current	1,979	1,979
Associated companies accounts payable	85,485	43,416
Accounts payable	37,394	36,686
Customer deposits	28,515	28,667
Taxes Payable, Current	4,310	4,068
Interest accrued	6,380	6,366
Deferred fuel costs	9,616	1,288
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	15,439	25,301
Other	7,182	9,521
TOTAL	196,300	157,292
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	349,600	323,595
Accumulated deferred investment tax credits	2,153	2,219
Regulatory liability for income taxes - net	52,705	60,249
Decommissioning and asset retirement cost liabilities	3,463	3,291
Loss Contingency Accrual	88,017	86,594
Long-term debt	462,273	467,358
Notes Payable, Related Parties, Noncurrent	14,367	14,367
Deferred Credits and Other Liabilities	18,069	16,673
TOTAL	990,647	974,346
Common Shareholders' Equity:
Members' Equity	491,884	444,950
TOTAL	491,884	444,950	442,356	415,548
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	1,678,831	1,576,588
Entergy Texas [Member]
Cash and cash equivalents:
Cash	25	26
Temporary cash investments	92,253	30
Total cash and cash equivalents	92,278	56	20,497	115,513
Securitization recovery trust account	31,649	40,185
Accounts receivable:
Customer	88,557	69,714
Allowance for doubtful accounts	(680)	(461)
Associated companies	24,124	64,441
Other	6,770	12,275
Accrued unbilled revenues	65,207	51,288
Total accounts receivable	183,978	197,257
Fuel inventory - at average cost	44,143	42,667
Public Utilities, Inventory	43,774	41,883
Prepaid Expense and Other Assets, Current	22,266	15,903
TOTAL	418,088	337,951
OTHER PROPERTY AND INVESTMENTS
Investment in affiliates - at equity	413	448
Non-utility property - at cost (less accumulated depreciation)	376	376
Other	19,863	19,218
TOTAL	20,652	20,042
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,028,850	4,773,984
Construction work in progress	663,465	325,193
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,692,315	5,099,177
Less - accumulated depreciation and amortization	1,745,046	1,684,569
PROPERTY, PLANT, AND EQUIPMENT - NET	3,947,269	3,414,608
Regulatory assets:
Other regulatory assets	534,255	598,048
Other	32,861	29,371
Deferred Costs and Other Assets	567,116	627,419
TOTAL ASSETS	4,953,125	4,400,020
CURRENT LIABILITIES
Currently maturing long-term debt	0	500,000
Associated companies accounts payable	45,090	119,371
Accounts payable	169,788	150,679
Customer deposits	40,304	43,387
Taxes Payable, Current	57,058	53,513
Interest accrued	12,877	24,355
Deferred fuel costs	13,109	19,697
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	35,213	87,627
Other	8,786	6,353
TOTAL	382,225	1,004,982
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	581,310	552,535
Accumulated deferred investment tax credits	10,713	11,176
Regulatory liability for income taxes - net	236,463	264,623
Other regulatory liabilities	44,784	47,884
Decommissioning and asset retirement cost liabilities	7,526	7,222
Loss Contingency Accrual	10,386	13,856
Long-term debt	1,938,303	1,013,735
Deferred Credits and Other Liabilities	64,635	61,605
TOTAL	2,894,120	1,972,636
Common Shareholders' Equity:
Common Stock, Value, Issued	49,452	49,452
Additional Paid in Capital, Common Stock	682,980	596,994
TOTAL	1,641,780	1,422,402
Stockholders' Equity Attributable to Noncontrolling Interest	35,000	0
Retained Earnings (Accumulated Deficit)	909,348	775,956
TOTAL	1,676,780	1,422,402	1,374,152	1,260,167
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	4,953,125	4,400,020
System Energy [Member]
Cash and cash equivalents:
Cash	79	68
Temporary cash investments	164,246	95,617
Total cash and cash equivalents	164,325	95,685	254,541	287,187
Accounts receivable:
Associated companies	62,740	148,571
Other	6,330	5,390
Total accounts receivable	69,070	153,961
Public Utilities, Inventory	111,927	97,225
Deferred nuclear refueling outage costs	20,253	44,424
Prepaid Expense and Other Assets, Current	9,040	2,985
Prepaid Taxes	0	5,415
TOTAL	374,615	399,695
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds	1,002,261	869,543
TOTAL	1,002,261	869,543
PROPERTY, PLANT, AND EQUIPMENT
Electric	5,036,030	5,036,116
Construction work in progress	141,858	70,156
Nuclear fuel	158,745	234,889
TOTAL PROPERTY, PLANT, AND EQUIPMENT	5,336,633	5,341,161
Less - accumulated depreciation and amortization	3,273,504	3,212,080
PROPERTY, PLANT, AND EQUIPMENT - NET	2,063,129	2,129,081
Regulatory assets:
Other regulatory assets	455,492	446,371
Other	3,759	4,124
Deferred Costs and Other Assets	459,251	450,495
TOTAL ASSETS	3,899,256	3,848,814
CURRENT LIABILITIES
Currently maturing long-term debt	10	6
Associated companies accounts payable	11,475	11,031
Accounts payable	61,391	47,565
Taxes Payable, Current	9,164	0
Interest accrued	11,817	13,295
Current portion of regulatory liability for income taxes - net related to unprotected ADIT	0	4,426
Other	2,829	2,832
TOTAL	96,686	79,155
NON-CURRENT LIABILITIES
Deferred Income Tax Liabilities, Net	811,875	805,296
Accumulated deferred investment tax credits	37,714	38,673
Regulatory liability for income taxes - net	144,639	158,998
Other regulatory liabilities	490,790	381,887
Decommissioning and asset retirement cost liabilities	922,663	896,000
Pension and other postretirement liabilities	93,626	98,639
Long-term debt	569,991	630,744
Deferred Credits and Other Liabilities	31,493	22,224
TOTAL	3,102,791	3,032,461
Common Shareholders' Equity:
Common Stock, Value, Issued	601,850	601,850
Retained Earnings (Accumulated Deficit)	97,929	135,348
TOTAL	699,779	737,198	$ 714,996	$ 710,809
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	$ 3,899,256	$ 3,848,814

X

- Definition Accounts Receivable. + References No definition available. + Details Name: etr_AccountsReceivableAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Unbilled amounts due for services rendered or products shipped. This element is distinct from unbilled contracts receivables because this is based on noncontract transactions. + References No definition available. + Details Name: etr_AccruedUnbilledRevenues Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Common Shareholders Equity. + References No definition available. + Details Name: etr_CommonShareholdersEquityAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Current portion of regulatory liability for income taxes - net related to unprotected ADIT + References No definition available. + Details Name: etr_CurrentportionofregulatoryliabilityforincometaxesnetrelatedtounprotectedADIT Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Carrying amount as of the balance sheet date of capitalized fuel costs of a regulated entity that are expected to be recoverable through rate adjustments after one year or the normal operating cycle, if longer. + References No definition available. + Details Name: etr_DeferredFuelCostNonCurrent Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Carrying amount as of the balance sheet date of capitalized fuel costs of a regulated entity that are expected to be returned to customers through rate adjustments within one year. + References No definition available. + Details Name: etr_DeferredFuelCostsCurrentLiabilities Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Costs deferred during a nuclear refueling outage and amortized over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. + References No definition available. + Details Name: etr_DeferredNuclearRefuelingOutageCosts Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Escrow accounts + References No definition available. + Details Name: etr_EscrowAccounts Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Fossil fuel inventory held for consumption in the production of energy. + References No definition available. + Details Name: etr_FuelInventoryAtAverageCost Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Period end amount of property, plant and equipment (PPE) related to transmission and distribution of natural gas for resale owned by public utility. + References No definition available. + Details Name: etr_NaturalGas Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Carrying amount as of the balance sheet date of capitalized costs of regulated entities that are not expected to be recovered through revenue sources within one year or the normal operating cycle if longer and are not specifically broken out elsewhere in the balance sheet. + References No definition available. + Details Name: etr_OtherRegulatoryAssets Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Regulatory Asset. + References No definition available. + Details Name: etr_RegulatoryAssetAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Regulatory liability for income taxes - net. + References No definition available. + Details Name: etr_RegulatoryLiabilityForIncomeTaxesNet Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Storm reserve escrow account. + References No definition available. + Details Name: etr_StormReserveEscrowAccount Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Carrying value as of the balance sheet date of liabilities incurred (and for which invoices have typically been received) and payable to vendors for goods and services received that are used in an entity's business. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(a)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_AccountsPayableCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount due from customers or clients, within one year of the balance sheet date (or the normal operating cycle, whichever is longer), for goods or services (including trade receivables) that have been delivered or sold in the normal course of business, reduced to the estimated net realizable fair value by an allowance established by the entity of the amount it deems uncertain of collection. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 606 -SubTopic 10 -Section 50 -Paragraph 8 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109196051&loc=SL49130549-203045 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(3)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_AccountsReceivableNetCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of receivables arising from transactions with related parties due within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(k)(1)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 850 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39549-107864 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.3(a)(2)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 850 -SubTopic 10 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39622-107864 Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 850 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39603-107864 + Details Name: us-gaap_AccountsReceivableRelatedPartiesCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition The noncurrent portion of the reserve for accumulated deferred investment tax credits as of the balance sheet date. This is the remaining investment credit, which will reduce the cost of services collected from ratepayers by a ratable portion over the investment's regulatory life. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 255 -SubTopic 10 -Section 55 -Paragraph 8 -URI http://asc.fasb.org/extlink&oid=82838779&loc=d3e2408-110839 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.26(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 45 -Paragraph 27 -URI http://asc.fasb.org/extlink&oid=84176650&loc=d3e32262-109318 + Details Name: us-gaap_AccumulatedDeferredInvestmentTaxCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 11 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e637-108580 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 14A -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669686-108580 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 14 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e681-108580 + Details Name: us-gaap_AccumulatedOtherComprehensiveIncomeLossNetOfTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Value received from shareholders in common stock-related transactions that are in excess of par value or stated value and amounts received from other stock-related transactions. Includes only common stock transactions (excludes preferred stock transactions). May be called contributed capital, capital in excess of par, capital surplus, or paid-in capital. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(30)(a)(1)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_AdditionalPaidInCapitalCommonStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition A valuation allowance for trade and other receivables due to an Entity within one year (or the normal operating cycle, whichever is longer) that are expected to be uncollectible. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 310 -SubTopic 10 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=84173941&loc=d3e5074-111524 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.4) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_AllowanceForDoubtfulAccountsReceivableCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Noncurrent portion of the carrying amount of a liability for an asset retirement obligation. An asset retirement obligation is a legal obligation associated with the disposal or retirement of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 410 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849 + Details Name: us-gaap_AssetRetirementObligationsNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Sum of the carrying amounts as of the balance sheet date of all assets that are recognized. Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(11)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 22 -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8736-108599 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(12)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_Assets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Excludes cash and cash equivalents within disposal group and discontinued operation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.1) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_Cash Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3044-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6676-107765 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.1) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CashAndCashEquivalentsAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.1) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CashEquivalentsAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Aggregate par or stated value of issued nonredeemable common stock (or common stock redeemable solely at the option of the issuer). This item includes treasury stock repurchased by the entity. Note: elements for number of nonredeemable common shares, par value and other disclosure concepts are in another section within stockholders' equity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(29)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CommonStockValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The current portion of money or property received from customers which is either to be returned upon satisfactory contract completion or applied to customer receivables in accordance with the terms of the contract or the understandings. + References Reference 1: http://fasb.org/us-gaap/role/ref/otherTransitionRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.20) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CustomerDepositsCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Decommission fund to pay for the costs of decontaminating and decommissioning of facilities through collection of revenues derived from utility assessments and government appropriations. Decommission fund investment for the process whereby a power station, at the end of its economic life, is taken permanently out of service and its site made available for other purposes. In the case of a nuclear station this comprises three different states of clearance. Immediately after the final closure, radioactive material such as nuclear fuel and operational waste is removed and the buildings surrounding the reactor shield are dismantled and finally the reactor itself is dismantled. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.12) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_DecommissioningFundInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Carrying amount as of the balance sheet date of capitalized fuel costs of a regulated entity that are expected to be recoverable through rate adjustments within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -SubTopic 340 -Section 25 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=77907324&loc=d3e43603-110378 + Details Name: us-gaap_DeferredFuelCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount, after allocation of valuation allowances and deferred tax liability, of deferred tax asset attributable to deductible differences and carryforwards, with jurisdictional netting. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=84230637&loc=d3e32537-109319 + Details Name: us-gaap_DeferredIncomeTaxAssetsNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition This item represents the carrying amount on the entity's balance sheet of its investment in common stock of an equity method investee. This is not an indicator of the fair value of the investment, rather it is the initial cost adjusted for the entity's share of earnings and losses of the investee, adjusted for any distributions (dividends) and other than temporary impairment (OTTI) losses recognized. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 323 -SubTopic 10 -Section 45 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=109237563&loc=d3e33749-111570 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 25 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8813-108599 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.12) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_EquityMethodInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Total obligations incurred as part of normal operations that are expected to be paid during the following twelve months or within one business cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.21) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LiabilitiesCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of obligation due after one year or beyond the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 201.5-02(25)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(23)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 201.5-02(26)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 201.5-02(24)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LiabilitiesNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount, after unamortized (discount) premium and debt issuance costs, of long-term debt, classified as current. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19,20) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LongTermDebtCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount after unamortized (discount) premium and debt issuance costs of long-term debt classified as noncurrent and excluding amounts to be repaid within one year or the normal operating cycle, if longer. Includes, but not limited to, notes payable, bonds payable, debentures, mortgage loans and commercial paper. Excludes capital lease obligations. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.22) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LongTermDebtNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The total amount of investments that are intended to be held for an extended period of time (longer than one operating cycle). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.12) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LongTermInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of loss contingency liability. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 450 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=82911808&loc=d3e14326-108349 + Details Name: us-gaap_LossContingencyAccrualAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of ownership interest in limited liability company (LLC), attributable to the parent entity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.3-04) -URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 272 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6373374&loc=d3e70434-108055 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 272 -SubTopic 10 -Section 50 -Paragraph 3 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6373374&loc=d3e70478-108055 + Details Name: us-gaap_MembersEquity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Total of all stockholders' equity (deficit) items, net of receivables from officers, directors, owners, and affiliates of the entity which is directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent (that is, noncontrolling interest, previously referred to as minority interest). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(24)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.31) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(22)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 + Details Name: us-gaap_MinorityInterest Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The amount for notes payable (written promise to pay), due to related parties. Used to reflect the current portion of the liabilities (due within one year or within the normal operating cycle if longer). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 850 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39549-107864 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(k)(1)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(a)(5)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_NotesPayableRelatedPartiesClassifiedCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The amount for notes payable (written promise to pay), payable to related parties, which are due after one year (or one business cycle). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 850 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=6457730&loc=d3e39549-107864 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(k)(1)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.23) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_NotesPayableRelatedPartiesNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The carrying amount as of the balance sheet of nuclear fuel held as property plant and equipment. This amount is net of amortization based on the energy produced over the life of the fuel. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.13(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_NuclearFuelNetOfAmortization Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of noncurrent assets classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.17) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_OtherAssetsNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of liabilities classified as other, due within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 5 -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6904-107765 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 6 -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6911-107765 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.20) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_OtherLiabilitiesCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of long-term investments classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03.1(f)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.12) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_OtherLongTermInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount due from parties in nontrade transactions, classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.8) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_OtherReceivables Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of liability, recognized in statement of financial position, for defined benefit pension and other postretirement plans, classified as current. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109237824&loc=d3e1703-114919 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(20)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 45 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109237824&loc=d3e1731-114919 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 + Details Name: us-gaap_PensionAndOtherPostretirementDefinedBenefitPlansCurrentLiabilities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of liability, recognized in statement of financial position, for defined benefit pension and other postretirement plans, classified as noncurrent. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109237824&loc=d3e1703-114919 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 45 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109237824&loc=d3e1731-114919 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(24)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_PensionAndOtherPostretirementDefinedBenefitPlansLiabilitiesNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of asset related to consideration paid in advance for costs that provide economic benefits in future periods, and amount of other assets that are expected to be realized or consumed within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(7)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6676-107765 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(8)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_PrepaidExpenseAndOtherAssetsCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Period end book value of accumulated depreciation on property, plant and equipment (PPE) that is owned by the regulated operations of the public utility. + References No definition available. + Details Name: us-gaap_PublicUtilitiesPropertyPlantAndEquipmentAccumulatedDepreciation Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Period end book value of other property, plant and equipment (PPE) owned (but not classified elsewhere) by the public utility. + References No definition available. + Details Name: us-gaap_PublicUtilitiesPropertyPlantAndEquipmentOtherPropertyPlantAndEquipment Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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v3.19.3

Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Tax	$ (5,343)	$ (8,517)	$ 14,547	$ (480)
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	6,760	4,126	13,086	12,919
Other Comprehensive Income (Loss), Securities, Available-for-sale, Tax	1,303	(825)	17,472	1,708
Entergy Louisiana [Member]
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax	$ (342)	$ (177)	$ (1,026)	$ (530)

X

- Definition Amount of tax expense (benefit), after reclassification adjustments, of appreciation (loss) in value of unsold available-for-sale securities. Excludes amounts related to other than temporary impairment (OTTI) loss. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 10A -Subparagraph (e) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669646-108580 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e640-108580 + Details Name: us-gaap_OtherComprehensiveIncomeLossAvailableForSaleSecuritiesTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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v3.19.3

Dispositions Dispositions	9 Months Ended
	Sep. 30, 2019
Business Acquisition [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	DISPOSITIONS (Entergy Corporation) Vermont Yankee As discussed in Note 14 to the financial statements in the Form 10-K, in January 2019, Entergy transferred 100% of the membership interests in Entergy Nuclear Vermont Yankee, LLC, the owner of the Vermont Yankee plant, to a subsidiary of NorthStar. Entergy Nuclear Vermont Yankee had an outstanding credit facility that was used to pay for dry fuel storage costs. This credit facility was guaranteed by Entergy Corporation. Vermont Yankee Asset Retirement Management, LLC, a subsidiary of Entergy, assumed the obligations under the credit facility. At the closing of the transaction, NorthStar caused Entergy Nuclear Vermont Yankee, renamed NorthStar Vermont Yankee, to issue a $139 million promissory note to Vermont Yankee Asset Retirement Management. The amount of the note included the balance outstanding on the credit facility, as well as borrowing fees and costs incurred by Entergy in connection with the credit facility. Upon closing of the transaction in January 2019, the Vermont Yankee decommissioning trust, along with the decommissioning obligation for the plant, was transferred to NorthStar. The Vermont Yankee spent fuel disposal contract was assigned to NorthStar as part of the transaction. The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. The transaction also resulted in other charges of $5.4 million ($4.2 million net-of-tax) in the first quarter 2019. Pilgrim In July 2018, Entergy entered into a purchase and sale agreement with Holtec International to sell to a Holtec subsidiary 100% of the equity interests in Entergy Nuclear Generation Company, the owner of the Pilgrim plant. In August 2019 the NRC approved the sale of the plant to Holtec. The transaction closed in August 2019 for a purchase price of $1,000 (subject to adjustments for net liabilities and other amounts). The sale included the transfer of the Pilgrim nuclear decommissioning trust and obligation for spent fuel management and plant decommissioning. The transaction resulted in a loss of $191 million ($156 million net-of-tax) in the third quarter 2019. The disposition-date fair value of the nuclear decommissioning trust fund was approximately $1,030 million and the disposition-date fair value of the asset retirement obligation was $837 million. The transaction also included property, plant, and equipment with a net book value of zero, materials and supplies, and prepaid assets.

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v3.19.3

Variable Interest Entities	9 Months Ended
	Sep. 30, 2019
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
Entergy Arkansas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
Entergy Louisiana [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
Entergy Mississippi [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
Entergy New Orleans [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
Entergy Texas [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.
System Energy [Member]
Variable Interest Entities	VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities.  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities and commercial paper borrowings and long-term debt. System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest representing approximately 11.5% of the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 10 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in the three months ended September 30, 2019 and in the three months ended September 30, 2018. System Energy made payments under this arrangement, including interest, of $17.2 million in the nine months ended September 30, 2019 and in the nine months ended September 30, 2018.

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v3.19.3

Retirement And Other Postretirement Benefits	9 Months Ended
	Sep. 30, 2019
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Arkansas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Louisiana [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Mississippi [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy New Orleans [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
Entergy Texas [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654
System Energy [Member]
Retirement And Other Postretirement Benefits	RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Components of Qualified Net Pension Cost Entergy’s qualified pension cost, including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $33,553   $38,752 Interest cost on projected benefit obligation 73,261   66,854 Expected return on assets (103,751 )   (110,535 ) Amortization of prior service cost —   99 Amortization of net loss 60,395   68,526 Settlement charges 16,291   — Net pension costs $79,749   $63,696 Entergy’s qualified pension cost, including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $100,766   $116,256 Interest cost on projected benefit obligation 221,114   200,562 Expected return on assets (311,494 )   (331,605 ) Amortization of prior service cost —   297 Amortization of net loss 177,233   205,578 Settlement charges 17,591   — Net pension costs $205,210   $191,088 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $5,260   $7,284   $1,629   $568   $1,350   $1,549 Interest cost on projected benefit obligation   14,175   15,882   4,068   1,873   3,613   3,364 Expected return on assets   (20,177 )   (22,651 )   (5,969 )   (2,696 )   (5,862 )   (4,678 ) Amortization of net loss   11,840   11,643   3,104   1,529   2,334   2,850 Net pension cost   $11,098   $12,158   $2,832   $1,274   $1,435   $3,085 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $6,189   $8,446   $1,822   $673   $1,589   $1,776 Interest cost on projected benefit obligation   13,004   14,940   3,769   1,813   3,348   3,227 Expected return on assets   (21,851 )   (24,809 )   (6,502 )   (2,993 )   (6,523 )   (4,991 ) Amortization of net loss   13,412   14,450   3,610   1,954   2,626   3,715 Net pension cost   $10,754   $13,027   $2,699   $1,447   $1,040   $3,727 The Registrant Subsidiaries’ qualified pension cost, including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $15,782   $21,852   $4,887   $1,706   $4,050   $4,649 Interest cost on projected benefit obligation   42,525   47,646   12,204   5,621   10,837   10,091 Expected return on assets   (60,529 )   (67,955 )   (17,905 )   (8,089 )   (17,586 )   (14,032 ) Amortization of net loss   35,522   34,929   9,313   4,588   7,002   8,550 Net pension cost   $33,300   $36,472   $8,499   $3,826   $4,303   $9,258 2018   Entergy Arkansas   Entergy Louisiana   Entergy  Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $18,567   $25,338   $5,466   $2,019   $4,767   $5,328 Interest cost on projected benefit obligation   39,012   44,820   11,307   5,439   10,044   9,681 Expected return on assets   (65,553 )   (74,427 )   (19,506 )   (8,979 )   (19,569 )   (14,973 ) Amortization of net loss   40,236   43,350   10,830   5,862   7,878   11,145 Net pension cost   $32,262   $39,081   $8,097   $4,341   $3,120   $11,181 Non-Qualified Net Pension Cost Entergy recognized $4.6 million and $4.2 million in pension cost for its non-qualified pension plans in the third quarters of 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans in the third quarters of 2019 and 2018 were settlement charges of $955 thousand and $212 thousand, respectively, related to the payment of lump sum benefits out of the plan. Entergy recognized $16.3 million and $19.7 million in pension cost for its non-qualified pension plans for the nine months ended September 30, 2019 and 2018, respectively. Reflected in the pension cost for non-qualified pension plans for the nine months ended September 30, 2019 and 2018 were settlement charges of $4.6 million and $7 million, respectively, related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the third quarters of 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $67   $38   $69   $5   $119 2018 $114   $42   $73   $20   $122 Reflected in Entergy Arkansas’s non-qualified pension costs in the third quarter of 2018 were settlement charges of $7 thousand related to the payment of lump sum benefits out of the plan. The Registrant Subsidiaries recognized the following pension cost for their employees for their non-qualified pension plans for the nine months ended September 30, 2019 and 2018:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) 2019 $211   $122   $257   $16   $365 2018 $369   $138   $230   $62   $529 Reflected in Entergy Mississippi’s non-qualified pension costs for the nine months ended September 30, 2019 were settlement charges of $40 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Arkansas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $30 thousand related to the payment of lump sum benefits out of the plan. Reflected in Entergy Texas’s non-qualified pension costs for the nine months ended September 30, 2018 were settlement charges of $139 thousand related to the payment of lump sum benefits out of the plan. Components of Net Other Postretirement Benefit Cost (Income) Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the third quarters of 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $4,675   $6,782 Interest cost on accumulated postretirement benefit obligation (APBO) 11,975   12,681 Expected return on assets (9,562 )   (10,373 ) Amortization of prior service credit (8,844 )   (9,251 ) Amortization of net loss 358   3,432 Net other postretirement benefit cost (income) ($1,398 )   $3,271 Entergy’s other postretirement benefit cost (income), including amounts capitalized, for the nine months ended September 30, 2019 and 2018, included the following components:   2019   2018   (In Thousands) Service cost - benefits earned during the period $14,025   $20,346 Interest cost on accumulated postretirement benefit obligation (APBO) 35,925   38,043 Expected return on assets (28,686 )   (31,119 ) Amortization of prior service credit (26,532 )   (27,753 ) Amortization of net loss 1,074   10,296 Net other postretirement benefit cost (income) ($4,194 )   $9,813 The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for third quarters of 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $591   $1,160   $262   $92   $236   $243 Interest cost on APBO   1,807   2,666   670   395   854   476 Expected return on assets   (3,991 )   —   (1,199 )   (1,237 )   (2,276 )   (697 ) Amortization of prior service credit   (1,238 )   (1,837 )   (439 )   (171 )   (561 )   (363 ) Amortization of net (gain) loss   144   (174 )   181   58   121   89 Net other postretirement benefit cost (income)   ($2,687 )   $1,815   ($525 )   ($863 )   ($1,626 )   ($252 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $793   $1,556   $321   $129   $330   $306 Interest cost on APBO   1,997   2,789   683   417   939   500 Expected return on assets   (4,342 )   —   (1,303 )   (1,313 )   (2,446 )   (783 ) Amortization of prior service credit   (1,278 )   (1,934 )   (456 )   (186 )   (579 )   (378 ) Amortization of net loss   289   388   377   34   206   233 Net other postretirement benefit cost (income)   ($2,541 )   $2,799   ($378 )   ($919 )   ($1,550 )   ($122 ) The Registrant Subsidiaries’ other postretirement benefit cost (income), including amounts capitalized, for their employees for the nine months ended September 30, 2019 and 2018, included the following components: 2019   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $1,773   $3,480   $786   $276   $708   $729 Interest cost on APBO   5,421   7,998   2,010   1,185   2,562   1,428 Expected return on assets   (11,973 )   —   (3,597 )   (3,711 )   (6,828 )   (2,091 ) Amortization of prior service credit   (3,714 )   (5,511 )   (1,317 )   (513 )   (1,683 )   (1,089 ) Amortization of net (gain) loss   432   (522 )   543   174   363   267 Net other postretirement benefit cost (income)   ($8,061 )   $5,445   ($1,575 )   ($2,589 )   ($4,878 )   ($756 ) 2018   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy     (In Thousands) Service cost - benefits earned during the period   $2,379   $4,668   $963   $387   $990   $918 Interest cost on APBO   5,991   8,367   2,049   1,251   2,817   1,500 Expected return on assets   (13,026 )   —   (3,909 )   (3,939 )   (7,338 )   (2,349 ) Amortization of prior service credit   (3,834 )   (5,802 )   (1,368 )   (558 )   (1,737 )   (1,134 ) Amortization of net loss   867   1,164   1,131   102   618   699 Net other postretirement benefit cost (income)   ($7,623 )   $8,397   ($1,134 )   ($2,757 )   ($4,650 )   ($366 ) Reclassification out of Accumulated Other Comprehensive Income (Loss) Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the third quarters of 2019 and 2018: 2019   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   $—   $5,375   ($50 )   $5,325 Amortization of net gain (loss)   (20,686 )   308   (541 )   (20,919 ) Settlement loss   (16,257 )   —   (373 )   (16,630 )     ($36,943 )   $5,683   ($964 )   ($32,224 ) Entergy Louisiana                 Amortization of prior service credit   $—   $1,837   $—   $1,837 Amortization of net gain (loss)   (699 )   174   (1 )   (526 )     ($699 )   $2,011   ($1 )   $1,311 2018 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit ($99 ) $5,595 ($71 ) $5,425 Amortization of net loss (21,958 ) (1,932 ) (850 ) (24,740 ) Settlement loss — — (76 ) (76 ) ($22,057 ) $3,663 ($997 ) ($19,391 ) Entergy Louisiana Amortization of prior service credit $— $1,934 $— $1,934 Amortization of net loss (867 ) (388 ) (2 ) (1,257 ) ($867 ) $1,546 ($2 ) $677 Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the nine months ended September 30, 2019 and 2018: 2019 Qualified Pension Costs Other Postretirement Costs Non-Qualified Pension Costs Total (In Thousands) Entergy Amortization of prior service (cost) credit $— $16,125 ($148 ) $15,977 Amortization of net gain (loss) (58,156 ) 923 (1,655 ) (58,888 ) Settlement loss (17,557 ) — (1,128 ) (18,685 ) ($75,713 ) $17,048 ($2,931 ) ($61,596 ) Entergy Louisiana Amortization of prior service credit $— $5,511 $— $5,511 Amortization of net gain (loss) (2,096 ) 522 (4 ) (1,578 ) ($2,096 ) $6,033 ($4 ) $3,933 2018   Qualified Pension Costs   Other Postretirement Costs   Non-Qualified Pension Costs   Total     (In Thousands)     Entergy                 Amortization of prior service (cost) credit   ($297 )   $16,786   ($211 )   $16,278 Amortization of net loss   (65,870 )   (5,801 )   (2,832 )   (74,503 ) Settlement loss   —   —   (2,098 )   (2,098 )     ($66,167 )   $10,985   ($5,141 )   ($60,323 ) Entergy Louisiana                 Amortization of prior service credit   $—   $5,802   $—   $5,802 Amortization of net loss   (2,601 )   (1,164 )   (5 )   (3,770 )     ($2,601 )   $4,638   ($5 )   $2,032 Employer Contributions Based on current assumptions, Entergy expects to contribute $176.9 million to its qualified pension plans in 2019.  As of September 30, 2019, Entergy had contributed $123.1 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their employees in 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   System Energy   (In Thousands) Expected 2019 pension contributions $27,112   $26,451   $7,701   $1,800   $1,645   $8,285 Pension contributions made through September 2019 $18,222   $18,272   $5,186   $1,237   $1,192   $5,631 Remaining estimated pension contributions to be made in 2019 $8,890   $8,179   $2,515   $563   $453   $2,654

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v3.19.3

Rate And Regulatory Matters	9 Months Ended
	Sep. 30, 2019
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
Entergy Arkansas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
Entergy Louisiana [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
Entergy Mississippi [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
Entergy New Orleans [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
Entergy Texas [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.
System Energy [Member]
Rate and Regulatory Matters	RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Regulatory Assets and Regulatory Liabilities See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion. Regulatory activity regarding the Tax Cuts and Jobs Act System Energy In a filing made with the FERC in March 2018, Entergy proposed revisions to the Unit Power Sales Agreement, among other agreements, to reflect the effects of the Tax Act. In the filing System Energy proposed to return all of its unprotected excess accumulated deferred income taxes to its customers by the end of 2018. In May 2018 the FERC accepted System Energy’s proposed tax revisions with an effective date of June 1, 2018, subject to refund and the outcome of settlement and hearing procedures.  Settlement discussions were terminated in April 2019, and the hearing is scheduled for March 2020. The retail regulators of the Utility operating companies that are parties to the Unit Power Sales Agreement are challenging the treatment and amount of excess tax liabilities associated with uncertain tax positions related to nuclear decommissioning. Fuel and purchased power cost recovery Entergy Arkansas Production Cost Allocation Rider In May 2019, Entergy Arkansas filed its annual redetermination pursuant to the production cost allocation rider, which reflected a credit to customers for the recovery of the true-up adjustment resulting from the 2018 over-recovered retail balance of $0.1 million and the recovery of a $4.2 million payment to Entergy Arkansas as a result of the FERC’s May 2018 decision in the 2005 bandwidth proceeding, in which the FERC directed a compliance filing to be made that consisted of the comprehensive recalculation of the bandwidth formula rate with true-up payments and receipts based on test period data for June 1, 2005 through December 31, 2005. The rates for the 2019 production cost allocation rider update are effective July 2019 through June 2020. Energy Cost Recovery Rider In March 2019, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected a decrease from $0.01882 per kWh to $0.01462 per kWh and became effective with the first billing cycle in April 2019. In March 2019 the Arkansas Attorney General filed a response to Entergy Arkansas’s annual adjustment and included with its filing a motion for investigation of alleged overcharges to customers in connection with the FERC’s October 2018 order in the opportunity sales proceeding. Entergy Arkansas filed its response to the Attorney General’s motion in April 2019 in which Entergy Arkansas stated its intent to initiate a proceeding to address recovery issues related to the October 2018 FERC order. In May 2019, Entergy Arkansas initiated the opportunity sales recovery proceeding, discussed below, and requested that the APSC establish that proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC October 2018 order and related FERC orders in the opportunity sales proceeding. In June 2019 the APSC granted Entergy Arkansas’s request and also denied the Attorney General’s motion in the energy cost recovery proceeding seeking an investigation into Entergy Arkansas’s annual energy cost recovery rider adjustment and referred the evaluation of such matters to the opportunity sales recovery proceeding. Entergy Louisiana In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel adjustment clause for the period from 2010 through 2013. In January 2019 the LPSC staff issued its audit report recommending that Entergy Louisiana refund approximately $7.3 million, plus interest, to customers based upon the imputation of a claim of vendor fault in servicing its nuclear plant. Entergy Louisiana recorded a provision in the first quarter 2019 for the potential outcome of the audit. In August 2019, Entergy Louisiana filed direct testimony challenging the basis for the LPSC staff’s recommended disallowance and providing an alternative calculation of replacement power costs should it be determined that a disallowance is appropriate. Entergy Louisiana’s calculation would require a refund to customers of approximately $4.2 million, plus interest, as compared to the LPSC staff’s recommendation of $7.3 million, plus interest. Responsive testimony was filed by the LPSC staff and intervenors in September 2019; all parties either agreed with or did not oppose Entergy Louisiana’s alternative calculation of replacement power costs. In September 2019 the procedural schedule was suspended to facilitate settlement negotiations. Entergy Mississippi Mississippi Attorney General Complaint As discussed in the Form 10-K, the Mississippi Attorney General filed a complaint in state court in December 2008 against Entergy Corporation, Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. Entergy believes the complaint is unfounded. In December 2008 the Attorney General’s lawsuit was removed to U.S. District Court in Jackson, Mississippi. Pre-trial and settlement conferences were held in October 2018. In October 2018 the District Court rescheduled the trial to April 2019. In April 2019 the District Court remanded the Attorney General’s lawsuit to the Hinds County Chancery Court in Jackson, Mississippi. A hearing on procedural and dispositive motions was held in August 2019. Following the parties’ oral arguments, the Attorney General filed a post hearing brief, to which Entergy Mississippi filed a response. The motions remain pending before the chancellor of the Hinds County Chancery Court. Entergy Texas In September 2019, Entergy Texas filed an application to reconcile its fuel and purchased power costs for the period from April 2016 through March 2019. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in Texas jurisdictional eligible fuel and purchased power expenses, net of certain revenues credited to such expenses and other adjustments. Entergy Texas estimated an under-recovery balance of approximately $25.8 million, including interest, which Entergy Texas requested authority to carry over as the beginning balance for the subsequent reconciliation period beginning April 2019. The proceeding is currently pending. Retail Rate Proceedings See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies.  The following are updates to that discussion. Filings with the APSC (Entergy Arkansas) Retail Rates 2019 Formula Rate Plan Filing In July 2019, Entergy Arkansas filed with the APSC its 2019 formula rate plan filing to set its formula rate for the 2020 calendar year. The filing contained an evaluation of Entergy Arkansas’s earnings for the projected year 2020 and a netting adjustment for the historical year 2018.  The total proposed formula rate plan rider revenue change designed to produce a target rate of return on common equity of 9.75% is $15.3 million, which is based upon a deficiency of approximately $61.9 million for the 2020 projected year, netted with a credit of approximately $46.6 million in the 2018 historical year netting adjustment. During 2018, Entergy Arkansas experienced higher-than expected sales volume, and actual costs were lower than forecasted.  These changes, coupled with a reduced income tax rate resulting from the Tax Cuts and Jobs Act, resulted in the credit for the historical year netting adjustment. In the fourth quarter 2018, Entergy Arkansas recorded a provision of $35.1 million that reflected the estimate of the historical year netting adjustment that was expected to be included in the 2019 filing. In 2019, Entergy Arkansas recorded additional provisions totaling $11.5 million to reflect the updated estimate of the historical year netting adjustment included in the 2019 filing.  In October 2019 other parties in the proceeding filed their errors and objections requesting certain adjustments to Entergy Arkansas’s filing, which, if granted, would reduce or eliminate Entergy Arkansas’s proposed revenue change. Entergy Arkansas filed its response addressing the requested adjustments in October 2019. In its response, Entergy Arkansas accepted certain of the adjustments recommended by the General Staff of the APSC that would reduce the proposed formula rate plan rider revenue change to $14 million. Entergy Arkansas disputed the remaining adjustments proposed by the parties. In October 2019, Entergy Arkansas filed a unanimous settlement agreement with the other parties in the proceeding seeking APSC approval of a revised total formula rate plan rider revenue change of $10.1 million. The proposed new formula rates would go into effect in January 2020. In its July 2019 formula rate plan filing, Entergy Arkansas proposed to recover an $11.2 million regulatory asset, amortized over five years, associated with specific costs related to the potential construction of scrubbers at the White Bluff plant. While Entergy Arkansas does not concede that the regulatory asset does not have merit, for purposes of reaching a settlement amount on the total formula rate plan rider change Entergy Arkansas agreed not to include the amounts associated with the White Bluff scrubber regulatory asset in the 2019 formula rate plan filing or future filings. Entergy Arkansas will record a write off of the $11.2 million White Bluff scrubber regulatory asset. Filings with the LPSC (Entergy Louisiana) Retail Rates - Electric 2017 Formula Rate Plan Filing Commercial operation at St. Charles Power Station commenced in May 2019. In May 2019, Entergy Louisiana filed an update to its 2017 formula rate plan evaluation report to include the estimated first-year revenue requirement of $109.5 million associated with the St. Charles Power Station. The resulting interim adjustment to rates became effective with the first billing cycle of June 2019. 2018 Formula Rate Plan Filing In May 2019, Entergy Louisiana filed its formula rate plan evaluation report for its 2018 calendar year operations. The 2018 test year evaluation report produced an earned return on common equity of 10.61% leading to a base rider formula rate plan revenue decrease of $8.9 million. While base rider formula rate plan revenue decreased as a result of this filing, overall formula rate plan revenues increased by approximately $118.7 million. This outcome is primarily driven by a reduction to the credits previously flowed through the tax reform adjustment mechanism and an increase in the transmission recovery mechanism, partially offset by reductions in the additional capacity mechanism revenue requirements and extraordinary cost items. The filing is subject to review by the LPSC. Resulting rates were implemented in September 2019, subject to refund due to contested issues. Entergy Louisiana also included in its filing a presentation of an initial proposal to combine the legacy Entergy Louisiana and legacy Entergy Gulf States Louisiana residential rates, which combination, if approved, would be accomplished on a revenue-neutral basis intended not to affect the rates of other customer classes. Entergy Louisiana contemplates that any combination of residential rates resulting from this request would be implemented with the results of the 2019 test year formula rate plan filing. Several parties intervened in the proceeding and the LPSC staff filed its report of objections/reservations in accordance with the applicable provisions of the formula rate plan. In its report the LPSC staff re-urged reservations with respect to the outstanding issues from the 2017 test year formula rate plan filing and disputed the inclusion of certain affiliate costs for test years 2017 and 2018. The LPSC staff objected to Entergy Louisiana’s proposal to combine residential rates but proposed the setting of a status conference to establish a procedural schedule to more fully address the issue. The LPSC staff also reserved its right to object to the treatment of the sale of Willow Glen reflected in the evaluation report and to the August 2019 compliance update, which was made primarily to update the capital additions reflected in the formula rate plan’s transmission recovery mechanism, based on limited time to review it. Additionally, since the completion of certain transmission projects, the LPSC staff has issued supplemental data requests addressing the prudence of Entergy Louisiana’s expenditures in connection with those projects. Entergy Louisiana is in the process of responding to those requests. Investigation of Costs Billed by Entergy Services In November 2018 the LPSC issued a notice of proceeding initiating an investigation into costs incurred by Entergy Services that are included in the retail rates of Entergy Louisiana. As noted in the notice of proceeding, the LPSC observed an increase in capital construction-related costs that have been incurred by Entergy Services. Discovery is ongoing and has included efforts to seek highly detailed information on a broad range of matters unrelated to the scope of the audit. Retail Rates - Gas 2018 Rate Stabilization Plan Filing As discussed in the Form 10-K, in January 2019, Entergy Louisiana filed with the LPSC its gas rate stabilization plan for the test year ended September 30, 2018. Entergy Louisiana made a compliance filing in April 2019 and rates were implemented during the first billing cycle of May 2019, subject to refund and final LPSC review. Gas Rate Stabilization Plan Extension Request In August 2019, Entergy Louisiana submitted an application to the LPSC seeking extension of the gas rate stabilization plan for the 2019-2021 test years. The LPSC has established a procedural schedule to address this request with a hearing scheduled in May 2020. Filings with the MPSC (Entergy Mississippi) Formula Rate Plan In March 2019, Entergy Mississippi submitted its formula rate plan 2019 test year filing and 2018 look-back filing showing Entergy Mississippi’s earned return for the historical 2018 calendar year to be above the formula rate plan bandwidth and projected earned return for the 2019 calendar year to be below the formula rate plan bandwidth. The 2019 test year filing shows a $36.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.94% return on rate base, within the formula rate plan bandwidth. The 2018 look-back filing compares actual 2018 results to the approved benchmark return on rate base and shows a $10.1 million interim decrease in formula rate plan revenues is necessary. In the fourth quarter 2018, Entergy Mississippi recorded a provision of $9.3 million that reflected the estimate of the difference between the 2018 expected earned rate of return on rate base and an established performance-adjusted benchmark rate of return under the formula rate plan performance-adjusted bandwidth mechanism. In the first quarter 2019, Entergy Mississippi recorded an increase of $0.8 million in the provision to reflect the amount shown in the look-back filing. In June 2019, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed that the 2019 test year filing showed that a $32.8 million rate increase is necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.93% return on rate base, within the formula rate plan bandwidth. Additionally, pursuant to the joint stipulation, Entergy Mississippi’s 2018 look-back filing reflected an earned return on rate base of 7.81% in calendar year 2018 which is above the look-back benchmark return on rate base of 7.13%, resulting in an $11 million decrease in formula rate plan revenues on an interim basis through June 2020. In the second quarter 2019, Entergy Mississippi recorded an additional $0.9 million increase in the provision to reflect the $11 million shown in the look-back filing. In June 2019 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2019. Filings with the City Council (Entergy New Orleans) Retail Rates See the Form 10-K for discussion of the electric and gas base rate case filed by Entergy New Orleans in September 2018. The evidentiary hearing in this proceeding was held in June 2019. The record and post-hearing briefs were submitted in July 2019. In August 2019, Entergy New Orleans sent a letter to the City Council proposing a framework for settlement of the rate case.  That framework includes, among other things: (1) a total reduction in revenues of approximately $30 million ($27 million electric, $3 million gas); (2) a reduced return on common equity lower than 10.5%, but still commensurate with Entergy New Orleans’s level of risk, paired with three-year electric and gas formula rate plans with forward-looking features; (3) a demand-side management program intended to achieve greater penetration of the City Council’s Energy Smart programs and make progress towards the City Council’s energy efficiency goals. In October 2019 the City Council’s Utility Committee approved a resolution for consideration by the full City Council that included a 9.35% return on common equity, a total reduction in revenues of approximately $39 million ($36 million electric; $3 million gas), and an equity ratio of the lesser of 50% or Entergy New Orleans’s actual equity ratio. Also in October 2019, Entergy New Orleans sent another letter to the City Council identifying certain issues with the proposed resolution and inviting the City Council to resume negotiations in an effort to address these issues. The City Council may consider the resolution at its November 7, 2019 meeting. Filings with the PUCT (Entergy Texas) Base Rate Case In January 2019, Entergy Texas filed for recovery of rate case expenses totaling $7.2 million. The amounts requested primarily include internal and external expenses related to litigating the 2018 base rate case. Parties filed testimony in April 2019 recommending a disallowance ranging from $3.2 million to $4.2 million of the $7.2 million requested. In May 2019, Entergy Texas filed rebuttal testimony responding to the parties’ positions. In September 2019 an order was issued abating the procedural schedule and scheduled hearing to allow the finalization of a settlement in principle reached among the parties. The settlement provides for a black box disallowance of $1.4 million. In the third quarter 2019, Entergy Texas recorded a provision for the 2018 base rate case expenses based on the settlement in principle. In October 2019 the settlement was filed for review by the PUCT. Other Filings In March 2019, Entergy Texas filed with the PUCT a request to set a new distribution cost recovery factor (DCRF) rider. The proposed new DCRF rider is designed to collect approximately $3.2 million annually from Entergy Texas’s retail customers based on its capital invested in distribution between January 1, 2018 and December 31, 2018. In September 2019 the PUCT issued an order approving rates, which had been effective on an interim basis since June 2019, at the level proposed in Entergy Texas’s application. In December 2018, Entergy Texas filed with the PUCT a request to set a new transmission cost recovery factor (TCRF) rider. The proposed new TCRF rider is designed to collect approximately $2.7 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and September 30, 2018. In April 2019 parties filed testimony proposing a load growth adjustment, which would have fully offset Entergy Texas’s proposed TCRF revenue requirement. In July 2019 the PUCT granted Entergy Texas’s application as filed to begin recovery of the requested $2.7 million annual revenue requirement, rejecting opposing parties’ proposed adjustment; however, the PUCT found that the question of prudence of the actual investment costs should be determined in Entergy Texas’s next rate case similar to the procedure used for the costs recovered through the DCRF rider. In October 2019 the PUCT issued an order on a motion for rehearing, clarifying and affirming its prior order granting Entergy Texas’s application as filed. Also in October 2019 a second motion for rehearing was filed, and Entergy Texas filed a response in opposition to the motion. The second motion for rehearing is pending before the PUCT. In August 2019, Entergy Texas filed with the PUCT a request to amend its TCRF rider. The proposed new TCRF rider is designed to collect approximately $19.4 million annually from Entergy Texas’s retail customers based on its capital invested in transmission between January 1, 2018 and June 30, 2019, which is $16.7 million in incremental annual revenue above the $2.7 million approved in the prior pending TCRF proceeding. The proceeding is currently pending. System Agreement Cost Equalization Proceedings As discussed in the Form 10-K, the hearing on the bandwidth calculation for the seven months June 1, 2005 through December 31, 2005 occurred in July 2016. The presiding judge issued an initial decision in November 2016. In the initial decision, the presiding judge agreed with the Utility operating companies’ position that: (1) interest on the bandwidth payments for the 2005 test period should be accrued from June 1, 2006 until the date that the bandwidth payments for that calculation are paid, which is consistent with how the Utility operating companies performed the calculation; and (2) a portion of Entergy Louisiana’s 2001-vintage Louisiana state net operating loss accumulated deferred income tax that results from the Vidalia tax deduction should be excluded from the 2005 test period bandwidth calculation. Various participants filed briefs on exceptions and/or briefs opposing exceptions related to the initial decision, including the LPSC, the APSC, the FERC trial staff, and Entergy Services. In May 2018 the FERC issued an order affirming the initial decision and ordered a comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and a recalculation of the 2006 and 2007 test years as a result of limited revisions. Entergy filed the comprehensive recalculation of the bandwidth payments/receipts for the seven months June 1, 2005 through December 31, 2005 and the 2006 and 2007 test years in July 2018. The filing shows the additional following payments and receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas ($4) Entergy Louisiana ($23) Entergy Mississippi $16 Entergy New Orleans $5 Entergy Texas $6 These payments were made in July 2018. In January 2019 the FERC denied the LPSC’s request for rehearing of the May 2018 order. In May 2019 the FERC accepted the July 2018 compliance filing, and the LPSC sought rehearing of that decision in June 2019. Rough Production Cost Equalization 2010 Rate Filing Based on Calendar Year 2009 Production Costs In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System Agreement proceeding, and supplemented the filing in September 2010.  Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests.  In July 2010 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund.  After an abeyance of the proceeding schedule, a hearing was held in March 2014 and in December 2015 the FERC issued an order. Among other things, the December 2015 order directed Entergy to submit a compliance filing. In January 2016 the LPSC, the APSC, and Entergy filed requests for rehearing of the FERC’s December 2015 order. In February 2016, Entergy submitted the compliance filing ordered in the December 2015 order.  The result of the true-up payments and receipts for the recalculation of production costs resulted in the following payments/receipts among the Utility operating companies:   Payments (Receipts)   (In Millions) Entergy Arkansas $2 Entergy Louisiana $6 Entergy Mississippi ($4) Entergy New Orleans ($1) Entergy Texas ($3)   In September 2016 the FERC accepted the February 2016 compliance filing subject to a further compliance filing made in November 2016. The further compliance filing was required as a result of an order issued in September 2016 ruling on the January 2016 rehearing requests filed by the LPSC, the APSC, and Entergy. In the order addressing the rehearing requests, the FERC granted the LPSC’s rehearing request and directed that interest be calculated on the payment/receipt amounts. The FERC also granted the APSC’s and Entergy’s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation. In November 2016, Entergy submitted its compliance filing in response to the FERC’s order on rehearing. The compliance filing included a revised calculation of the bandwidth true-up payments and receipts based on 2009 test year data and interest calculations. The LPSC protested the interest calculations. In November 2017 the FERC issued an order rejecting the November 2016 compliance filing. The FERC determined that the payments detailed in the November 2016 compliance filing did not include adequate interest for the payments from Entergy Arkansas to Entergy Louisiana because it did not include interest on the principal portion of the payment that was made in February 2016. In December 2017, Entergy recalculated the interest pursuant to the November 2017 order. As a result of the recalculations, Entergy Arkansas owed very minor payments to Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. In June 2019 the FERC issued an order denying the LPSC’s rehearing request of FERC’s September 2016 order. The LPSC rehearing request asked the FERC to reverse its decision that both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes should be removed from the bandwidth calculation. Entergy Arkansas Opportunity Sales Proceeding As discussed in the Form 10-K, in December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order in the opportunity sales proceeding. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. The December 2018 compliance filing is pending FERC action. In February 2019 the LPSC filed a new complaint relating to two issues that were raised in the opportunity sales proceeding, but that, in its October 2018 order, the FERC held were outside the scope of the proceeding. In March 2019, Entergy Services filed an answer and motion to dismiss the new complaint. In May 2019, Entergy Arkansas filed an application and supporting testimony with the APSC requesting approval of a special rider tariff to recover the costs of these payments from its retail customers over a 24-month period.  The application requested that the APSC approve the rider to take effect within 30 days or, if suspended by the APSC as allowed by commission rule, approve the rider to take effect in the first billing cycle of the first month occurring 30 days after issuance of the APSC’s order approving the rider. In June 2019 the APSC suspended Entergy Arkansas’s tariff and granted Entergy Arkansas’s motion asking the APSC to establish the proceeding as the single designated proceeding in which interested parties may assert claims related to the appropriate retail rate treatment of the FERC’s October 2018 order and related FERC orders in the opportunity sales proceeding. Complaints Against System Energy Return on Equity and Capital Structure Complaints See the Form 10-K for a discussion of the return on equity complaints filed by the APSC and the MPSC and by the LPSC against System Energy. The LPSC’s complaint also includes a challenge to System Energy’s capital structure. In August 2018 the FERC issued an order dismissing the LPSC’s request to investigate System Energy’s capital structure and setting for hearing the return on equity complaint, with a refund effective date of April 27, 2018. The portion of the LPSC’s complaint dealing with return on equity was subsequently consolidated with the APSC and MPSC complaint for hearing. The parties are required to address an order (issued in a separate proceeding involving New England transmission owners) that proposed modifying the FERC’s standard methodology for determining return on equity. In September 2018, System Energy filed a request for rehearing and the LPSC filed a request for rehearing or reconsideration of the FERC’s August 2018 order. The LPSC’s request referenced an amended complaint that it filed on the same day raising the same capital structure claim the FERC had earlier dismissed. The FERC initiated a new proceeding for the amended capital structure complaint, and System Energy submitted a response in October 2018. In January 2019 the FERC set the amended capital structure complaint for settlement and hearing proceedings. Settlement procedures in the capital structure proceeding commenced in February 2019. As noted below, in June 2019 settlement discussions were terminated and the amended capital structure complaint was consolidated with the ongoing return on equity proceeding. In January 2019 the LPSC and the APSC and MPSC filed direct testimony in the return on equity proceeding. For the refund period January 23, 2017 through April 23, 2018, the LPSC argues for an authorized return on equity for System Energy of 7.81% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.24%. For the refund period April 27, 2018 through July 27, 2019, and for application on a prospective basis, the LPSC argues for an authorized return on equity for System Energy of 7.97% and the APSC and MPSC argue for an authorized return on equity for System Energy of 8.41%. In March 2019, System Energy submitted answering testimony in the return on equity proceeding. For the first refund period, System Energy’s testimony argues for a return on equity of 10.10% (median) or 10.70% (midpoint). For the second refund period, System Energy’s testimony shows that the calculated returns on equity for the first period fall within the range of presumptively just and reasonable returns on equity, and thus the second complaint should be dismissed (and the first period return on equity used going forward). If the FERC nonetheless were to set a new return on equity for the second period (and going forward), System Energy argues the return on equity should be either 10.32% (median) or 10.69% (midpoint). In May 2019 the FERC trial staff filed its direct and answering testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.89% based on the application of FERC’s proposed methodology. The FERC trial staff’s direct and answering testimony noted that an authorized return on equity of 9.89% for the first refund period was within the range of presumptively just and reasonable returns on equity for the second refund period, as calculated using a study period ending January 31, 2019 for the second refund period. In June 2019, System Entergy filed testimony responding to the testimony filed by the FERC trial staff. Among other things, System Energy’s testimony rebutted arguments raised by the FERC trial staff and provided updated calculations for the second refund period based on the study period ending May 31, 2019. For that refund period, System Energy’s testimony shows that strict application of the return on equity methodology proposed by the FERC trial staff indicates that the second complaint would not be dismissed, and the new return on equity would be set at 9.65% (median) or 9.74% (midpoint). System Energy’s testimony argues that these results are insufficient in light of benchmarks such as state returns on equity and treasury bond yields, and instead proposes that the calculated returns on equity for the second period should be either 9.91% (median) or 10.3% (midpoint). System Energy’s testimony also argues that, under application of its proposed modified methodology, the 10.10% return on equity calculated for the first refund period would fall within the range of presumptively just and reasonable returns on equity for the second refund period. System Energy is recording a provision against revenue for the potential outcome of this proceeding. Also in June 2019, the FERC’s Chief ALJ issued an order terminating settlement discussions in the amended complaint addressing System Energy’s capital structure. The ALJ consolidated the amended complaint with the ongoing return on equity proceeding and set new procedural deadlines for the consolidated hearing, such that the hearing will commence in January 2020 and the initial decision will be due in June 2020. In August 2019 the LPSC and the APSC and MPSC filed rebuttal testimony in the return on equity proceeding and direct and answering testimony relating to System Energy’s capital structure. The LPSC reargues for an authorized return on equity for System Energy of 7.81% for the first refund period and 7.97% for the second refund period. The APSC and MPSC argue for an authorized return on equity for System Energy of 8.26% for the first refund period and 8.32% for the second refund period. With respect to capital structure, the LPSC proposes that the FERC establish a hypothetical capital structure for System Energy for ratemaking purposes. Specifically, the LPSC proposes that System Energy’s common equity ratio be set to Entergy Corporation’s equity ratio of 37% equity and 63% debt. In the alternative, the LPSC argues that the equity ratio should be no higher than 49%, the composite equity ratio of System Energy and the other Entergy operating companies who purchase under the Unit Power Sales Agreement. The APSC and MPSC recommend that 35.98% be set as the common equity ratio for System Energy. As an alternative, the APSC and MPSC propose that System Energy’s common equity be set at 46.75% based on the median equity ratio of the proxy group for setting the return on equity. In September 2019 the FERC trial staff filed its rebuttal testimony in the return on equity proceeding. For the first refund period, the FERC trial staff calculates an authorized return on equity for System Energy of 9.40% based on the application of the FERC’s proposed methodology and an updated proxy group. For the second refund period, based on the study period ending May 31, 2019, the FERC trial staff rebuttal testimony argues for a return on equity of 9.63%. In September 2019 the FERC trial staff also filed direct and answering testimony relating to System Energy’s capital structure. The FERC trial staff argues that the average capital structure of the proxy group used to develop System Energy’s return on equity should be used to establish the capital structure. Using this approach, the FERC trial staff calculates the average capital structure for its proposed proxy group of 46.74% common equity, and 53.26% debt. In October 2019, System Energy filed answering testimony disputing the FERC trial staff’s, the LPSC’s, and the APSC’s and MPSC’s arguments for the use of a hypothetical capital structure and arguing that the use of System Energy’s actual capital structure is just and reasonable. Grand Gulf Sale-leaseback Renewal Complaint As discussed in the Form 10-K, in May 2018 the LPSC filed a complaint against System Energy and Entergy Services related to System Energy’s renewal of a sale-leaseback transaction originally entered into in December 1988 for an 11.5% undivided interest in Grand Gulf Unit 1. In February 2019 the presiding ALJ ruled that the hearing ordered by the FERC includes the issue of whether specific subcategories of accumulated deferred income tax should be included in, or excluded from, System Energy’s formula rate. In March 2019 the LPSC, MPSC, APSC, and City Council filed direct testimony. The LPSC testimony seeks refunds that include the renewal lease payments (approximately $17.2 million per year since July 2015), rate base reductions for accumulated deferred income taxes associated with uncertain tax positions (claimed to be approximately $334.5 million as of December 2018), and the cost of capital additions associated with the sale-leaseback interest (claimed to be approximately $274.8 million), as well as interest on those amounts. The direct testimony of the City Council and the APSC and MPSC address various issues raised by the LPSC. System Energy disputes that any refunds are owed for billings under the Unit Power Sales Agreement. A hearing has been scheduled for November 2019. In June 2019 System Energy filed answering testimony in the sale-leaseback complaint proceeding arguing that the FERC should reject all claims for refunds.  Among other things, System Energy argued that claims for refunds of the costs of lease renewal payments and capital additions should be rejected because those costs were recovered consistent with the Unit Power Sales Agreement formula rate, System Energy was not over or double recovering any costs, and customers will save approximately $850 million over initial and renewal terms of the leases.  System Energy argued that claims for refunds associated with liabilities arising from uncertain tax positions should be rejected because the liabilities do not provide cost-free capital, the repayment timing of the liabilities is uncertain, and the outcome of the underlying tax positions is uncertain.  System Energy’s testimony also challenged the refund calculations supplied by the other parties. In August 2019 the FERC trial staff filed direct and answering testimony seeking refunds for rate base reductions for liabilities associated with uncertain tax positions (claimed to be up to approximately $602 million plus interest). The FERC trial staff also argued that System Energy recovered $32 million more than it should have in depreciation expense for capital additions. In September 2019, System Energy filed cross-answering testimony disputing the FERC trial staff’s arguments for refunds, stating that the FERC trial staff’s position regarding depreciation rates for capital additions is not unreasonable and explaining that any change in depreciation expense is only one element of a Unit Power Sales Agreement rebilling calculation. Adjustments to depreciation expense in any rebilling under the Unit Power Sales Agreement formula rate will also involve changes to accumulated depreciation, accumulated deferred income taxes, and other formula elements as needed. In October 2019 the LPSC filed rebuttal testimony increasing the amount of refunds sought for liabilities associated with uncertain tax positions.  The LPSC now seeks approximately $512 million plus interest.  At the same time, the FERC trial staff filed rebuttal testimony conceding that it was no longer seeking up to $602 million related to the uncertain tax positions; instead, it is seeking approximately $511 million plus interest.  The LPSC also argued that adjustments to depreciation rates should affect rate base on a prospective basis only. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi As discussed in the Form 10-K, Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. As of May 31, 2019, Entergy Mississippi’s storm damage provision balance was less than $10 million. Accordingly, Entergy Mississippi resumed billing the monthly storm damage provision effective with July 2019 bills.

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v3.19.3

Income Taxes	9 Months Ended
	Sep. 30, 2019
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
Entergy Arkansas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
Entergy Louisiana [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
Entergy Mississippi [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
Entergy New Orleans [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
Entergy Texas [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.
System Energy [Member]
Income Taxes	INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion. Tax Cuts and Jobs Act During the second quarter 2018, Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the Tax Cuts and Jobs Act, to their customers through rate riders and other means approved by their respective regulatory commissions. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This has a significant effect on the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46 Other Tax Matters     In April 2019 the state of Arkansas enacted corporate income tax law changes that phase in an Arkansas tax rate reduction from the current rate of 6.5% to 6.2% in 2021 and 5.9% in 2022.  The rate reduction will eventually reduce Entergy Arkansas’s combined federal and state applicable tax rate by less than 0.5% once fully adopted.  As a result of the rate reduction, Entergy Arkansas recorded a regulatory liability for income taxes of approximately $25 million which includes a tax gross-up related to the treatment of income taxes in the ratemaking formula. The Arkansas tax law enactment also phases in an increase to the net operating loss carryover period from five to ten years. In September 2019, Entergy Utility Holding Company, LLC and its regulated, wholly owned subsidiaries including Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, became eligible to and joined the Entergy Corporation consolidated federal income tax group.  Additionally, in September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock with a liquidation value of $25 per share resulting in the disaffiliation and de-consolidation of Entergy Texas from the consolidated federal income tax return of Entergy Corporation.  These changes will not affect the accrual or allocation of income taxes for the Registrant Subsidiaries. See Note 3 to the financial statements herein for discussion of the preferred stock issuance. Vermont Yankee The Vermont Yankee transaction resulted in Entergy generating a net deferred tax asset in January 2019.  The deferred tax asset could not be fully realized by Entergy in the first quarter of 2019; accordingly, Entergy accrued a net tax expense of $29 million on the disposition of Vermont Yankee. See Note 16 to the financial statements herein for discussion of the Vermont Yankee transaction.

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- Definition The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -URI http://asc.fasb.org/topic&trid=2144680 + Details Name: us-gaap_IncomeTaxDisclosureTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Income Taxes Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2019
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
Entergy Arkansas [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
Entergy Louisiana [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
Entergy Mississippi [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
Entergy New Orleans [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
Entergy Texas [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46
System Energy [Member]
Reduction to Regulatory Liability Due to Return of Unprotected Excess ADIT [Table Text Block]	The return of unprotected excess accumulated deferred income taxes reduced Entergy’s and the Registrant Subsidiaries’ regulatory liability for income taxes as follows:   Three Months Ended September 30,   Nine Months Ended September 30,   2019   2018   2019   2018   (In Millions) Entergy $96   $283   $219   $562 Entergy Arkansas $41   $153   $99   $260 Entergy Louisiana $17   $55   $31   $86 Entergy Mississippi $—   $32   $—   $161 Entergy New Orleans $7   $9   $9   $9 Entergy Texas $31   $—   $73   $— System Entergy $—   $34   $7   $46

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v3.19.3

Rate And Regulatory Matters (Narrative) (Details) - USD ($)		1 Months Ended											3 Months Ended	9 Months Ended		12 Months Ended					15 Months Ended		36 Months Ended
	Jul. 31, 2019	Oct. 31, 2019	Sep. 30, 2019	Aug. 31, 2019	Jul. 31, 2019	Jun. 30, 2019	May 31, 2019	Apr. 30, 2019	Mar. 31, 2019	Jan. 31, 2019	Dec. 31, 2018	Jul. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018	Jul. 27, 2019	Apr. 23, 2018	Mar. 31, 2019
Regulatory Assets [Line Items]
Impairment of Long-Lived Assets Held-for-use														$ 225,175,000	$ 210,263,000
Deferred Fuel Cost			$ 0								$ 27,251,000			0						$ 27,251,000
Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount							$ 118,700,000
Rate Increase Included in Formula Rate Plan							109,500,000
Earned return on common equity																				10.61%
Formula rate plan revenue decrease																				$ 8,900,000
Entergy Louisiana [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
LPSC staff recommended fuel adjustment clause refund including interest										$ 7,300,000
Entergy Louisiana calculated fuel adjustment clause refund including interest				$ 4,200,000
Entergy Mississippi [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost			0								8,016,000			$ 0						$ 8,016,000
Authorized return on common equity														6.93%						7.13%
Public Utilities, Requested Return on Equity, Percentage														6.94%
Public Utilities, Requested Rate Increase (Decrease), Amount																				$ 10,100,000
Public Utilities, Approved Rate Increase (Decrease), Amount																				$ 11,000,000
Earned return on common equity																				7.81%
Monthly storm damage provision														$ 1,750,000
Authorized Storm Damage Reserve Balance			15,000,000											15,000,000
Balance At Which Storm Damage Accrual Will Return To Current Level							$ 10,000,000							10,000,000
Entergy Mississippi [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return											9,300,000									$ 9,300,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return						$ 900,000			$ 800,000										$ 800,000				$ 800,000
Entergy Mississippi [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount																		$ 36,800,000
Public Utilities, Approved Rate Increase (Decrease), Amount																		$ 32,800,000
Entergy New Orleans [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				30,000,000
Entergy New Orleans [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				27,000,000
Entergy New Orleans [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 3,000,000
Entergy New Orleans [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage				10.50%
Entergy New Orleans [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 39,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Electricity [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		36,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Natural Gas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 3,000,000
Entergy New Orleans [Member] | Subsequent Event [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage		9.35%
Public Utilities, Approved Equity Capital Structure, Percentage		50.00%
Entergy Texas [Member]
Regulatory Assets [Line Items]
Jurisdictional eligible fuel and purchased power expenses, net of credits																							1,600,000,000
Fuel and purchased power under-recovery balance including interest									25,800,000										25,800,000				$ 25,800,000
Requested recovery of internal and external litigation expenses previously paid or incurred										$ 7,200,000
Entergy Texas [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred								$ 3,200,000
Entergy Texas [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred								$ 4,200,000
Entergy Texas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Recommended disallowance of requested recovery of expenses previously paid or incurred		$ 1,400,000
Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Deferred Fuel Cost			0								19,235,000			0						19,235,000
Public Utilities, Requested Return on Equity, Percentage	9.75%
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 15,300,000
Refund to Customers Credited Through Formula Rate Plan																				46,600,000
Regulatory asset related to scrubber costs incurred at White Bluff plant	$ 11,200,000				$ 11,200,000
Energy Cost Recovery Rider Rate Per kWh																			$ 0.01882
Retail balance over-recovery											100,000									100,000
Receipts from utility operating companies pursuant to FERC order												$ 4,200,000
Entergy Arkansas [Member] | Revenue Subject to Refund [Member]
Regulatory Assets [Line Items]
Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return											35,100,000									35,100,000
True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return			11,500,000											11,500,000
Entergy Arkansas [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		14,000,000
Projected Revenue Deficiency																$ 61,900,000
Public Utilities, Approved Rate Increase (Decrease), Amount		10,100,000
Regulatory charge recorded to write-off White Bluff scrubber regulatory asset													$ 11,200,000
Energy Cost Recovery Rider Rate Per kWh																	$ 0.01462
System Energy [Member]
Regulatory Assets [Line Items]
FERC requested authorized return on equity for System Energy in return on equity proceeding																						9.89%
Public utilities requested return on equity percentage, median 2nd refund period																					9.65%
Public utilities requested return on equity percentage, midpoint 2nd refund period																					9.74%
Modified public utilities requested return on equity percentage based on benchmarks, median 2nd refund period																					9.91%
Modified public utilities requested return on equity percentage based on benchmarks, midpoint 2nd refund period																					10.30%
LPSC requested authorized return on equity for System Energy in return on equity proceeding																					7.97%	7.81%
APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding																					8.32%	8.26%
FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal																					9.63%	9.40%
APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding																					8.41%	8.24%
Annual renewal lease payments on Grand Gulf Sale-Leaseback														17,200,000
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback											334,500,000									$ 334,500,000
FERC staff argued over-recovery in depreciation expense for capital additions				$ 32,000,000
LPSC requested refund of cost of capital additions resulting from Grand Gulf sale-leaseback			$ 274,800,000											$ 274,800,000
Ratepayer savings due to Grand Gulf sale-leaseback initial and renewal terms						$ 850,000,000
FERC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback				$ 602,000,000
System Energy [Member] | Minimum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																					10.32%	10.10%
System Energy [Member] | Maximum [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Return on Equity, Percentage																					10.69%	10.70%
Percent Equity in Proposed Common Equity Ratio				37.00%
Percent Debt in Proposed Common Equity Ratio				63.00%
LPSC Argued Equity Capital Structure, Percentage				49.00%
APSC and MPSC Argued Equity Capital Structure, Percentage				35.98%
APSC and MPSC Alternative Argued Equity Capital Structure, Percentage				46.75%
FERC Percent Equity in Proposed Common Equity Ratio			46.74%
FERC Percent Debt in Proposed Common Equity Ratio			53.26%
System Energy [Member] | Subsequent Event [Member]
Regulatory Assets [Line Items]
LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback		512,000,000
FERC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback		$ 511,000,000
Grand Gulf [Member] | System Energy [Member]
Regulatory Assets [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage														11.50%
FERC May 2018 Order [Member] | Entergy Louisiana [Member]
Regulatory Assets [Line Items]
Receipts from utility operating companies pursuant to FERC order												23,000,000
FERC May 2018 Order [Member] | Entergy Arkansas [Member]
Regulatory Assets [Line Items]
Receipts from utility operating companies pursuant to FERC order												$ 4,000,000
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount									$ 3,200,000
Transmission Cost Recovery Factor Rider [Member] | Entergy Texas [Member]
Regulatory Assets [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount				$ 19,400,000							$ 2,700,000
Revenue increase resulting from incremental revenue				$ 16,700,000
Public Utilities, Approved Rate Increase (Decrease), Amount					$ 2,700,000

X

- Definition APSC/MPSC requested authorized return on equity for System Energy in return on equity proceeding + References No definition available. + Details Name: etr_APSCMPSCrequestedauthorizedreturnonequityforSystemEnergyinreturnonequityproceeding Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition APSC/MPSC revised argued authorized return on equity for System Energy in return on equity proceeding + References No definition available. + Details Name: etr_APSCMPSCrevisedarguedauthorizedreturnonequityforSystemEnergyinreturnonequityproceeding Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition APSC and MPSC Alternative Argued Equity Capital Structure, Percentage. Based on median equity ratio of proxy group for setting ROE. + References No definition available. + Details Name: etr_APSCandMPSCAlternativeArguedEquityCapitalStructurePercentage Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition APSC and MPSC Argued Equity Capital Structure, Percentage + References No definition available. + Details Name: etr_APSCandMPSCArguedEquityCapitalStructurePercentage Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Annual renewal lease payments on Grand Gulf Sale-Leaseback + References No definition available. + Details Name: etr_AnnualrenewalleasepaymentsonGrandGulfSaleLeaseback Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Authorized Storm Damage Reserve Balance + References No definition available. + Details Name: etr_AuthorizedStormDamageReserveBalance Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Balance At Which Storm Damage Accrual Will Return To Current Level + References No definition available. + Details Name: etr_BalanceAtWhichStormDamageAccrualWillReturnToCurrentLevel Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Earned return on common equity. + References No definition available. + Details Name: etr_EarnedReturnOnCommonEquity Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Energy Cost Recovery Rider Rate Per kWh + References No definition available. + Details Name: etr_EnergyCostRecoveryRiderRatePerkWh Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Entergy Louisiana calculated fuel adjustment clause refund including interest + References No definition available. + Details Name: etr_EntergyLouisianacalculatedfueladjustmentclauserefundincludinginterest Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition FERC Percent Debt in Proposed Common Equity Ratio + References No definition available. + Details Name: etr_FERCPercentDebtinProposedCommonEquityRatio Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition FERC Percent Equity in Proposed Common Equity Ratio + References No definition available. + Details Name: etr_FERCPercentEquityinProposedCommonEquityRatio Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition FERC requested authorized return on equity for System Energy in return on equity proceeding + References No definition available. + Details Name: etr_FERCrequestedauthorizedreturnonequityforSystemEnergyinreturnonequityproceeding Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition FERC requested authorized return on equity for System Energy in return on equity proceeding, rebuttal + References No definition available. + Details Name: etr_FERCrequestedauthorizedreturnonequityforSystemEnergyinreturnonequityproceedingrebuttal Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition FERC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback + References No definition available. + Details Name: etr_FERCrequestedratereductionforADITassociatedwithuncertaintaxpositionsresultingfromGrandGulfsaleleaseback Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition FERC staff argued over-recovery in depreciation expense for capital additions + References No definition available. + Details Name: etr_FERCstaffarguedoverrecoveryindepreciationexpenseforcapitaladditions Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Formula rate plan revenue decrease + References No definition available. + Details Name: etr_Formularateplanrevenuedecrease Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Fuel and purchased power under-recovery balance including interest + References No definition available. + Details Name: etr_Fuelandpurchasedpowerunderrecoverybalanceincludinginterest Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Jurisdictional eligible fuel and purchased power expenses, net of credits + References No definition available. + Details Name: etr_Jurisdictionaleligiblefuelandpurchasedpowerexpensesnetofcredits Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition LPSC Argued Equity Capital Structure, Percentage + References No definition available. + Details Name: etr_LPSCArguedEquityCapitalStructurePercentage Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition LPSC requested authorized return on equity for System Energy in return on equity proceeding + References No definition available. + Details Name: etr_LPSCrequestedauthorizedreturnonequityforSystemEnergyinreturnonequityproceeding Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition LPSC requested rate reduction for ADIT associated with uncertain tax positions resulting from Grand Gulf sale-leaseback + References No definition available. + Details Name: etr_LPSCrequestedratereductionforADITassociatedwithuncertaintaxpositionsresultingfromGrandGulfsaleleaseback Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition LPSC requested refund of cost of capital additions resulting from Grand Gulf sale-leaseback + References No definition available. + Details Name: etr_LPSCrequestedrefundofcostofcapitaladditionsresultingfromGrandGulfsaleleaseback Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition LPSC staff recommended refund to customers including interest related to fuel adjustment clause + References No definition available. + Details Name: etr_LPSCstaffrecommendedfueladjustmentclauserefundincludinginterest Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Modified public utilities requested return on equity percentage based on benchmarks, median + References No definition available. + Details Name: etr_Modifiedpublicutilitiesrequestedreturnonequitypercentagebasedonbenchmarksmedian2ndrefundperiod Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Modified public utilities requested return on equity percentage based on benchmarks, midpoint + References No definition available. + Details Name: etr_Modifiedpublicutilitiesrequestedreturnonequitypercentagebasedonbenchmarksmidpoint2ndrefundperiod Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Monthly storm damage provision + References No definition available. + Details Name: etr_Monthlystormdamageprovision Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition LPSC Percent Debt in Proposed Common Equity Ratio + References No definition available. + Details Name: etr_PercentDebtinProposedCommonEquityRatio Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition LPSC Percent Equity in Proposed Common Equity Ratio + References No definition available. + Details Name: etr_PercentEquityinProposedCommonEquityRatio Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Projected Revenue Deficiency + References No definition available. + Details Name: etr_ProjectedRevenueDeficiency Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return + References No definition available. + Details Name: etr_Provisionrecordedtoreflectchangeinformularateplanrevenuescomparedtoallowedrateofreturn Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Public utilities requested return on equity percentage, median + References No definition available. + Details Name: etr_Publicutilitiesrequestedreturnonequitypercentagemedian2ndrefundperiod Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Public utilities requested return on equity percentage, midpoint + References No definition available. + Details Name: etr_Publicutilitiesrequestedreturnonequitypercentagemidpoint2ndrefundperiod Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Rate Increase Included in Formula Rate Plan + References No definition available. + Details Name: etr_RateIncreaseIncludedinFormulaRatePlan Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Ratepayer savings due to Grand Gulf sale-leaseback initial and renewal terms + References No definition available. + Details Name: etr_RatepayersavingsduetoGrandGulfsaleleasebackinitialandrenewalterms Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Receipts from utility operating companies pursuant to FERC order + References No definition available. + Details Name: etr_ReceiptsfromutilityoperatingcompaniespursuanttoFERCorder Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Recommended disallowance of requested recovery of expenses previously paid or incurred + References No definition available. + Details Name: etr_Recommendeddisallowanceofrequestedrecoveryofexpensespreviouslypaidorincurred Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Refund to Customers Credited Through Formula Rate Plan + References No definition available. + Details Name: etr_RefundtoCustomersCreditedThroughFormulaRatePlan Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Regulatory asset related to scrubber costs incurred at White Bluff plant + References No definition available. + Details Name: etr_RegulatoryassetrelatedtoscrubbercostsincurredatWhiteBluffplant Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Regulatory charge recorded to write-off White Bluff scrubber regulatory asset + References No definition available. + Details Name: etr_RegulatorychargerecordedtowriteoffWhiteBluffscrubberregulatoryasset Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Requested recovery of internal and external litigation expenses previously paid or incurred + References No definition available. + Details Name: etr_Requestedrecoveryofinternalandexternallitigationexpensespreviouslypaidorincurred Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Retail balance over-recovery + References No definition available. + Details Name: etr_Retailbalanceoverrecovery Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Revenue increase resulting from incremental revenue + References No definition available. + Details Name: etr_Revenueincreaseresultingfromincrementalrevenue Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition True-up to provision recorded to reflect change in formula rate plan revenues compared to allowed rate of return + References No definition available. + Details Name: etr_Trueuptoprovisionrecordedtoreflectchangeinformularateplanrevenuescomparedtoallowedrateofreturn Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Carrying amount as of the balance sheet date of capitalized fuel costs of a regulated entity that are expected to be recoverable through rate adjustments within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -SubTopic 340 -Section 25 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=77907324&loc=d3e43603-110378 + Details Name: us-gaap_DeferredFuelCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition The aggregate amount of write-downs for impairments recognized during the period for long lived assets held for use (including those held for disposal by means other than sale). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109226691&loc=d3e2921-110230 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 958 -SubTopic 220 -Section 45 -Paragraph 11 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=114873921&loc=SL114875236-224282 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109226348&loc=d3e2420-110228 + Details Name: us-gaap_ImpairmentOfLongLivedAssetsHeldForUse Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Percentage of public utility's approved equity to capital, including debt and equity. + References No definition available. + Details Name: us-gaap_PublicUtilitiesApprovedEquityCapitalStructurePercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Amount of public utility's approved rate increase (decrease) by regulatory agency. + References No definition available. + Details Name: us-gaap_PublicUtilitiesApprovedRateIncreaseDecreaseAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Percentage of public utility's approved return on equity. + References No definition available. + Details Name: us-gaap_PublicUtilitiesApprovedReturnOnEquityPercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Amount of public utility's requested rate increase (decrease) with regulatory agency. + References No definition available. + Details Name: us-gaap_PublicUtilitiesRequestedRateIncreaseDecreaseAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Percentage of public utility's requested return on equity. + References No definition available. + Details Name: us-gaap_PublicUtilitiesRequestedReturnOnEquityPercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_RegulatoryAssetLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Percentage of the Variable Interest Entity's (VIE) voting interest owned by (or beneficial interest in) the reporting entity (directly or indirectly). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 50 -Paragraph 5A -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=108788376&loc=SL6759159-111685 + Details Name: us-gaap_VariableInterestEntityOwnershipPercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_RegulatoryLiabilityAxis=us-gaap_RevenueSubjectToRefundMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_SubsequentEventTypeAxis=us-gaap_SubsequentEventMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: srt_ProductOrServiceAxis=us-gaap_ElectricityMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: srt_ProductOrServiceAxis=srt_NaturalGasReservesMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: srt_RangeAxis=srt_MaximumMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: srt_RangeAxis=srt_MinimumMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_VariableInterestEntitiesByClassificationOfEntityAxis=etr_GrandGulfMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_PublicUtilitiesRegulatoryProceedingAxis=etr_FERCMay2018OrderMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_PublicUtilitiesRegulatoryProceedingAxis=etr_DistributionCostRecoveryFactorRiderMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_PublicUtilitiesRegulatoryProceedingAxis=etr_TransmissionCostRecoveryFactorRiderMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Retirement And Other Postretirement Benefits (Expected Employer Contributions) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Dec. 31, 2019	Sep. 30, 2019
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		$ 176,900
Defined Benefit Plan, Plan Assets, Contributions by Employer		123,100
Entergy Louisiana [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		26,451
Defined Benefit Plan, Plan Assets, Contributions by Employer		18,272
Entergy Louisiana [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 8,179
Entergy Mississippi [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		7,701
Defined Benefit Plan, Plan Assets, Contributions by Employer		5,186
Entergy Mississippi [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,515
Entergy New Orleans [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		1,800
Defined Benefit Plan, Plan Assets, Contributions by Employer		1,237
Entergy New Orleans [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	563
Entergy Texas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		1,645
Defined Benefit Plan, Plan Assets, Contributions by Employer		1,192
Entergy Texas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	453
System Energy [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		8,285
Defined Benefit Plan, Plan Assets, Contributions by Employer		5,631
System Energy [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	2,654
Entergy Arkansas [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year		27,112
Defined Benefit Plan, Plan Assets, Contributions by Employer		$ 18,222
Entergy Arkansas [Member] | Subsequent Event [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Plan Assets, Contributions by Employer	$ 8,890

X

- Definition A roll forward is a reconciliation of a concept from the beginning of a period to the end of a period. + References No definition available. + Details Name: us-gaap_DefinedBenefitPlanChangeInFairValueOfPlanAssetsRollForward Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Amount of contribution received by defined benefit plan from employer which increases plan assets. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (d)(iv)(01) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 3: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (d)(ii) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 4: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 Reference 5: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 + Details Name: us-gaap_DefinedBenefitPlanContributionsByEmployer Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of contributions expected to be received by defined benefit plan from employer in fiscal year. Excludes contributions paid by employer in current fiscal year. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanExpectedFutureEmployerContributionsRemainderOfFiscalYear Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Stock-Based Compensation (Financial Information For Stock Options) (Details) - Employee Stock Option [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 0.9	$ 1.1	$ 2.9	$ 3.3
Tax benefit recognized in Entergy's net income	0.2	0.2	0.7	0.8
Compensation cost capitalized as part of fixed assets and inventory	$ 0.4	$ 0.1	$ 1.0	$ 0.5

X

- Definition Represents the expense recognized during the period arising from equity-based compensation arrangements (for example, shares of stock, unit, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5047-113901 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SAB Topic 14.F) -URI http://asc.fasb.org/extlink&oid=115993241&loc=d3e301413-122809 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(i) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_AllocatedShareBasedCompensationExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- References No definition available. + Details Name: us-gaap_EmployeeServiceShareBasedCompensationAggregateDisclosuresAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Represents the compensation cost capitalized during the period arising from equity-based compensation arrangements (for example, shares of stock, units, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(ii) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_EmployeeServiceShareBasedCompensationAllocationOfRecognizedPeriodCostsCapitalizedAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition The total recognized tax benefit related to compensation cost for equity-based payment arrangements recognized in income during the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(i) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_EmployeeServiceShareBasedCompensationTaxBenefitFromCompensationExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Details Name: us-gaap_IncomeStatementLocationAxis=us-gaap_EmployeeStockOptionMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Label	Element	Value
Common Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	$ 2,616,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	2,548,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Additional Paid-in Capital [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,951,431,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	5,433,433,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Retained Earnings [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	8,727,956,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	8,553,959,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	576,257,000
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	6,806,000
AOCI Attributable to Parent [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(563,979,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(656,148,000)
Treasury Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,273,719,000)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	(5,397,637,000)
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
Subsidiaries Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	0
New Accounting Pronouncement or Change in Accounting Principle, Cumulative Effect of Change on Equity or Net Assets	us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1	$ 0

X

- Definition Amount of cumulative effect of the change in accounting principle or new accounting pronouncement on retained earnings or other components of equity or net assets in the statement of financial position as of the beginning of the earliest period presented. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b)(3) -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22499-107794 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22583-107794 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 250 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109234566&loc=d3e22580-107794 + Details Name: us-gaap_NewAccountingPronouncementOrChangeInAccountingPrincipleCumulativeEffectOfChangeOnEquityOrNetAssets1 Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 45 -Paragraph 16 -URI http://asc.fasb.org/extlink&oid=108774443&loc=SL4568740-111683 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 55 -Paragraph 4I -URI http://asc.fasb.org/extlink&oid=84234705&loc=SL4590271-111686 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 45 -Paragraph 15 -URI http://asc.fasb.org/extlink&oid=108774443&loc=SL4568447-111683 + Details Name: us-gaap_StockholdersEquityIncludingPortionAttributableToNoncontrollingInterest Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Details Name: us-gaap_StatementEquityComponentsAxis=us-gaap_CommonStockMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_StatementEquityComponentsAxis=us-gaap_AdditionalPaidInCapitalMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_StatementEquityComponentsAxis=etr_SubsidiariesPreferredStockMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Leases Leases (Lease, Cost) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Short-term Lease, Cost	$ 15	$ 15
Operating Lease, Expense	16,086	47,061
Finance Lease, Right-of-Use Asset, Amortization	2,945	10,837
Finance Lease, Interest Expense	763	2,597
Entergy Arkansas [Member]
Operating Lease, Expense	3,306	9,724
Finance Lease, Right-of-Use Asset, Amortization	621	2,448
Finance Lease, Interest Expense	105	408
Entergy Louisiana [Member]
Short-term Lease, Cost	15	15
Operating Lease, Expense	3,003	8,854
Finance Lease, Right-of-Use Asset, Amortization	1,014	4,014
Finance Lease, Interest Expense	161	612
Entergy Mississippi [Member]
Operating Lease, Expense	1,752	5,220
Finance Lease, Right-of-Use Asset, Amortization	369	1,408
Finance Lease, Interest Expense	65	241
Entergy New Orleans [Member]
Operating Lease, Expense	349	1,058
Finance Lease, Right-of-Use Asset, Amortization	178	696
Finance Lease, Interest Expense	29	114
Entergy Texas [Member]
Operating Lease, Expense	1,074	3,135
Finance Lease, Right-of-Use Asset, Amortization	335	965
Finance Lease, Interest Expense	$ 54	$ 153

X

- Definition Amount of interest expense on finance lease liability. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 4 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918638-209977 Reference 3: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseInterestExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of amortization expense attributable to right-of-use asset from finance lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 4 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918638-209977 Reference 3: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_FinanceLeaseRightOfUseAssetAmortization Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of operating lease expense. Excludes sublease income. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 4 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918638-209977 + Details Name: us-gaap_OperatingLeaseExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of short-term lease cost, excluding expense for lease with term of one month or less. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_ShortTermLeaseCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Decommissioning Trust Funds (Fair Value Of Debt Securities By Contractual Maturities) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair value of debt securities by contractual maturities
Less than 1 year	$ 165.0	$ 199.0
1 year - 5 years	870.0	1,066.0
5 years - 10 years	636.0	544.0
10 years - 15 years	89.0	77.0
15 years - 20 years	98.0	78.0
20 years+	604.0	531.0
Total	2,462.0	2,495.0
Entergy Arkansas [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	50.3	32.5
1 year - 5 years	120.4	170.3
5 years - 10 years	144.5	114.0
10 years - 15 years	24.3	10.3
15 years - 20 years	14.2	8.1
20 years+	54.0	46.1
Total	407.7	381.3
Entergy Louisiana [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	56.6	31.1
1 year - 5 years	138.2	130.5
5 years - 10 years	118.4	111.0
10 years - 15 years	34.7	29.0
15 years - 20 years	45.0	37.1
20 years+	200.5	194.2
Total	593.4	532.9
System Energy [Member]
Fair value of debt securities by contractual maturities
Less than 1 year	11.2	22.8
1 year - 5 years	187.7	188.0
5 years - 10 years	92.7	73.4
10 years - 15 years	3.0	5.2
15 years - 20 years	5.9	10.2
20 years+	94.8	64.6
Total	$ 395.3	$ 364.2

X

- Definition Available For Sale Securities Debt Maturities After Fifteen to twenty Years Fair Value. + References No definition available. + Details Name: etr_AvailableForSaleSecuritiesDebtMaturitiesAfterFifteenToTwentyYearsFairValue Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Available for sale securities debt maturities after ten to fifteen years fair value. + References No definition available. + Details Name: etr_AvailableForSaleSecuritiesDebtMaturitiesAfterTenToFifteenYearsFairValue Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Available For Sale Securities Debt Maturities After Twenty Years Fair Value. + References No definition available. + Details Name: etr_AvailableForSaleSecuritiesDebtMaturitiesAfterTwentyYearsFairValue Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Fair value of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale), with single maturity date and allocated without single maturity date, maturing in sixth through tenth fiscal year following latest fiscal year. Excludes interim and annual periods when interim period is reported on rolling approach, from latest statement of financial position date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 3 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27198-111563 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 320 -Section 50 -Paragraph 3 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=75019621&loc=d3e62586-112803 + Details Name: us-gaap_AvailableForSaleSecuritiesDebtMaturitiesAfterFiveThroughTenYearsFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Fair value of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale), with single maturity date and allocated without single maturity date, maturing in second through fifth fiscal year following latest fiscal year. Excludes interim and annual periods when interim period is reported on rolling approach, from latest statement of financial position date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 3 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27198-111563 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 320 -Section 50 -Paragraph 3 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=75019621&loc=d3e62586-112803 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 + Details Name: us-gaap_AvailableForSaleSecuritiesDebtMaturitiesAfterOneThroughFiveYearsFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesDebtMaturitiesFairValueAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Fair value of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale), maturing in next fiscal year following latest fiscal year. Excludes interim and annual periods when interim period is reported on rolling approach, from latest statement of financial position date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 3 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27198-111563 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 320 -Section 50 -Paragraph 3 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=75019621&loc=d3e62586-112803 + Details Name: us-gaap_AvailableForSaleSecuritiesDebtMaturitiesWithinOneYearFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109979856&loc=d3e26610-111562 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (aa) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 + Details Name: us-gaap_AvailableForSaleSecuritiesDebtSecurities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Leases Leases (Lease, Liabilities) (Details) $ in Thousands	Sep. 30, 2019 USD ($)
Operating Lease, Liability, Current	$ 52,348
Finance Lease, Liability, Current	11,482
Operating Lease, Liability, Noncurrent	184,404
Finance Lease, Liability, Noncurrent	53,252
Entergy Arkansas [Member]
Operating Lease, Liability, Current	10,662
Finance Lease, Liability, Current	2,600
Operating Lease, Liability, Noncurrent	38,881
Finance Lease, Liability, Noncurrent	8,665
Entergy Louisiana [Member]
Operating Lease, Liability, Current	9,969
Finance Lease, Liability, Current	3,860
Operating Lease, Liability, Noncurrent	24,289
Finance Lease, Liability, Noncurrent	12,925
Entergy Mississippi [Member]
Operating Lease, Liability, Current	6,137
Finance Lease, Liability, Current	1,473
Operating Lease, Liability, Noncurrent	12,254
Finance Lease, Liability, Noncurrent	5,521
Entergy New Orleans [Member]
Operating Lease, Liability, Current	1,138
Finance Lease, Liability, Current	626
Operating Lease, Liability, Noncurrent	2,755
Finance Lease, Liability, Noncurrent	2,286
Entergy Texas [Member]
Operating Lease, Liability, Current	3,427
Finance Lease, Liability, Current	1,252
Operating Lease, Liability, Noncurrent	9,689
Finance Lease, Liability, Noncurrent	$ 4,221

X

- Definition Present value of lessee's discounted obligation for lease payments from finance lease, classified as current. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_FinanceLeaseLiabilityCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Present value of lessee's discounted obligation for lease payments from finance lease, classified as noncurrent. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_FinanceLeaseLiabilityNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Present value of lessee's discounted obligation for lease payments from operating lease, classified as current. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_OperatingLeaseLiabilityCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Present value of lessee's discounted obligation for lease payments from operating lease, classified as noncurrent. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_OperatingLeaseLiabilityNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Leases Leases (Schedule of Rent Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Operating Leases, Rent Expense, Net	$ 47.8	$ 53.1	$ 44.4
Entergy Arkansas [Member]
Operating Leases, Rent Expense, Net	6.2	7.5	8.0
Entergy Louisiana [Member]
Operating Leases, Rent Expense, Net	20.2	23.0	17.8
Entergy Mississippi [Member]
Operating Leases, Rent Expense, Net	4.6	5.6	4.0
Entergy New Orleans [Member]
Operating Leases, Rent Expense, Net	2.5	2.5	0.9
Entergy Texas [Member]
Operating Leases, Rent Expense, Net	3.1	3.4	2.8
System Energy [Member]
Operating Leases, Rent Expense, Net	$ 1.9	$ 2.2	$ 1.6

X

- Definition Rental expense for the reporting period incurred under operating leases, including minimum and any contingent rent expense, net of related sublease income. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41499-112717 + Details Name: us-gaap_OperatingLeasesRentExpenseNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Variable Interest Entities (Narrative) (Details) - Grand Gulf [Member] - System Energy [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Variable Interest Entity [Line Items]
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage		11.50%
Payments on lease, including interest	$ 8.6	$ 17.2	$ 17.2

X

- Definition Payments on lease, including interest. + References No definition available. + Details Name: etr_PaymentsOnLeaseIncludingInterest Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_VariableInterestEntityLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Percentage of the Variable Interest Entity's (VIE) voting interest owned by (or beneficial interest in) the reporting entity (directly or indirectly). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 50 -Paragraph 5A -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=108788376&loc=SL6759159-111685 + Details Name: us-gaap_VariableInterestEntityOwnershipPercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Details Name: us-gaap_VariableInterestEntitiesByClassificationOfEntityAxis=etr_GrandGulfMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended					9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Feb. 28, 2019	Jan. 31, 2019	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Short-term borrowings	$ 1,917,788					$ 1,917,788	$ 1,942,339
Amount of Facility	3,500,000					3,500,000
Amount Drawn/ Outstanding	$ 155,000					$ 155,000
Commercial Paper Program [Member]
Debt Instrument [Line Items]
Debt, weighted average interest rate	2.88%					2.88%
Commercial Paper program limit	$ 2,000,000					$ 2,000,000
Commercial Paper Amount Outstanding	1,918,000					1,918,000
Credit Facility [Member]
Debt Instrument [Line Items]
Amount of Facility	3,500,000					3,500,000
Amount of total borrowing capacity against which fronting commitments exist	20,000					$ 20,000
Line of credit facility, commitment fee percentage						0.225%
Line of Credit Facility, Interest Rate During Period						3.94%
Entergy Arkansas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	250,000					$ 250,000
Amount of total borrowing capacity against which fronting commitments exist	5,000					5,000
Entergy Arkansas [Member] | Mortgage Bonds Four Point Two Percent Series Due April 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 350,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Louisiana [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	450,000					450,000
Amount of total borrowing capacity against which fronting commitments exist	15,000					15,000
Entergy Louisiana [Member] | Mortgage Bonds, Four Point Two Zero Percent Series due April Twenty Fifty [Member] [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 525,000
Debt instrument, interest rate, stated percentage			4.20%
Entergy Mississippi [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	175,000					175,000
Letters of Credit Outstanding, Amount	200					200	200
Entergy Mississippi [Member] | Mortgage bonds, 3.85% Series due June 2049 [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt		$ 300,000
Debt instrument, interest rate, stated percentage		3.85%
Entergy Mississippi [Member] | Mortgage Bonds Six Point Six Four Percent Series Due July Two Thousand Nineteen [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage		6.64%
Repayments of Debt		$ 150,000
Entergy Texas [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	200,000					200,000
Amount of total borrowing capacity against which fronting commitments exist	30,000					$ 30,000
Letters of Credit Outstanding, Amount							$ 4,100
Entergy Texas [Member] | Mortgage Bonds Four Percent Due March 2029 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 300,000
Debt instrument, interest rate, stated percentage					4.00%
Entergy Texas [Member] | Mortgage Bonds Four Point Five Percent Due March 2039 [Domain] [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 400,000
Debt instrument, interest rate, stated percentage					4.50%
Entergy Texas [Member] | 7.125% Series First Mortgage Bonds Due February 2019 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage				7.125%
Repayments of Debt				$ 500,000
Entergy Texas [Member] | Mortgage Bonds Three Point Fifty Five Percent Due September 2049 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt	$ 300,000
Debt instrument, interest rate, stated percentage	3.55%					3.55%
System Energy [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	$ 200,000					$ 200,000
System Energy [Member] | Two Point Five Percent Series 2019 Revenue Refunding Bonds Due April 2022 [Domain]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt			$ 134,000
Debt instrument, interest rate, stated percentage			2.50%
System Energy [Member] | Two Point Five Percent Series 2019 Revenue Refunding Bonds Due April 2022 [Domain]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage			5.875%
Repayments of Debt			$ 134,000
Entergy Nuclear Vermont Yankee [Member]
Debt Instrument [Line Items]
Amount of Facility	139,000					$ 139,000
Line of credit facility, commitment fee percentage						0.20%
Amount Drawn/ Outstanding	139,000				$ 139,000	$ 139,000
Line of Credit Facility, Interest Rate During Period						4.07%
Entergy New Orleans [Member]
Debt Instrument [Line Items]
Authorized Short Term Borrowings	150,000					$ 150,000
Amount of total borrowing capacity against which fronting commitments exist	10,000					10,000
System Energy VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	53,600					$ 53,600
Line of Credit Facility, Interest Rate During Period						3.42%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Entergy Arkansas VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 30,300					$ 30,300
Line of Credit Facility, Interest Rate During Period						3.41%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Entergy Arkansas VIE [Member] | Three Point Six Five Percent Series L Notes Due July Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.65%					3.65%
Entergy Louisiana Waterford VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 65,500					$ 65,500
Line of Credit Facility, Interest Rate During Period						3.41%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Entergy Louisiana Waterford VIE [Member] | Three Point Nine Two Percent Series H Dues February Two Thousand Twenty One [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate, stated percentage	3.92%					3.92%
Entergy Louisiana River Bend VIE [Member]
Debt Instrument [Line Items]
Amount Drawn/ Outstanding	$ 84,300					$ 84,300
Line of Credit Facility, Interest Rate During Period						3.37%
Line of credit facility commitment fee as a percentage of undrawn commitment amount						0.10%
Line of Credit Facility, Expiration Date						Sep. 16, 2021
Maximum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage						0.225%
Consolidated debt ratio	0.65					0.65
Maximum [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65					0.65
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65					0.65
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65					0.65
Maximum [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65					0.65
Maximum [Member] | System Energy [Member]
Debt Instrument [Line Items]
Consolidated debt ratio of total capitalization						70.00%
Maximum [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Consolidated debt ratio	0.65					0.65
Minimum [Member]
Debt Instrument [Line Items]
Line of credit facility, commitment fee percentage						0.075%
Credit Facility Of Twenty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	$ 20,000					$ 20,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.17%
Line of Credit Facility, Expiration Date						Apr. 30, 2020
Credit Facility Of Three Hundred Fifty Million [Member] | Entergy Louisiana [Member]
Debt Instrument [Line Items]
Amount of Facility	350,000					$ 350,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.17%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Arkansas [Member]
Debt Instrument [Line Items]
Amount of Facility	150,000					$ 150,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.17%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
Credit Facility Of One Hundred And Fifty Million [Member] | Entergy Texas [Member]
Debt Instrument [Line Items]
Amount of Facility	150,000					$ 150,000
Letters of Credit Outstanding, Amount	1,300					1,300
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.54%
Line of Credit Facility, Expiration Date						Sep. 14, 2024
Credit Facility Of Thirty Seven Point Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	37,500					$ 37,500
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
Credit Facility Of Thirty Five Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	35,000					$ 35,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
Credit Facility Of Ten Million [Member] | Entergy Mississippi [Member]
Debt Instrument [Line Items]
Amount of Facility	10,000					$ 10,000
Letters of Credit Outstanding, Amount	0					0
Amount Drawn/ Outstanding	0					$ 0
Line of Credit Facility, Interest Rate During Period						3.54%
Line of Credit Facility, Expiration Date						May 31, 2020
Credit Facility Of Twenty Five Million [Member] | Entergy New Orleans [Member]
Debt Instrument [Line Items]
Amount of Facility	25,000					$ 25,000
Letters of Credit Outstanding, Amount	800					800
Amount Drawn/ Outstanding	$ 0					$ 0
Line of Credit Facility, Interest Rate During Period						3.32%
Line of Credit Facility, Expiration Date						Nov. 20, 2021

X

- Definition Amount of total borrowing capacity against which fronting commitments exist + References No definition available. + Details Name: etr_Amountoftotalborrowingcapacityagainstwhichfrontingcommitmentsexist Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Authorized short-term borrowings. + References No definition available. + Details Name: etr_AuthorizedShortTermBorrowings Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Commercial Paper Amount Outstanding + References No definition available. + Details Name: etr_CommercialPaperAmountOutstanding Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Commercial Paper program limit + References No definition available. + Details Name: etr_CommercialPaperProgramLimit Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Consolidated debt ratio of capitalization. + References No definition available. + Details Name: etr_ConsolidatedDebtRatioOfCapitalization Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Line of credit facility commitment fee as a percentage of undrawn commitment amount + References No definition available. + Details Name: etr_LineOfCreditFacilityCommitmentFeeAsPercentageOfUndrawnCommitmentAmount Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Contractual interest rate for funds borrowed, under the debt agreement. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.22(a)(1)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_DebtInstrumentInterestRateStatedPercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_DebtInstrumentLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Weighted average interest rate of debt outstanding. + References No definition available. + Details Name: us-gaap_DebtWeightedAverageInterestRate Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

- Definition The total amount of the contingent obligation under letters of credit outstanding as of the reporting date. + References No definition available. + Details Name: us-gaap_LettersOfCreditOutstandingAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(16)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_LineOfCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The fee, expressed as a percentage of the line of credit facility, for the line of credit facility regardless of whether the facility has been used. + References No definition available. + Details Name: us-gaap_LineOfCreditFacilityCommitmentFeePercentage Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Date the credit facility terminates, in CCYY-MM-DD format. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityExpirationDate1 Namespace Prefix: us-gaap_ Data Type: xbrli:dateItemType Balance Type: na Period Type: duration

X

- Definition The effective interest rate during the reporting period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityInterestRateDuringPeriod Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Maximum borrowing capacity under the credit facility without consideration of any current restrictions on the amount that could be borrowed or the amounts currently outstanding under the facility. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityMaximumBorrowingCapacity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The cash inflow during the period from additional borrowings in aggregate debt. Includes proceeds from short-term and long-term debt. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 14 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3255-108585 + Details Name: us-gaap_ProceedsFromIssuanceOfDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Indebtedness divided by net capital. + References No definition available. + Details Name: us-gaap_RatioOfIndebtednessToNetCapital1 Namespace Prefix: us-gaap_ Data Type: xbrli:pureItemType Balance Type: na Period Type: instant

X

- Definition The cash outflow during the period from the repayment of aggregate short-term and long-term debt. Excludes payment of capital lease obligations. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_RepaymentsOfDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Reflects the total carrying amount as of the balance sheet date of debt having initial terms less than one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(19)(a)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(a)(16)(a)(1)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(13)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 + Details Name: us-gaap_ShortTermBorrowings Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: us-gaap_DebtInstrumentAxis=etr_CommercialPaperProgramMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_DebtInstrumentAxis=etr_CreditFacilityMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_DebtInstrumentAxis=etr_MortgageBondsFourPointTwoPercentSeriesDueApril2049Member Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_DebtInstrumentAxis=etr_MortgageBondsFourPointTwoZeroPercentSeriesdueAprilTwentyFiftyMemberMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: us-gaap_DebtInstrumentAxis=etr_Mortgagebonds3.85SeriesdueJune2049Member Namespace Prefix: Data Type: na Balance Type: Period Type:

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019 USD ($)
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Amount Drawn/ Outstanding	$ 155.0
Entergy Arkansas VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 80.0
Line of Credit Facility, Interest Rate During Period	3.41%
Amount Drawn/ Outstanding	$ 30.3
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
System Energy VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 120.0
Line of Credit Facility, Interest Rate During Period	3.42%
Amount Drawn/ Outstanding	$ 53.6
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana River Bend VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105.0
Line of Credit Facility, Interest Rate During Period	3.37%
Amount Drawn/ Outstanding	$ 84.3
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%
Entergy Louisiana Waterford VIE [Member]
Issuance of commercial paper to finance the acquisition and ownership of nuclear fuel
Expiration Date	Sep. 16, 2021
Amount of Facility	$ 105.0
Line of Credit Facility, Interest Rate During Period	3.41%
Amount Drawn/ Outstanding	$ 65.5
Line of credit facility commitment fee as a percentage of undrawn commitment amount	0.10%

X

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- Definition Amount of current borrowing capacity under the credit facility considering any current restrictions on the amount that could be borrowed (for example, borrowings may be limited by the amount of current assets), but without considering any amounts currently outstanding under the facility. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityCurrentBorrowingCapacity Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Date the credit facility terminates, in CCYY-MM-DD format. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityExpirationDate1 Namespace Prefix: us-gaap_ Data Type: xbrli:dateItemType Balance Type: na Period Type: duration

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- Definition The effective interest rate during the reporting period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.19(b),22(b)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_LineOfCreditFacilityInterestRateDuringPeriod Namespace Prefix: us-gaap_ Data Type: num:percentItemType Balance Type: na Period Type: duration

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v3.19.3

Risk Management and Fair Values (Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income) (Details) - Not Designated As Hedging Instrument [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Competitive Businesses Operating Revenues [Member] | Electricity Swaps And Options [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	$ 0.0	$ 0.0	$ 0.0	$ 0.0
Amount of gain (loss) recorded in income	1.0	(2.0)	4.0	0.0
Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0.0	0.0	0.0	0.0
Amount of gain (loss) recorded in income	(2.0)	0.0	(9.0)	5.0
Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recognized in AOCI	0.0	0.0	0.0	0.0
Amount of gain (loss) recorded in income	25.0	31.0	78.0	104.0
Entergy Arkansas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	3.5	10.1	15.4	20.1
Entergy Louisiana [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(1.7)	(0.7)	(3.6)	4.2
Entergy Louisiana [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	14.4	13.8	40.9	57.2
Entergy Mississippi [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.3)	0.1	(5.5)	0.9
Entergy Mississippi [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	1.9	5.4	5.3	23.0
Entergy New Orleans [Member] | Fuel, Fuel Related Expenses And Gas Purchased For Resale [Member] | Natural Gas Swaps [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.1)		0.1
Entergy New Orleans [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	(0.3)	2.0	2.2	10.5
Entergy Texas [Member] | Purchased Power Expense [Member] | Fixed Transmission Rights (FTRs) [Member]
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]
Amount of gain (loss) recorded in income	$ 5.5	$ (0.4)	$ 13.6	$ (5.6)

X

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v3.19.3

Business Segment Information Business Segment Information (Restructuring Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Payments for Restructuring	$ 86	$ 0	$ 140	$ 0
Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges			70
Payments for Restructuring	86	0	140	0
Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Payments for Restructuring	0	0	0	0
Entergy Wholesale Commodities [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	14	43	70	103
Restructuring Reserve	123	200	123	200	$ 195	$ 193	$ 157	$ 97
Entergy Wholesale Commodities [Member] | Employee Retention and Severances Expenses and Other Benefits-Related Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	14	43	70	103
Restructuring Reserve	109	186	109	186	181	179	143	83
Entergy Wholesale Commodities [Member] | Economic Development Costs [Member]
Segment Reporting Information [Line Items]
Restructuring Charges	0	0	0	0
Restructuring Reserve	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14	$ 14

X

- Definition Amount of cash payments made as the result of exit or disposal activities. Excludes payments associated with a discontinued operation or an asset retirement obligation. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b)(2) -URI http://asc.fasb.org/extlink&oid=6394359&loc=d3e17939-110869 Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 17 -Subparagraph (f) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3367-108585 + Details Name: us-gaap_PaymentsForRestructuring Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of expenses associated with exit or disposal activities pursuant to an authorized plan. Excludes expenses related to a discontinued operation or an asset retirement obligation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SAB Topic 5.P.3) -URI http://asc.fasb.org/extlink&oid=115931487&loc=d3e140864-122747 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6394359&loc=d3e17939-110869 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SAB Topic 5.P.4(b)) -URI http://asc.fasb.org/extlink&oid=115931487&loc=d3e140904-122747 + Details Name: us-gaap_RestructuringCharges Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Carrying amount (including both current and noncurrent portions of the accrual) as of the balance sheet date pertaining to a specified type of cost associated with exit from or disposal of business activities or restructuring pursuant to a duly authorized plan. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b)(2) -URI http://asc.fasb.org/extlink&oid=6394359&loc=d3e17939-110869 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 420 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SAB TOPIC 5.P.4(b)) -URI http://asc.fasb.org/extlink&oid=115931487&loc=d3e140904-122747 + Details Name: us-gaap_RestructuringReserve Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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v3.19.3

Decommissioning Trust Funds (Narrative) (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Aug. 31, 2019	Jan. 01, 2019	Jan. 01, 2018
Debt Securities, Trading, Measurement Input	$ 506,000,000		$ 506,000,000		$ 389,000,000
Decommissioning Trust Funds [Abstract]
Accumulated Other Comprehensive Income (Loss), Financial Liability, Fair Value Option, after Tax							$ (6,806,000)	$ (632,617,000)
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts	1,303,000	$ (825,000)	17,472,000	$ 1,708,000
Amortized cost of debt securities	$ 2,362,000,000		$ 2,362,000,000		2,511,000,000
Average coupon rate of debt securities	3.15%		3.15%
Average duration of debt securities, years			5 years 7 months 17 days
Average maturity of debt securities, years			9 years 7 days
Proceeds from the dispositions of debt securities	$ 407,000,000	2,377,000,000	$ 1,133,000,000	4,178,000,000
Gains from dispositions of debt securities, gross	11,000,000	4,000,000	20,000,000	6,000,000
Losses from dispositions of debt securities, gross	400,000	15,000,000	3,000,000	37,000,000
Equity Securities, FV-NI, Unrealized Gain	17,000,000		491,000,000
Debt Securities [Member]
Decommissioning Trust Funds [Abstract]
Deferred taxes on unrealized gains/(losses) recorded in OCI for non-regulated decommissioning trusts			16,000,000		(1,000,000)
Entergy Arkansas [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 396,800,000		$ 396,800,000		389,000,000
Average coupon rate of debt securities	2.78%		2.78%
Average duration of debt securities, years			5 years 6 months 25 days
Average maturity of debt securities, years			8 years 1 month 17 days
Proceeds from the dispositions of debt securities	$ 45,500,000	137,900,000	$ 78,700,000	259,300,000
Gains from dispositions of debt securities, gross	2,000,000	10,000.00	2,100,000	100,000
Losses from dispositions of debt securities, gross		600,000	100,000	3,000,000
Equity Securities, FV-NI, Unrealized Gain	2,600,000		96,500,000
Entergy Louisiana [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 561,000,000		$ 561,000,000		534,800,000
Average coupon rate of debt securities	3.85%		3.85%
Average duration of debt securities, years			6 years 6 months 10 days
Average maturity of debt securities, years			13 years 1 month 9 days
Proceeds from the dispositions of debt securities	$ 59,700,000	773,900,000	$ 155,400,000	943,300,000
Gains from dispositions of debt securities, gross	2,500,000	1,900,000	4,200,000	2,500,000
Losses from dispositions of debt securities, gross	29,000	3,600,000	$ 200,000	4,800,000
Percentage Interest in River Bend			30.00%
Equity Securities, FV-NI, Unrealized Gain	6,000,000		$ 137,200,000
System Energy [Member]
Decommissioning Trust Funds [Abstract]
Amortized cost of debt securities	$ 375,600,000		$ 375,600,000		367,100,000
Average coupon rate of debt securities	3.09%		3.09%
Average duration of debt securities, years			6 years 10 months 2 days
Average maturity of debt securities, years			9 years 10 months 17 days
Proceeds from the dispositions of debt securities	$ 108,600,000	157,800,000	$ 238,400,000	357,200,000
Gains from dispositions of debt securities, gross	1,700,000	6,500	3,600,000	300,000
Losses from dispositions of debt securities, gross	200,000	$ 300,000	600,000	$ 4,800,000
Equity Securities, FV-NI, Unrealized Gain	2,500,000		91,800,000
Indian Point 3 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	893,000,000		893,000,000		781,000,000
Indian Point 1 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	534,000,000		534,000,000		471,000,000
Indian Point 2 [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	676,000,000		676,000,000		598,000,000
Palisades [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value	$ 492,000,000		$ 492,000,000		444,000,000
Pilgrim [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					1,028,000,000	$ 1,030,000,000
Vermont Yankee [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value					$ 532,000,000
Entergy Nuclear Generation Company [Member]
Decommissioning Trust Funds [Abstract]
Decommissioning Fund Investments, Fair Value						$ 1,030,000,000

X

- Definition Average coupon rate of debt securities percentage. + References No definition available. + Details Name: etr_AverageCouponRateOfDebtSecuritiesPercentage Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

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- Definition Average Maturity of Debt Securities, Years + References No definition available. + Details Name: etr_AverageMaturityofDebtSecuritiesYears Namespace Prefix: etr_ Data Type: xbrli:durationItemType Balance Type: na Period Type: duration

X

- Definition Decommissioning Trust Funds. + References No definition available. + Details Name: etr_DecommissioningTrustFundsTextualAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Percentage Interest in River Bend + References No definition available. + Details Name: etr_PercentageInterestinRiverBend Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Amount, after tax, of accumulated gain (loss) from increase (decrease) in instrument-specific credit risk of financial liability measured under fair value option. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 825 -SubTopic 10 -Section 50 -Paragraph 30 -Subparagraph (d)(1) -URI http://asc.fasb.org/extlink&oid=75031198&loc=d3e14172-108612 + Details Name: us-gaap_AccumulatedOtherComprehensiveIncomeLossFinancialLiabilityFairValueOptionAfterTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Amortized cost of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 + Details Name: us-gaap_AvailableForSaleDebtSecuritiesAmortizedCostBasis Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition This item represents the gross profit realized on the sale of debt or equity securities categorized neither as held-to-maturity nor trading securities. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesGrossRealizedGains Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition This item represents the gross loss realized on the sale of debt or equity securities categorized neither as held-to-maturity nor trading securities. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesGrossRealizedLosses Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition The fair value of investments held in a trust fund to pay for the costs of decontaminating and decommissioning facilities, whether such amount is presented as a separate caption or as a parenthetical disclosure on the balance sheet. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 410 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849 + Details Name: us-gaap_DecommissioningTrustAssetsAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of unrealized gain on investment in equity security measured at fair value with change in fair value recognized in net income (FV-NI). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 321 -SubTopic 10 -Section 50 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=84241550&loc=SL75117546-209714 + Details Name: us-gaap_EquitySecuritiesFvNiUnrealizedGain Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of tax expense (benefit), after reclassification adjustments, of appreciation (loss) in value of unsold available-for-sale securities. Excludes amounts related to other than temporary impairment (OTTI) loss. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 10A -Subparagraph (e) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669646-108580 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e640-108580 + Details Name: us-gaap_OtherComprehensiveIncomeLossAvailableForSaleSecuritiesTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of cash inflow from sale of investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 45 -Paragraph 11 -URI http://asc.fasb.org/extlink&oid=109979856&loc=d3e26853-111562 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 11 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3151-108585 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_ProceedsFromSaleOfAvailableForSaleSecuritiesDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of investment in debt security measured at fair value with change in fair value recognized in net income (trading). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 45 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109979856&loc=d3e26610-111562 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 45 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=109979856&loc=d3e26610-111562 + Details Name: us-gaap_TradingSecuritiesDebt Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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v3.19.3

Consolidated Statements Of Changes In Equity - USD ($) $ in Thousands	Total	Subsidiaries Preferred Stock [Member]	Paid In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]	Common Stock [Member]	Treasury Stock [Member]	Entergy Texas [Member]	Entergy Texas [Member] Subsidiaries Preferred Stock [Member]	Entergy Texas [Member] Paid In Capital [Member]	Entergy Texas [Member] Retained Earnings [Member]	Entergy Texas [Member] Common Stock [Member]	Entergy Mississippi [Member]	Entergy Arkansas [Member]	Entergy Louisiana [Member]	Entergy Louisiana [Member] Member's Equity [Member]	Entergy Louisiana [Member] Accumulated Other Comprehensive Income [Member]	Entergy New Orleans [Member]	System Energy [Member]	System Energy [Member] Retained Earnings [Member]	System Energy [Member] Common Stock [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 7,992,515	$ 0	$ 5,433,433	$ 7,977,702	$ (23,531)	$ 2,548	$ (5,397,637)	$ 1,260,167	$ 0	$ 596,994	$ 613,721	$ 49,452	$ 1,177,870	$ 2,376,754	$ 5,308,804	$ 5,355,204	$ (46,400)	$ 415,548	$ 710,809	$ 52,459	$ 658,350
Consolidated net income	136,200	3,439	0	132,761	0	0	0	17,350	0	0	17,350	0	22,843	36,255	111,593	111,593	0	10,882	22,308	22,308	0
Dividends, Common Stock, Cash	(160,887)	0	0	(160,887)	0	0	0											(6,250)	(63,240)	(6,740)	(56,500)
Dividends, Preferred Stock, Cash													(238)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	79,145	0	0	0	79,145	0	0								(501)	0	(501)
Common stock issuances related to stock plans	(4,307)	0	16,170	0	0	0	(20,477)
Other															24	24	0
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect	(16,538)	0	0	(32,043)	15,505	0	0								(3,787)	6,262	(10,049)
Consolidated net income	924,877							113,985					111,818	247,701	514,260			50,558	68,667
Proceeds from Contributions from Parent								0						350,000
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(10,317)												(715)	(1,071)
Other comprehensive income (loss)	8,517														(1,502)
Payments for Repurchase of Preferred Stock and Preference Stock	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	7,974,943	0	5,417,263	8,493,790	(561,498)	2,548	(5,377,160)	1,277,517	0	596,994	631,071	49,452	1,200,475	2,412,652	5,416,133	5,473,083	(56,950)	420,180	669,877	68,027	601,850
Consolidated net income	248,860	3,439	0	245,421	0	0	0	30,789	0	0	30,789	0	38,242	82,556	184,358	184,358	0	18,269	23,387	23,387	0
Proceeds from Contributions from Parent														350,000
Dividends, Common Stock, Cash	(160,935)	0	0	(160,935)	0	0	0								(56,000)	(56,000)	0	(8,250)
Dividends, Preferred Stock, Cash													(239)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	(52,144)	0	0	0	(52,144)	0	0								(501)	0	(501)
Common stock issuances related to stock plans	(15,176)	0	(12,141)	0	0	0	(3,035)
Other															(10)	(10)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,022,461	0	5,429,404	8,578,276	(613,642)	2,548	(5,374,125)	1,308,306	0	596,994	661,860	49,452	1,238,478	2,844,851	5,543,980	5,601,431	(57,451)	430,199	693,264	91,414	601,850
Consolidated net income	539,818	3,439	0	536,379	0	0	0	65,846	0	0	65,846	0	50,733	128,890	218,308	218,308	0	21,407	22,972	22,972	0
Dividends, Common Stock, Cash	(161,044)	0	0	(161,044)	0	0	0											(9,250)	(1,240)	(1,240)	0
Dividends, Preferred Stock, Cash													(238)	(357)
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(3,439)	(3,439)	0	0	0	0	0
Other comprehensive income (loss)	(18,484)	0	0	0	(18,484)	0	0								(500)	0	(500)
Common stock issuances related to stock plans	(33,400)	0	(12,292)	0	0	0	(21,108)
Other															(10)	(10)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,412,712	0	5,441,696	8,953,611	(632,126)	2,548	(5,353,017)	1,374,152	0	596,994	727,706	49,452	1,288,973	2,973,384	5,761,778	5,819,729	(57,951)	442,356	714,996	113,146	601,850
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,844,305	0	5,951,431	8,721,150	(557,173)	2,616	(5,273,719)	1,422,402	0	596,994	775,956	49,452	1,292,226	2,983,103	5,902,918	5,909,071	(6,153)	444,950	737,198	135,348	601,850
Consolidated net income	258,646	4,109	0	254,537	0	0	0	21,342	0	0	21,342	0	15,398	39,121	127,633	127,633	0	9,023	23,578	23,578	0
Dividends, Common Stock, Cash	(172,591)	0	0	(172,591)	0	0	0								(49,000)	(49,000)	0		(45,500)	(45,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,109)	(4,109)	0	0	0	0	0
Other comprehensive income (loss)	12,827	0	0	0	12,827	0	0								(969)	0	(969)
Common stock issuances related to stock plans	(31,289)	0	31,248	0	0	0	(62,537)
Other															(11)	(11)	0
Consolidated net income	868,639							133,502					98,302	239,136	565,977			46,934	73,081
Proceeds from Contributions from Parent								87,500						0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(12,328)												0	0
Other comprehensive income (loss)	144,207														(2,907)
Payments for Repurchase of Preferred Stock and Preference Stock	50,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	8,970,367	0	5,920,183	8,809,902	(551,152)	2,616	(5,211,182)	1,443,744	0	596,994	797,298	49,452	1,307,624	3,022,224	5,980,571	5,987,693	(7,122)	453,973	715,276	113,426	601,850
Consolidated net income	240,533	4,109	0	236,424	0	0	0	38,936	0	0	38,936	0	26,667	50,299	183,084	183,084	0	13,003	24,472	24,472	0
Dividends, Common Stock, Cash	(172,861)	0	0	(172,861)	0	0	0							(115,000)	(53,000)	(53,000)	0		(42,500)	(42,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,109)	(4,109)	0	0	0	0	0
Other comprehensive income (loss)	120,748	0	0	0	120,748	0	0								(969)	0	(969)
Stock Issued During Period, Value, New Issues	(607,650)	0	(607,566)	0	0	(84)	0
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs	(7)	0	(7)	0	0	0	0
Common stock issuances related to stock plans	(35,182)	0	(11,791)	0	0	0	(23,391)
Other															(14)	(14)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	9,797,503	0	6,539,533	8,873,465	(430,404)	2,700	(5,187,791)	1,482,680	0	596,994	836,234	49,452	1,334,291	2,957,523	6,109,672	6,117,763	(8,091)	466,976	697,248	95,398	601,850
Consolidated net income	369,459	4,219	0	365,240	0	0	0	73,224	0	0	73,224	0	56,237	149,716	255,260	255,260	0	24,908	25,031	25,031	0
Proceeds from Contributions from Parent								87,500	0	87,500	0	0
Dividends, Common Stock, Cash	(180,956)	0	0	(180,956)	0	0	0	(110)	0	0	(110)	0			(53,000)	(53,000)	0		(22,500)	(22,500)	0
Payments of Ordinary Dividends, Preferred Stock and Preference Stock	(4,219)	(4,219)	0	0	0	0	0
Other comprehensive income (loss)	10,632	0	0	0	10,632	0	0								(969)	0	(969)
Stock Issued During Period, Value, New Issues	(35,000)	(35,000)	0	0	0	0	0	(33,486)	(35,000)	1,514	0	0
Common stock issuances related to stock plans	(42,642)	0	(13,476)	0	0	0	(29,166)
Other															(8)	(8)	0
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	$ 10,070,061	$ 35,000	$ 6,553,009	$ 9,057,749	$ (419,772)	$ 2,700	$ (5,158,625)	$ 1,676,780	$ 35,000	$ 682,980	$ 909,348	$ 49,452	$ 1,390,528	$ 3,107,239	$ 6,310,955	$ 6,320,015	$ (9,060)	$ 491,884	$ 699,779	$ 97,929	$ 601,850

X

- Definition Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings, Tax Effect + References No definition available. + Details Name: etr_TaxCutsandJobsActReclassificationfromAOCItoRetainedEarningsTaxEffect Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of decrease in additional paid in capital (APIC) resulting from direct costs associated with issuing stock. Includes, but is not limited to, legal and accounting fees and direct costs associated with stock issues under a shelf registration. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21463-112644 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.3-04) -URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770 + Details Name: us-gaap_AdjustmentsToAdditionalPaidInCapitalStockIssuedIssuanceCosts Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of paid and unpaid common stock dividends declared with the form of settlement in cash. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.3-04) -URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770 + Details Name: us-gaap_DividendsCommonStockCash Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of paid and unpaid preferred stock dividends declared with the form of settlement in cash. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 405 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=6957935&loc=d3e64057-112817 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.3-04) -URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770 + Details Name: us-gaap_DividendsPreferredStockCash Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition A roll forward is a reconciliation of a concept from the beginning of a period to the end of a period. + References No definition available. + Details Name: us-gaap_IncreaseDecreaseInStockholdersEquityRollForward Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Amount after tax and reclassification adjustments of other comprehensive income (loss). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1A -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669619-108580 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 505 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109259400&loc=d3e21463-112644 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 55 -Paragraph 15 -URI http://asc.fasb.org/extlink&oid=109228884&loc=d3e1436-108581 Reference 4: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1B -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669625-108580 + Details Name: us-gaap_OtherComprehensiveIncomeLossNetOfTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash outflow to reacquire preferred stock during the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_PaymentsForRepurchaseOfPreferredStockAndPreferenceStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cash outflow in the form of ordinary dividends to preferred shareholders of the parent entity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_PaymentsOfDividendsPreferredStockAndPreferenceStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash inflow from parent as a source of financing that is recorded as additional paid in capital. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 14 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3255-108585 + Details Name: us-gaap_ProceedsFromContributionsFromParent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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v3.19.3

Consolidated Statements Of Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575	$ 3,104,319	$ 8,416,367	$ 8,496,970
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	596,939	729,269	1,542,592	1,638,367
Nuclear refueling outage expenses	52,044	37,937	153,447	116,057
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	805,696	854,013	2,430,617	2,477,699
Asset Impairment Charges	198,086	155,215	288,483	297,082
Decommissioning	101,811	93,829	308,557	285,834
Taxes, Other	165,731	161,916	487,715	485,682
Other Depreciation and Amortization	379,219	324,628	1,099,990	1,022,099
Other regulatory charges (credits) - net	4,781	37,097	(38,698)	223,416
Costs and Expenses	2,620,646	2,833,284	7,274,410	7,798,673
OPERATING INCOME	519,929	271,035	1,141,957	698,297
OTHER INCOME
Allowance for equity funds used during construction	33,161	32,354	108,546	92,367
Investment Income, Net	82,295	177,081	406,663	265,086
Miscellaneous - net	(50,086)	(43,591)	(160,614)	(123,439)
TOTAL	65,370	165,844	354,595	234,014
INTEREST EXPENSE
Interest expense	201,412	195,311	603,517	570,548
Allowance for borrowed funds used during construction	(14,773)	(15,244)	(49,034)	(43,177)
TOTAL	186,639	180,067	554,483	527,371
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	398,660	256,812	942,069	404,940
Income taxes	29,201	(283,006)	73,430	(519,937)
Consolidated net income	369,459	539,818	868,639	924,877
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	$ 4,219	$ 3,439	$ 12,438	$ 10,317
Earnings per average common share:
Basic (in dollars per share)	$ 1.84	$ 2.96	$ 4.42	$ 5.06
Diluted (in dollars per share)	$ 1.82	$ 2.92	$ 4.38	$ 5.01
Basic average number of common shares outstanding (in shares)	198,932,387	181,002,303	193,876,557	180,845,440
Diluted average number of common shares outstanding (in shares)	200,492,935	183,664,583	195,685,851	182,692,325
Net Income (Loss) Available to Common Stockholders, Basic	$ 365,240	$ 536,379	$ 856,201	$ 914,560
Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	2,812,934	2,697,887	7,279,683	7,276,374
Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	27,269	26,352	112,916	112,990
Competitive Businesses [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	300,372	380,080	1,023,768	1,107,606
Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	316,339	439,380	1,001,707	1,252,437
Entergy Mississippi [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	87,386	78,533	188,006	207,724
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	69,253	69,936	195,357	193,979
Taxes, Other	26,673	26,024	78,613	75,212
Other Depreciation and Amortization	44,339	37,752	123,145	114,293
Other regulatory charges (credits) - net	5,771	5,487	11,708	133,715
Costs and Expenses	311,708	322,519	820,290	1,014,320
OPERATING INCOME	87,024	45,215	163,423	22,846
OTHER INCOME
Allowance for equity funds used during construction	2,079	2,251	6,341	6,351
Investment Income, Net	462	1	1,011	26
Miscellaneous - net	(1,648)	116	(2,238)	(1,866)
TOTAL	893	2,368	5,114	4,511
INTEREST EXPENSE
Interest expense	15,922	13,950	45,804	41,916
Allowance for borrowed funds used during construction	(892)	(944)	(2,683)	(2,662)
TOTAL	15,030	13,006	43,121	39,254
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	72,887	34,577	125,416	(11,897)
Income taxes	16,650	(16,156)	27,114	(123,715)
Consolidated net income	56,237	50,733	98,302	111,818
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	238	0	715
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	56,237	50,495	98,302	111,103
Entergy Mississippi [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	398,732	367,734	983,713	1,037,166
Entergy Mississippi [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Mississippi [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	78,286	104,787	223,461	289,397
Entergy Arkansas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	109,779	164,438	370,534	379,240
Nuclear refueling outage expenses	17,381	19,062	51,823	61,623
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	188,299	188,882	542,765	536,032
Decommissioning	17,422	15,226	50,351	44,971
Taxes, Other	31,783	27,972	87,327	80,322
Other Depreciation and Amortization	78,594	73,579	231,502	218,261
Other regulatory charges (credits) - net	1,018	(13,758)	(8,873)	(29,378)
Costs and Expenses	505,350	533,614	1,481,846	1,486,095
OPERATING INCOME	182,176	34,785	294,421	127,933
OTHER INCOME
Allowance for equity funds used during construction	3,977	3,735	10,777	12,214
Investment Income, Net	8,788	12,060	19,193	21,352
Miscellaneous - net	(4,286)	(3,063)	(12,704)	(10,815)
TOTAL	8,479	12,732	17,266	22,751
INTEREST EXPENSE
Interest expense	35,454	31,632	104,664	92,315
Allowance for borrowed funds used during construction	(1,641)	(1,739)	(4,384)	(5,737)
TOTAL	33,813	29,893	100,280	86,578
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	156,842	17,624	211,407	64,106
Income taxes	7,126	(111,266)	(27,729)	(183,595)
Consolidated net income	149,716	128,890	239,136	247,701
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	0	357	0	1,071
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	149,716	128,533	239,136	246,630
Entergy Arkansas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	687,526	568,399	1,776,267	1,614,028
Entergy Arkansas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Arkansas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	61,074	58,213	156,417	195,024
Entergy Louisiana [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677	1,206,612	3,297,324	3,308,744
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	259,419	318,987	627,240	700,296
Nuclear refueling outage expenses	14,026	12,969	40,225	38,739
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	249,773	239,230	726,496	724,604
Decommissioning	15,606	13,654	43,544	39,906
Taxes, Other	49,602	44,594	145,942	143,021
Other Depreciation and Amortization	137,891	124,030	394,271	366,950
Other regulatory charges (credits) - net	(29,224)	(1,433)	(90,762)	30,781
Costs and Expenses	894,923	970,094	2,565,106	2,780,746
OPERATING INCOME	336,754	236,518	732,218	527,998
OTHER INCOME
Allowance for equity funds used during construction	14,609	20,423	59,194	57,292
Investment Income, Net	45,237	53,009	166,721	143,137
Miscellaneous - net	(15,067)	(25,782)	(79,717)	(56,217)
TOTAL	44,779	47,650	146,198	144,212
INTEREST EXPENSE
Interest expense	78,350	73,084	230,684	216,762
Allowance for borrowed funds used during construction	(7,041)	(10,168)	(28,145)	(28,382)
TOTAL	71,309	62,916	202,539	188,380
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	310,224	221,252	675,877	483,830
Income taxes	54,964	2,944	109,900	(30,430)
Consolidated net income	255,260	218,308	565,977	514,260
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	255,260	218,308	565,977	514,260
Entergy Louisiana [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	1,221,874	1,196,278	3,252,826	3,263,073
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	9,803	10,334	44,498	45,671
Entergy Louisiana [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	197,830	218,063	678,150	736,449
Entergy New Orleans [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	194,204	200,182	533,191	566,903
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	27,013	54,754	84,963	93,859
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	32,755	30,593	95,305	87,312
Taxes, Other	15,142	15,551	41,819	43,534
Other Depreciation and Amortization	14,756	14,059	43,146	41,756
Other regulatory charges (credits) - net	7,571	5,853	9,716	18,313
Costs and Expenses	165,328	178,638	470,670	499,547
OPERATING INCOME	28,876	21,544	62,521	67,356
OTHER INCOME
Allowance for equity funds used during construction	2,793	1,694	7,769	3,762
Investment Income, Net	109	30	352	330
Miscellaneous - net	(1,019)	(660)	(3,467)	(2,401)
TOTAL	1,883	1,064	4,654	1,691
INTEREST EXPENSE
Interest expense	6,046	5,388	18,001	15,936
Allowance for borrowed funds used during construction	(1,115)	(626)	(3,102)	(1,390)
TOTAL	4,931	4,762	14,899	14,546
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	25,828	17,846	52,276	54,501
Income taxes	920	(3,561)	5,342	3,943
Consolidated net income	24,908	21,407	46,934	50,558
Entergy New Orleans [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	176,738	184,164	464,773	499,584
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	17,466	16,018	68,418	67,319
Entergy New Orleans [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	68,091	57,828	195,721	214,773
Entergy Texas [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	64,211	79,130	129,285	154,925
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	69,937	58,795	190,989	171,317
Taxes, Other	20,870	20,752	60,773	61,461
Other Depreciation and Amortization	38,722	31,365	113,071	93,272
Other regulatory charges (credits) - net	27,662	33,550	66,574	85,064
Costs and Expenses	373,367	377,265	1,024,658	1,029,972
OPERATING INCOME	69,510	99,966	122,273	199,685
OTHER INCOME
Allowance for equity funds used during construction	7,454	2,222	18,948	5,716
Investment Income, Net	486	601	2,542	1,698
Miscellaneous - net	115	468	980	(154)
TOTAL	8,055	3,291	22,470	7,260
INTEREST EXPENSE
Interest expense	21,379	21,760	63,992	65,646
Allowance for borrowed funds used during construction	(3,534)	(1,253)	(9,370)	(3,224)
TOTAL	17,845	20,507	54,622	62,422
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	59,720	82,750	90,121	144,523
Income taxes	(13,504)	16,904	(43,381)	30,538
Consolidated net income	73,224	65,846	133,502	113,985
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	110	0	110	0
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	73,114	65,846	133,392	113,985
Entergy Texas [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	442,877	477,231	1,146,931	1,229,657
Entergy Texas [Member] | Natural Gas, US Regulated [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	0	0	0	0
Entergy Texas [Member] | Electricity, Purchased [Member]
Operation and Maintenance:
Cost of Goods and Services Sold	151,965	153,673	463,966	463,933
System Energy [Member]
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale	23,748	14,484	66,335	44,939
Nuclear refueling outage expenses	8,412	5,906	25,013	12,698
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses	49,533	48,969	147,283	143,003
Decommissioning	8,976	8,626	26,663	25,624
Taxes, Other	7,120	7,106	21,835	21,069
Other Depreciation and Amortization	26,613	4,355	79,761	71,143
Other regulatory charges (credits) - net	(8,016)	7,398	(27,059)	(15,080)
Costs and Expenses	116,386	96,844	339,831	303,396
OPERATING INCOME	29,086	(17,879)	84,754	36,468
OTHER INCOME
Allowance for equity funds used during construction	2,251	2,028	5,518	7,032
Investment Income, Net	8,215	23,738	21,577	33,567
Miscellaneous - net	(1,300)	(1,421)	(4,018)	(4,391)
TOTAL	9,166	24,345	23,077	36,208
INTEREST EXPENSE
Interest expense	8,546	9,753	26,467	28,734
Allowance for borrowed funds used during construction	(551)	(515)	(1,350)	(1,783)
TOTAL	7,995	9,238	25,117	26,951
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest	30,257	(2,772)	82,714	45,725
Income taxes	5,226	(25,744)	9,633	(22,942)
Consolidated net income	25,031	22,972	73,081	68,667
Earnings per average common share:
Net Income (Loss) Available to Common Stockholders, Basic	25,031	22,972	73,081	68,667
System Energy [Member] | Electricity [Member]
REVENUES
Revenue from Contract with Customer, Excluding Assessed Tax	$ 145,472	$ 78,965	$ 424,585	$ 339,864

X

- Definition Amortization of costs deferred during nuclear refueling outages over the estimated period to the next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating cycle without having to be taken off line. + References No definition available. + Details Name: etr_NuclearRefuelingOutageExpenses Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

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v3.19.3

Equity (Tables)	9 Months Ended
	Sep. 30, 2019
Schedule Of Earnings Per Share Basic And Diluted	The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:   For the Three Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $365.2   198.9   $1.84   $536.4   181.0   $2.96 Average dilutive effect of:                       Stock options     0.7   (0.01 )       0.4   (0.01 ) Other equity plans     0.9   (0.01 )       0.8   (0.01 ) Equity forwards     —   —       1.5   (0.02 ) Diluted earnings per share $365.2   200.5   $1.82   $536.4   183.7   $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018.   For the Nine Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $856.2   193.9   $4.42   $914.6   180.8   $5.06 Average dilutive effect of:                       Stock options     0.5   (0.01 )       0.3   (0.01 ) Other equity plans     0.7   (0.02 )       0.7   (0.01 ) Equity forwards     0.6   (0.01 )       0.9   (0.03 ) Diluted earnings per share $856.2   195.7   $4.38   $914.6   182.7   $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018.
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2019 $51,736   ($508,876 )   $26,736   ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 )   —   8,350   3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 )   25,464   (3,079 )   7,472 Net other comprehensive income (loss) for the period (20,103 )   25,464   5,271   10,632 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2018 ($14,874 )   ($589,926 )   ($8,842 )   ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 )   —   (7,173 )   (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397   15,265   5,428   29,090 Net other comprehensive income (loss) for the period (32,004 )   15,265   (1,745 )   (18,484 ) Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2018 ($23,135 )   ($531,922 )   ($2,116 )   ($557,173 ) Implementation of accounting standards (7,685 )   —   879   (6,806 ) Beginning balance, January 1, 2019 ($30,820 )   ($531,922 )   ($1,237 )   ($563,979 )                 Other comprehensive income (loss) before reclassifications 122,481   —   37,724   160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 )   48,510   (4,480 )   (15,998 ) Net other comprehensive income (loss) for the period 62,453   48,510   33,244   144,207 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2017 ($37,477 )   ($531,099 )   $545,045   ($23,531 ) Implementation of accounting standards —   —   (632,617 )   (632,617 ) Beginning balance, January 1, 2018 ($37,477 )   ($531,099 )   ($87,572 )   ($656,148 )                 Other comprehensive income (loss) before reclassifications (31,816 )   —   (50,958 )   (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171   47,404   13,716   91,291 Net other comprehensive income (loss) for the period (1,645 )   47,404   (37,242 )   8,517                 Reclassification pursuant to ASU 2018-02 (7,756 )   (90,966 )   114,227   15,505                 Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location   2019   2018     (In Thousands) Cash flow hedges net unrealized gain (loss)        Power contracts $18,925   ($10,566 ) Competitive business operating revenues    Interest rate swaps (48 )   (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877   (10,629 ) (3,964 )   2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913   ($8,397 )     Pension and other postretirement liabilities        Amortization of prior-service credit $5,325   $5,425 (a)    Amortization of loss (20,919 )   (24,740 ) (a)    Settlement loss (16,630 )   (76 ) (a) Total amortization (32,224 )   (19,391 ) 6,760   4,126 Income taxes Total amortization (net of tax) ($25,464 )   ($15,265 )     Net unrealized investment gain (loss)     Realized gain (loss) $4,872   ($8,589 ) Interest and investment income (1,793 )   3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079   ($5,428 )     Total reclassifications for the period (net of tax) ($7,472 )   ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows:   Amounts reclassified from AOCI   Income Statement Location   2019   2018       (In Thousands)     Cash flow hedges net unrealized gain (loss)              Power contracts $76,129   ($37,913 )   Competitive business operating revenues    Interest rate swaps (145 )   (278 )   Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984   (38,191 )       (15,956 )   8,020   Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028   ($30,171 )                 Pension and other postretirement liabilities              Amortization of prior-service credit $15,977   $16,278   (a)    Amortization of loss (58,888 )   (74,503 )   (a)    Settlement loss (18,685 )   (2,098 )   (a) Total amortization (61,596 )   (60,323 )       13,086   12,919   Income taxes Total amortization (net of tax) ($48,510 )   ($47,404 )                 Net unrealized investment gain (loss)           Realized gain (loss) $7,088   ($21,703 )   Interest and investment income   (2,608 )   7,987   Income taxes Total realized investment gain (loss) (net of tax) $4,480   ($13,716 )                 Total reclassifications for the period (net of tax) $15,998   ($91,291 )     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]
Schedule of Accumulated Other Comprehensive Income (Loss)	The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, July 1,   ($8,091 )   ($57,451 ) Amounts reclassified from accumulated other comprehensive income (loss)   (969 )   (500 ) Net other comprehensive income (loss) for the period   (969 )   (500 ) Ending balance, September 30,   ($9,060 )   ($57,951 )      The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, January 1,   ($6,153 )   ($46,400 ) Amounts reclassified from accumulated other comprehensive income (loss)   (2,907 )   (1,502 ) Net other comprehensive income (loss) for the period   (2,907 )   (1,502 )           Reclassification pursuant to ASU 2018-02   —   (10,049 )           Ending balance, September 30,   ($9,060 )   ($57,951 )
Reclassification out of Accumulated Other Comprehensive Income	Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $1,837   $1,934   (a)    Amortization of loss   (526 )   (1,257 )   (a) Total amortization   1,311   677         (342 )   (177 )   Income taxes Total amortization (net of tax)   969   500                   Total reclassifications for the period (net of tax)   $969   $500     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $5,511   $5,802   (a)    Amortization of loss   (1,578 )   (3,770 )   (a) Total amortization   3,933   2,032         (1,026 )   (530 )   Income taxes Total amortization (net of tax)   2,907   1,502                   Total reclassifications for the period (net of tax)   $2,907   $1,502     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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- Definition Tabular disclosure of an entity's basic and diluted earnings per share calculations, including a reconciliation of numerators and denominators of the basic and diluted per-share computations for income from continuing operations. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 260 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6371337&loc=d3e3550-109257 + Details Name: us-gaap_ScheduleOfEarningsPerShareBasicAndDilutedTableTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Asset Retirement Obligations Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
Entergy Arkansas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
Entergy Louisiana [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
Entergy Mississippi [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
Entergy New Orleans [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
Entergy Texas [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.
System Energy [Member]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) See Note 9 to the financial statements in the Form 10-K for a discussion of asset retirement obligations. The following are updates to that discussion. In the first quarter 2019, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $126.2 million increase in its decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining lives of the units. In the second quarter 2019, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $147.5 million increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost asset that will be depreciated over the remaining useful life of the unit.

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v3.19.3

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	$ 3,140,575			$ 3,104,319			$ 8,416,367	$ 8,496,970
Other Nonoperating Income (Expense)	(50,086)			(43,591)			(160,614)	(123,439)
Income taxes (benefits)	(29,201)			283,006			(73,430)	519,937
Consolidated net income	369,459	$ 240,533	$ 258,646	539,818	$ 248,860	$ 136,200	868,639	924,877
Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	300,372			380,080			1,023,768	1,107,606
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Consolidated net income	(7,472)			(29,090)			15,998	(91,291)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other Nonoperating Income (Expense)	(48)			(63)			(145)	(278)
INCOME (LOSS) BEFORE INCOME TAXES	18,877			(10,629)			75,984	(38,191)
Income taxes (benefits)	(3,964)			2,232			(15,956)	8,020
Consolidated net income	14,913			(8,397)			60,028	(30,171)
Accumulated Net Gain (Loss) from Cash Flow Hedges Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Competitive Businesses [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	18,925			(10,566)			76,129	(37,913)
Accumulated Net Investment Gain (Loss) Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Realized gain (loss)	4,872			(8,589)			7,088	(21,703)
Income taxes (benefits)	(1,793)			3,161			(2,608)	7,987
Consolidated net income	3,079			(5,428)			4,480	(13,716)
Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	5,325			5,425			15,977	16,278
Amortization of loss	(20,919)			(24,740)			(58,888)	(74,503)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement	(16,630)			(76)			(18,685)	(2,098)
INCOME (LOSS) BEFORE INCOME TAXES	(32,224)			(19,391)			(61,596)	(60,323)
Income taxes (benefits)	6,760			4,126			13,086	12,919
Consolidated net income	(25,464)			(15,265)			(48,510)	(47,404)
Entergy Louisiana [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Revenue from Contract with Customer, Excluding Assessed Tax	1,231,677			1,206,612			3,297,324	3,308,744
Other Nonoperating Income (Expense)	(15,067)			(25,782)			(79,717)	(56,217)
Income taxes (benefits)	(54,964)			(2,944)			(109,900)	30,430
Consolidated net income	255,260	$ 183,084	$ 127,633	218,308	$ 184,358	$ 111,593	565,977	514,260
Entergy Louisiana [Member] | Accumulated Defined Benefit Plans Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Amortization of prior-service credit	1,837			1,934			5,511	5,802
Amortization of loss	(526)			(1,257)			(1,578)	(3,770)
INCOME (LOSS) BEFORE INCOME TAXES	1,311			677			3,933	2,032
Income taxes (benefits)	(342)			(177)			(1,026)	(530)
Consolidated net income	$ 969			$ 500			$ 2,907	$ 1,502

X

- Definition Amount of gain (loss) recognized in net periodic benefit (cost) credit of defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(4) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(4) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanAmortizationOfGainsLosses Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of prior service cost (credit) recognized in net periodic benefit cost (credit) of defined benefit plan. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 55 -Paragraph 17 -URI http://asc.fasb.org/extlink&oid=112275985&loc=d3e4179-114921 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(5) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(5) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanAmortizationOfPriorServiceCostCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount of gain (loss) recognized in net periodic benefit (cost) credit from irrevocable action relieving primary responsibility for benefit obligation and eliminating risk related to obligation and assets used to effect settlement. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (h)(7) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e1928-114920 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 715 -SubTopic 20 -Section 50 -Paragraph 6 -Subparagraph (a)(7) -URI http://asc.fasb.org/extlink&oid=108410482&loc=d3e2709-114920 + Details Name: us-gaap_DefinedBenefitPlanRecognizedNetGainLossDueToSettlements1 Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of income (loss) from continuing operations before deduction of income tax expense (benefit) and income (loss) attributable to noncontrolling interest, and addition of income (loss) from equity method investments. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08.(h)(1)(i)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 + Details Name: us-gaap_IncomeLossFromContinuingOperationsBeforeIncomeTaxesMinorityInterestAndIncomeLossFromEquityMethodInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of current income tax expense (benefit) and deferred income tax expense (benefit) pertaining to continuing operations. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 22 -Subparagraph (h) -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8736-108599 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.4-08(h)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 20 -Section 45 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109238882&loc=d3e38679-109324 + Details Name: us-gaap_IncomeTaxExpenseBenefit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Amount before accretion (amortization) of purchase discount (premium) of interest income and dividend income on nonoperating securities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SX 210.5-03.7(a),(b)) -URI http://asc.fasb.org/extlink&oid=115205541&loc=SL114868664-224227 + Details Name: us-gaap_InvestmentIncomeInterestAndDividend Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of income (expense) related to nonoperating activities, classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section S99 -Paragraph 2 -Subparagraph (SX 210.5-03.9) -URI http://asc.fasb.org/extlink&oid=115205541&loc=SL114868664-224227 + Details Name: us-gaap_OtherNonoperatingIncomeExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1A -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669619-108580 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 50 -Paragraph 1A -Subparagraph (a)(1) -URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1B -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669625-108580 Reference 4: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 50 -Paragraph 1A -Subparagraph (c)(1) -URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684 Reference 5: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 22 -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8736-108599 Reference 6: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 55 -Paragraph 4J -URI http://asc.fasb.org/extlink&oid=84234705&loc=SL4591551-111686 Reference 7: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3000-108585 Reference 8: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 45 -Paragraph 19 -URI http://asc.fasb.org/extlink&oid=108774443&loc=SL4569616-111683 Reference 9: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -SubTopic 10 -Section 50 -Paragraph 32 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=115929826&loc=d3e8933-108599 Reference 10: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 810 -SubTopic 10 -Section 55 -Paragraph 4K -URI http://asc.fasb.org/extlink&oid=84234705&loc=SL4591552-111686 + Details Name: us-gaap_ProfitLoss Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_ReclassificationAdjustmentOutOfAccumulatedOtherComprehensiveIncomeLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Amount, excluding tax collected from customer, of revenue from satisfaction of performance obligation by transferring promised good or service to customer. Tax collected from customer is tax assessed by governmental authority that is both imposed on and concurrent with specific revenue-producing transaction, including, but not limited to, sales, use, value added and excise. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 606 -SubTopic 10 -Section 50 -Paragraph 4 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109196051&loc=SL49130543-203045 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 606 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109196051&loc=SL49130539-203045 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 606 -SubTopic 10 -Section 50 -Paragraph 5 -URI http://asc.fasb.org/extlink&oid=109196051&loc=SL49130545-203045 + Details Name: us-gaap_RevenueFromContractWithCustomerExcludingAssessedTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Short-Term Borrowings And The Outstanding Short-Term Borrowings) (Details) $ in Millions	Sep. 30, 2019 USD ($)
Entergy Arkansas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	$ 250
Borrowings	0
Entergy Louisiana [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	450
Borrowings	0
Entergy Mississippi [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	175
Borrowings	0
Entergy New Orleans [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	150
Borrowings	46
Entergy Texas [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	0
System Energy [Member]
Short-term borrowings and the outstanding short-term borrowings
Authorized	200
Borrowings	$ 0

X

- Definition Authorized short-term borrowings. + References No definition available. + Details Name: etr_AuthorizedShortTermBorrowings Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Total amount of money pool and external short-term borrowings. + References No definition available. + Details Name: etr_ShortTermBorrowing Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Short-term borrowings and the outstanding short-term borrowings. + References No definition available. + Details Name: etr_ShortTermBorrowingsAndOutstandingShortTermBorrowingsAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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X

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X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Decommissioning Trust Funds (Securities Held) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 2,462.0	$ 2,495.0
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	114.0	19.0
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	2.0	35.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	407.7	381.3
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	11.8	0.6
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.9	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	593.4	532.9
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	32.6	4.1
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	0.3	6.0
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Fair Value	395.3	364.2
Available-for-sale Securities, Accumulated Gross Unrealized Gain, before Tax	19.7	2.9
Available-for-sale Securities, Accumulated Gross Unrealized Loss, before Tax	$ 0.1	$ 5.8

X

- Definition Amount of investment in debt and equity securities categorized neither as held-to-maturity nor trading. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecurities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount before tax of unrealized gain in accumulated other comprehensive income (AOCI) on investments in debt and equity securities classified as available-for-sale. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27161-111563 + Details Name: us-gaap_AvailableForSaleSecuritiesAccumulatedGrossUnrealizedGainBeforeTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount before tax of unrealized loss in accumulated other comprehensive income (AOCI) on investments in debt and equity securities classified as available-for-sale. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesAccumulatedGrossUnrealizedLossBeforeTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_ScheduleOfAvailableForSaleSecuritiesLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Risk Management and Fair Values (Assets And Liabilities At Fair Value On A Recurring Basis) (Details) - USD ($)		Sep. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		$ 885,436,000	$ 424,285,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		55,000,000	51,000,000
Replacement Reserve Escrow		410,000,000	403,000,000
Equity Securities, FV-NI		836,000,000	1,686,000,000
Debt Securities		2,968,000,000	2,884,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		7,544,000,000	7,818,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			35,000,000
Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		5,000,000	1,000,000
Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			34,000,000
Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities		2,325,000,000	2,350,000,000
Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		48,000,000	3,000,000
Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000	2,000,000
Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		16,000,000	15,000,000
Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		885,000,000	424,000,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		55,000,000	51,000,000
Replacement Reserve Escrow		410,000,000	403,000,000
Equity Securities, FV-NI		836,000,000	1,686,000,000
Debt Securities		1,214,000,000	1,259,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,400,000,000	3,823,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			1,000,000
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		4,000,000	1,000,000
Fair Value Inputs Level 1 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value Inputs Level 1 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI		0	0
Debt Securities		1,754,000,000	1,625,000,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,755,000,000	1,627,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,000,000	0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Fair Value, Inputs, Level 2 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000	2,000,000
Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI		0	0
Debt Securities		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		64,000,000	18,000,000
Financial and Nonfinancial Liabilities, Fair Value Disclosure			34,000,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Fair Value, Inputs, Level 3 [Member] | Power Contracts Liabilities [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			34,000,000
Fair Value, Inputs, Level 3 [Member] | Power Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		48,000,000	3,000,000
Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		16,000,000	15,000,000
Entergy New Orleans [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	19,651,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		5,268,000	2,224,000
Replacement Reserve Escrow		82,200,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		88,200,000	104,100,000
Entergy New Orleans [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		100,000	100,000
Entergy New Orleans [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		700,000	1,300,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			19,700,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		5,300,000	2,200,000
Replacement Reserve Escrow		82,200,000	80,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		87,500,000	102,800,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		100,000	100,000
Entergy New Orleans [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value			0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		700,000	1,300,000
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		700,000	1,300,000
Entergy Mississippi [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		98,925,000	36,943,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		33,000,000.0	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		133,400,000	71,500,000
Entergy Mississippi [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,100,000
Entergy Mississippi [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,500,000	2,200,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		98,900,000	36,900,000
Assets at fair value on a recurring basis
Replacement Reserve Escrow		33,000,000.0	32,400,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		131,900,000	69,300,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,100,000
Entergy Mississippi [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Replacement Reserve Escrow		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,500,000	2,200,000
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,500,000	2,200,000
Entergy Louisiana [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		127,821,000	43,112,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		10,100,000	3,600,000
Replacement Reserve Escrow		294,500,000	289,500,000
Equity Securities, FV-NI	[1]	5,300,000	13,300,000
Debt Securities	[1]	593,400,000	532,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,928,200,000	1,631,400,000
Entergy Louisiana [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		3,600,000	1,100,000
Entergy Louisiana [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	886,900,000	738,800,000
Entergy Louisiana [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,100,000	1,900,000
Entergy Louisiana [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		9,100,000	8,300,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		127,800,000	43,100,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		10,100,000	3,600,000
Replacement Reserve Escrow		294,500,000	289,500,000
Equity Securities, FV-NI	[1]	5,300,000	13,300,000
Debt Securities	[1]	183,700,000	162,000,000.0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		621,500,000	511,500,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		2,200,000	700,000
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		100,000	0
Entergy Louisiana [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	409,700,000	370,900,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		410,700,000	372,800,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		1,400,000	400,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,000,000.0	1,900,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Replacement Reserve Escrow		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		9,100,000	8,300,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts [Member]
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Gas Hedge Contracts Assets [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		9,100,000	8,300,000
Entergy Arkansas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		76,659,000	1,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		7,904,000	4,666,000
Equity Securities, FV-NI	[1]	6,200,000	4,000,000.0
Debt Securities	[1]	407,700,000	381,300,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,134,300,000	920,100,000
Entergy Arkansas [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	631,900,000	526,700,000
Entergy Arkansas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		3,900,000	3,400,000
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		76,700,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		7,900,000	4,700,000
Equity Securities, FV-NI	[1]	6,200,000	4,000,000.0
Debt Securities	[1]	101,400,000	94,800,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		192,200,000	103,500,000
Entergy Arkansas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	306,300,000	286,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		306,300,000	286,500,000
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0	0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		3,900,000	3,400,000
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		3,900,000	3,400,000
Entergy Texas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		92,253,000	30,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		31,649,000	40,185,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		125,200,000
Entergy Texas [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,300,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			500,000
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		92,300,000
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		31,600,000	40,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		123,900,000
Entergy Texas [Member] | Fair Value Inputs Level 1 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		0
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0
Assets at fair value on a recurring basis
Restricted Cash and Cash Equivalents, Current		0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,300,000
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Fixed Transmission Rights (FTRs) [Member]
Assets at fair value on a recurring basis
Derivative Asset		1,300,000
Liabilities at fair value on a recurring basis
Liabilities, Fair Value Disclosure on Recurring Basis			500,000
System Energy [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		164,246,000	95,617,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,800,000	4,400,000
Debt Securities	[1]	395,300,000	364,200,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		1,166,500,000	965,100,000
System Energy [Member] | Common trust funds valued using Net Asset Value [Domain]
Assets at fair value on a recurring basis
Available-for-sale Securities	[2]	601,200,000	500,900,000
System Energy [Member] | Fair Value Inputs Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		164,200,000	95,600,000
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	5,800,000	4,400,000
Debt Securities	[1]	206,000,000.0	224,500,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		376,000,000.0	324,500,000
System Energy [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	189,300,000	139,700,000
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		189,300,000	139,700,000
System Energy [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value		0	0
Assets at fair value on a recurring basis
Equity Securities, FV-NI	[1]	0	0
Debt Securities	[1]	0	0
Liabilities at fair value on a recurring basis
Assets, Fair Value Disclosure		$ 0	$ 0
[1] (a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios. [2] (b) Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

X

- Definition Fair value portion of probable future economic benefits obtained or controlled by an entity as a result of past transactions or events. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_AssetsFairValueDisclosure Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- References No definition available. + Details Name: us-gaap_AssetsFairValueDisclosureAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition Amount of investment in debt and equity securities categorized neither as held-to-maturity nor trading. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecurities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.1) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CashEquivalentsAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of investment in debt security measured at amortized cost (held-to-maturity), investment in debt security measured at fair value with change in fair value recognized in other comprehensive income (available-for-sale) and investment in debt security measured at fair value with change in fair value recognized in net income (trading). + References No definition available. + Details Name: us-gaap_DebtSecurities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Fair value, after the effects of master netting arrangements, of a financial asset or other contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset. Includes assets not subject to a master netting arrangement and not elected to be offset. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 55 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=99393222&loc=SL20226008-175313 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 825 -SubTopic 10 -Section 50 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=109250915&loc=d3e13433-108611 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 50 -Paragraph 3 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=51824906&loc=SL20225862-175312 + Details Name: us-gaap_DerivativeAssets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Fair value, after the effects of master netting arrangements, of a financial liability or contract with one or more underlyings, notional amount or payment provision or both, and the contract can be net settled by means outside the contract or delivery of an asset. Includes liabilities not subject to a master netting arrangement and not elected to be offset. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 50 -Paragraph 3 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=51824906&loc=SL20225862-175312 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 825 -SubTopic 10 -Section 50 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=109250915&loc=d3e13433-108611 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 55 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=99393222&loc=SL20226008-175313 + Details Name: us-gaap_DerivativeLiabilities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of investment in equity security measured at fair value with change in fair value recognized in net income (FV-NI). + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 825 -SubTopic 10 -Section 45 -Paragraph 1A -URI http://asc.fasb.org/extlink&oid=99377092&loc=SL75136599-209740 + Details Name: us-gaap_EquitySecuritiesFvNi Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_FairValueAssetsAndLiabilitiesMeasuredOnRecurringAndNonrecurringBasisLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Fair value of financial and nonfinancial obligations. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 820 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=99377789&loc=d3e19207-110258 + Details Name: us-gaap_LiabilitiesFairValueDisclosure Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- References No definition available. + Details Name: us-gaap_LiabilitiesFairValueDisclosureAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition This element represents those amounts set aside for the repair and replacement of real or personal property in the foreseen future. Such amount may be funded from sales revenue (for example; timeshare sales) or operating revenues; in a lump sum or installments (such as monthly); as per internal policy (for example: hotel operators), as required by contractual agreement (for example: sales contract); or by the terms of debt agreements. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03.2,10) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_ReplacementReserveEscrow Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of cash and cash equivalents restricted as to withdrawal or usage, classified as current. Cash includes, but is not limited to, currency on hand, demand deposits with banks or financial institutions, and other accounts with general characteristics of demand deposits. Cash equivalents include, but are not limited to, short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6676-107765 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3044-108585 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(1)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 50 -Paragraph 8 -URI http://asc.fasb.org/extlink&oid=98513485&loc=SL98516268-108586 + Details Name: us-gaap_RestrictedCashAndCashEquivalentsAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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v3.19.3

Risk Management and Fair Values (Narrative) (Details) TWh in Millions, $ in Millions	3 Months Ended			9 Months Ended		12 Months Ended
	Dec. 31, 2019 TWh	Sep. 30, 2019 USD ($) GWh MMBTU	Sep. 30, 2018 USD ($)	Sep. 30, 2019 USD ($) GWh MMBTU	Sep. 30, 2018 USD ($)	Dec. 31, 2018 USD ($) counterparty
Risk Management and Fair Values [Abstract]
Cash flow hedges relating to power sales as part of net unrealized gains				$ 42.0
Reclassified from accumulated other comprehensive income (OCI) to operating revenues				30.0
Maturity of cash flow hedges, Tax		$ 4.0	$ (2.0)	$ 16.0	$ (8.0)
Maximum length of time over which Company is currently hedging the variability in future cash flows for forecasted power transactions, years				1 year 6 months
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		40,346,000		40,346,000
Total volume of fixed transmission rights outstanding | GWh		79,459		79,459
Change in cash flow hedges due to ineffectiveness			(3.1)		(5.2)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset and Liability Unrealized Gains (Loss) Included in Earnings		$ (1.2)	$ 1.7	$ (4.7)	$ 1.1
Entergy Arkansas [Member]
Risk Management and Fair Values [Abstract]
Total volume of fixed transmission rights outstanding | GWh		17,898		17,898
Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		32,880,000		32,880,000
Total volume of fixed transmission rights outstanding | GWh		36,474		36,474
Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount		$ 0.2		$ 0.2		$ 0.2
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		6,210,000		6,210,000
Total volume of fixed transmission rights outstanding | GWh		10,087		10,087
Entergy New Orleans [Member]
Risk Management and Fair Values [Abstract]
Total volume of natural gas swaps outstanding (MMBtu) | MMBTU		1,256,000		1,256,000
Total volume of fixed transmission rights outstanding | GWh		3,751		3,751
Entergy Texas [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount						4.1
Total volume of fixed transmission rights outstanding | GWh		10,931		10,931
Gas Hedge Contracts [Member] | Entergy Louisiana [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				4 years 6 months
Gas Hedge Contracts [Member] | Entergy Mississippi [Member]
Risk Management and Fair Values [Abstract]
Maximum Length of Time Hedged in Cash Flow Hedge				6 months
Entergy Wholesale Commodities [Member]
Risk Management and Fair Values [Abstract]
Cash collateral posted		$ 13.0		$ 13.0		$ 19.0
Derivative, Collateral, Obligation to Return Cash		2.0		2.0
Letters of Credit Held		$ 48.0		$ 48.0
Number of Derivative Contract Counterparties in a Liability Position | counterparty						6
Dollar amount of hedge contract in a liability position						$ 34.0
Utility [Member]
Risk Management and Fair Values [Abstract]
Letters of Credit Outstanding, Amount						$ 4.0
Subsequent Event [Member]
Risk Management and Fair Values [Abstract]
Planned generation sold forward from non utility nuclear power plants for the remainder of the period	97.00%
Planned Generation From Non Nuclear Power Plants Sold Forward Under Financial Hedges	72.00%
Total planned generation for remainder of the period | TWh	6.1

X

- Definition Derivative Instruments Gain Loss Reclassified From Accumulated OCI Into Income Effective Portion, Tax. + References No definition available. + Details Name: etr_DerivativeInstrumentsGainLossReclassifiedFromAccumulatedOCIIntoIncomeEffectivePortionTax Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Dollar amount of hedge contract in a liability position. + References No definition available. + Details Name: etr_HedgeContractsInLiabilityPosition Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Letters of credit posted to Entergy by its counterparties + References No definition available. + Details Name: etr_LettersofCreditHeld Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Maximum length of time over which Company is currently hedging the variability in future cash flows with derivatives for forecasted power transactions. + References No definition available. + Details Name: etr_MaximumlengthoftimeoverwhichCompanyiscurrentlyhedgingthevariabilityinfuturecashflowsforforecastedpowertransactions Namespace Prefix: etr_ Data Type: xbrli:durationItemType Balance Type: na Period Type: duration

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- Definition Number of Derivative Contract Counterparties in a Liability Position + References No definition available. + Details Name: etr_NumberofDerivativeContractCounterpartiesinaLiabilityPosition Namespace Prefix: etr_ Data Type: xbrli:integerItemType Balance Type: na Period Type: duration

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- Definition Planned generation from non nuclear power plants sold forward under financial hedges for remainder of the period + References No definition available. + Details Name: etr_PlannedGenerationFromNonNuclearPowerPlantsSoldForwardUnderFinancialHedges Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

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- Definition Planned generation sold forward from non utility nuclear power plants for the remainder of the period + References No definition available. + Details Name: etr_Plannedgenerationsoldforwardfromnonutilitynuclearpowerplantsfortheremainderoftheperiod Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

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- Definition Risk Management and Fair Values. + References No definition available. + Details Name: etr_RiskManagementAndFairValuesTextualAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Total planned generation for remainder of the period + References No definition available. + Details Name: etr_Totalplannedgenerationforremainderoftheperiod Namespace Prefix: etr_ Data Type: num:energyItemType Balance Type: na Period Type: duration

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- Definition Total volume of natural gas swaps outstanding. + References No definition available. + Details Name: etr_VolumeOfNaturalGasSwapsOutstanding Namespace Prefix: etr_ Data Type: num:energyItemType Balance Type: na Period Type: instant

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- Definition Volume of Financial Transmission Rights Outstanding + References No definition available. + Details Name: etr_VolumeofFinancialTransmissionRightsOutstanding Namespace Prefix: etr_ Data Type: num:energyItemType Balance Type: na Period Type: instant

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- Definition The estimated net amount of existing gains or losses on cash flow hedges at the reporting date expected to be reclassified to earnings within the next 12 months. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=112277219&loc=d3e80748-113994 + Details Name: us-gaap_CashFlowHedgeGainLossToBeReclassifiedWithinTwelveMonths Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The aggregate fair value of assets that are already posted, at the end of the reporting period, as collateral for derivative instruments with credit-risk-related contingent features. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4H -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5624258-113959 + Details Name: us-gaap_CollateralAlreadyPostedAggregateFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of obligation to return cash collateral under master netting arrangements that have not been offset against derivative assets. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 55 -Paragraph 13 -URI http://asc.fasb.org/extlink&oid=99393222&loc=SL20226016-175313 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 8 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109980867&loc=d3e41678-113959 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 20 -Section 50 -Paragraph 3 -Subparagraph (d)(2) -URI http://asc.fasb.org/extlink&oid=51824906&loc=SL20225862-175312 + Details Name: us-gaap_DerivativeCollateralObligationToReturnCash Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The net gain (loss) recognized in earnings during the period due to ineffectiveness in price risk cash flow hedges. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 10 -Section 50 -Paragraph 4C -Subparagraph (d)(1) -URI http://asc.fasb.org/extlink&oid=109980867&loc=SL5624171-113959 + Details Name: us-gaap_GainLossOnPriceRiskCashFlowHedgeIneffectiveness Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Maximum length of time over which the entity is hedging its exposure to the variability in future cash flows for forecasted transactions, excluding those forecasted transactions related to the payment of variable interest on existing financial instruments, in 'PnYnMnDTnHnMnS' format, for example, 'P1Y5M13D' represents the reported fact of one year, five months, and thirteen days. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 815 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (d) -URI http://asc.fasb.org/extlink&oid=112277219&loc=d3e80748-113994 + Details Name: us-gaap_MaximumLengthOfTimeHedgedInCashFlowHedge1 Namespace Prefix: us-gaap_ Data Type: xbrli:durationItemType Balance Type: na Period Type: duration

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v3.19.3

Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Summary Of The Borrowings Outstanding And Capacity Available Under The Facility	Following is a summary of the borrowings outstanding and capacity available under the facility as of September 30, 2019. Capacity   Borrowings   Letters of Credit   Capacity Available (In Millions) $3,500   $155   $6   $3,339
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]
Credit Facilities	Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of September 30, 2019 as follows: Company   Expiration Date   Amount of Facility   Interest Rate (a)   Amount Drawn as of September 30, 2019   Letters of Credit Outstanding as of September 30, 2019 Entergy Arkansas   April 2020   $20 million (b)   3.17%   $—   $— Entergy Arkansas   September 2024   $150 million (c)   3.17%   $—   $— Entergy Louisiana   September 2024   $350 million (c)   3.17%   $—   $— Entergy Mississippi   May 2020   $37.5 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $35 million (d)   3.54%   $—   $— Entergy Mississippi   May 2020   $10 million (d)   3.54%   $—   $— Entergy New Orleans   November 2021   $25 million (c)   3.32%   $—   $0.8 million Entergy Texas   September 2024   $150 million (c)   3.54%   $—   $1.3 million (a) The interest rate is the estimated interest rate as of September 30, 2019 that would have been applied to outstanding borrowings under the facility. (b) Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. (c) The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. (d) Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.
Uncommitted Standby Letter of Credit Facilities to Support MISO Obligations [Table Text Block]	Following is a summary of the uncommitted standby letter of credit facilities as of September 30, 2019: Company   Amount of Uncommitted Facility   Letter of Credit Fee   Letters of Credit Issued as of September 30, 2019 (a) Entergy Arkansas   $25 million   0.70%   $1 million Entergy Louisiana   $125 million   0.70%   $11.7 million Entergy Mississippi   $65 million   0.70%   $8.1 million Entergy New Orleans   $15 million   1.00%   $1 million Entergy Texas   $50 million   0.70%   $26.2 million (a) As of September 30, 2019, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein for discussion of financial transmission rights.
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]
Short-Term Borrowings And The Outstanding Short-Term Borrowings	The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of September 30, 2019 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:   Authorized   Borrowings   (In Millions) Entergy Arkansas $250   $— Entergy Louisiana $450   $— Entergy Mississippi $175   $— Entergy New Orleans $150   $46 Entergy Texas $200   $— System Energy $200   $—
Issuance Of Commercial Paper To Finance Acquisition And Ownership Of Nuclear Fuel	To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs have commercial paper programs in place. Following is a summary as of September 30, 2019: Company   Expiration Date   Amount of Facility   Weighted Average Interest Rate on Borrowings (a)   Amount Outstanding as of September 30, 2019       (Dollars in Millions) Entergy Arkansas VIE   September 2021   $80   3.41%   $30.3 Entergy Louisiana River Bend VIE   September 2021   $105   3.37%   $84.3 Entergy Louisiana Waterford VIE   September 2021   $105   3.41%   $65.5 System Energy VIE   September 2021   $120   3.42%   $53.6 (a) Includes letter of credit fees and bank fronting fees on commercial paper issuances, if any, by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company variable interest entity for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Notes Payable By Variable Interest Entities	The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective balance sheets as of September 30, 2019 as follows: Company   Description   Amount Entergy Arkansas VIE   3.65% Series L due July 2021   $90 million Entergy Arkansas VIE   3.17% Series M due December 2023   $40 million Entergy Louisiana River Bend VIE   3.38% Series R due August 2020   $70 million Entergy Louisiana Waterford VIE   3.92% Series H due February 2021   $40 million Entergy Louisiana Waterford VIE   3.22% Series I due December 2023   $20 million System Energy VIE   3.42% Series J due April 2021   $100 million
Book Value And The Fair Value Of Long-Term Debt	The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of September 30, 2019 are as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $17,458,026   $18,628,268 Entergy Arkansas $3,538,384   $3,621,073 Entergy Louisiana $7,344,160   $8,038,675 Entergy Mississippi $1,469,454   $1,586,199 Entergy New Orleans $478,619   $522,688 Entergy Texas $1,938,303   $2,128,842 System Energy $570,001   $554,374 (a) The fair value excludes lease obligations of $34 million at System Energy and long-term DOE obligations of $190 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein. The book value and the fair value of long-term debt for Entergy Corporation and the Registrant Subsidiaries as of December 31, 2018 were as follows:   Book Value of Long-Term Debt   Fair Value of Long-Term Debt (a) (b)   (In Thousands) Entergy $16,168,312   $15,880,239 Entergy Arkansas $3,225,759   $3,002,627 Entergy Louisiana $6,805,768   $6,834,134 Entergy Mississippi $1,325,750   $1,276,452 Entergy New Orleans $483,704   $491,569 Entergy Texas $1,513,735   $1,528,828 System Energy $630,750   $596,123 (a) The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $187 million at Entergy Arkansas, and include debt due within one year. (b) Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

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- Definition Summary of borrowings outstanding and capacity available under facility. + References No definition available. + Details Name: etr_SummaryOfBorrowingsOutstandingAndCapacityAvailableUnderFacilityTableTextBlock Namespace Prefix: etr_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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v3.19.3

Leases Leases	9 Months Ended
	Sep. 30, 2019
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Arkansas [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Louisiana [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Mississippi [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy New Orleans [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
Entergy Texas [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352
System Energy [Member]
Leases	LEASES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy implemented ASU 2016-02, “Leases (Topic 842),” effective January 1, 2019. The ASU’s core principle is that “a lessee should recognize the assets and liabilities that arise from leases.” The ASU considers that “all leases create an asset and a liability,” and accordingly requires recording the assets and liabilities related to all leases with a term greater than 12 months. Concurrent with the implementation of ASU 2016-02, Entergy implemented ASU 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” which provided Entergy the option to elect not to evaluate existing land easements that are not currently accounted for under the previous lease standard, and ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” which intended to simplify the transition requirement giving Entergy the option to apply the transition provisions of the new standard at the date of adoption instead of at the earliest comparative period. In implementing these ASUs, Entergy elected the options provided in both ASU 2018-01 and ASU 2018-11. This accounting was applied to all lease agreements using the modified retrospective method, which required an adjustment to retained earnings for the cumulative effect of adopting the standard as of the effective date, and when implemented with ASU 2018-11, allowed Entergy to recognize the leased assets and liabilities on its balance sheet beginning on January 1, 2019 without restating prior periods. In adopting the standard, in January 2019 Entergy recognized right-of-use assets and corresponding lease liabilities totaling approximately $263 million, including $59 million for Entergy Arkansas, $51 million for Entergy Louisiana, $26 million for Entergy Mississippi, $7 million for Entergy New Orleans, and $16 million for Entergy Texas. Implementation of the standards had no material effect on consolidated net income; therefore, no adjustment to retained earnings was recorded. The adoption of the standards had no effect on cash flows. General As of September 30, 2019, Entergy and the Registrant Subsidiaries held operating and financing leases for fleet vehicles used in operations, real estate, and aircraft. Excluded from this are power purchase agreements not meeting the definition of a lease, nuclear fuel leases, and the Grand Gulf sale-leaseback which were determined not to be leases. Leases have remaining terms of one year to 52 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications which would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor; however, due to the nature of the agreements and Entergy’s continuing relationship with the lessor, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. Entergy incurred the following total lease costs for the three months ended September 30, 2019:     (In Thousands) Operating lease cost   $16,086 Financing lease cost:     Amortization of right-of-use assets   $2,945 Interest on lease liabilities   $763 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the three months ended September 30, 2019. Entergy incurred the following total lease costs for the nine months ended September 30, 2019:     (In Thousands) Operating lease cost   $47,061 Financing lease cost:     Amortization of right-of-use assets   $10,837 Interest on lease liabilities   $2,597 Of the lease costs disclosed above, Entergy had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by Entergy for leases with all costs included within operating activities on the Consolidated Statements of Cash Flows, except for the financing lease costs which are included in financing activities. The Registrant Subsidiaries incurred the following lease costs for the three months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $3,306   $3,003   $1,752   $349   $1,074 Financing lease cost:                   Amortization of right-of-use assets $621   $1,014   $369   $178   $335 Interest on lease liabilities $105   $161   $65   $29   $54 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the three months ended September 30, 2019. The Registrant Subsidiaries incurred the following lease costs for the nine months ended September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating lease cost $9,724   $8,854   $5,220   $1,058   $3,135 Financing lease cost:                   Amortization of right-of-use assets $2,448   $4,014   $1,408   $696   $965 Interest on lease liabilities $408   $612   $241   $114   $153 Of the lease costs disclosed above, Entergy Louisiana had $15 thousand in short-term lease costs for the nine months ended September 30, 2019. The lease costs disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the financing lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Property, Plant, and Equipment on Entergy’s consolidated balance sheet at September 30, 2019 are $236 million related to operating leases and $60 million related to financing leases. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019 are the following amounts:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Operating leases $49,503   $34,248   $18,149   $3,894   $13,074 Financing leases $11,094   $16,795   $6,994   $2,913   $5,515 The following lease-related liabilities are recorded within the respective Other lines on Entergy’s consolidated balance sheet as of September 30, 2019:     (In Thousands) Current liabilities:     Operating leases   $52,348 Financing leases   $11,482 Non-current liabilities:     Operating leases   $184,404 Financing leases   $53,252 The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas   (In Thousands) Current liabilities:                   Operating leases $10,662   $9,969   $6,137   $1,138   $3,427 Financing leases $2,600   $3,860   $1,473   $626   $1,252 Non-current liabilities:                 Operating leases $38,881   $24,289   $12,254   $2,755   $9,689 Financing leases $8,665   $12,925   $5,521   $2,286   $4,221 The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of Entergy at September 30, 2019: Weighted average remaining lease terms:     Operating leases   5.10 Financing leases   6.79 Weighted average discount rate:     Operating leases   3.91 % Financing leases   4.67 % The following information contains the weighted average remaining lease term in years and the weighted average discount rate for the operating and financing leases of the Registrant Subsidiaries at September 30, 2019:   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     Weighted average remaining lease terms:                   Operating leases 6.09   4.28   4.65   3.99   4.49 Financing leases 5.44   5.41   5.41   5.72   5.25 Weighted average discount rate:                   Operating leases 3.75 %   3.74 %   3.77 %   3.94 %   3.86 % Financing leases 3.75 %   3.75 %   3.71 %   3.93 %   3.84 % Maturity of the lease liabilities for Entergy as of September 30, 2019 are as follows: Year   Operating Leases   Financing Leases     (In Thousands)           Remainder for 2019   $16,088   $3,608 2020   59,965   13,521 2021   53,791   11,973 2022   45,391   10,775 2023   35,050   9,664 Years thereafter   56,906   26,889 Minimum lease payments   267,191   76,430 Less: amount representing interest   30,438   11,696 Present value of net minimum lease payments   $236,753   $64,734 Maturity of the lease liabilities for the Registrant Subsidiaries as of September 30, 2019 are as follows: Operating Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $3,168   $2,863   $1,968   $332   $1,022 2020   11,756   10,518   6,066   1,196   4,014 2021   9,911   8,787   4,937   939   3,279 2022   7,613   6,068   3,503   659   2,338 2023   6,341   4,079   1,376   497   1,994 Years thereafter   16,421   4,702   2,642   729   2,193 Minimum lease payments   55,210   37,017   20,492   4,352   14,840 Less: amount representing interest   5,667   2,759   2,101   459   1,724 Present value of net minimum lease payments   $49,543   $34,258   $18,391   $3,893   $13,116 Financing Leases Year   Entergy Arkansas   Entergy Louisiana   Entergy Mississippi   Entergy New Orleans   Entergy Texas     (In Thousands)                       Remainder of 2019   $713   $1,135   $429   $204   $375 2020   2,654   4,191   1,655   660   1,364 2021   2,258   3,536   1,490   549   1,171 2022   1,969   3,096   1,297   499   965 2023   1,728   2,635   1,078   451   827 Years thereafter   2,905   3,818   1,740   881   1,316 Minimum lease payments   12,227   18,411   7,689   3,244   6,018 Less: amount representing interest   961   1,626   695   332   545 Present value of net minimum lease payments   $11,266   $16,785   $6,994   $2,912   $5,473 In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations, fuel storage agreements, and purchased power agreements and to allocate the contract consideration to both lease and non-lease components for real estate leases. In accordance with ASU 2018-11, below is the lease disclosure from Note 10 to the financial statements in the Form 10-K. General As of December 31, 2018, Entergy had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf sale and leaseback transaction, all of which are discussed elsewhere):   Year   Operating Leases   Capital Leases     (In Thousands) 2019   $94,043   $2,887 2020   82,191   2,887 2021   75,147   2,887 2022   60,808   2,887 2023   47,391   2,887 Years thereafter   88,004   16,117 Minimum lease payments   447,584   30,552 Less:  Amount representing interest   —   8,555 Present value of net minimum lease payments   $447,584   $21,997 Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $47.8 million in 2018, $53.1 million in 2017, and $44.4 million in 2016. As of December 31, 2018, the Registrant Subsidiaries had non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase agreement operating leases, nuclear fuel leases, and the Grand Gulf lease obligation, all of which are discussed elsewhere): Operating Leases     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     (In Thousands) 2019   $20,421   $25,970   $9,344   $2,493   $5,744 2020   13,918   21,681   8,763   2,349   4,431 2021   11,931   19,514   7,186   1,901   3,625 2022   9,458   15,756   5,675   1,314   2,218 2023   7,782   12,092   2,946   1,043   1,561 Years thereafter   23,297   22,003   4,417   2,323   2,726 Minimum lease payments   $86,807   $117,016   $38,331   $11,423   $20,305 Rental Expenses     Year     Entergy Arkansas     Entergy Louisiana     Entergy Mississippi   Entergy New Orleans     Entergy Texas     System Energy     (In Millions) 2018   $6.2   $20.2   $4.6   $2.5   $3.1   $1.9 2017   $7.5   $23.0   $5.6   $2.5   $3.4   $2.2 2016   $8.0   $17.8   $4.0   $0.9   $2.8   $1.6 In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory treatment.  Railcar operating lease payments were $2.8 million in 2018, $4 million in 2017, and $3.4 million in 2016 for Entergy Arkansas and $0.4 million in 2018, $0.3 million in 2017, and $0.3 million in 2016 for Entergy Louisiana.  Oil tank facilities lease payments for Entergy Mississippi were $0.1 million in 2018, $1.6 million in 2017, and $1.6 million in 2016. On January 1, 2019, Entergy implemented ASU No. 2016-02, “Leases (Topic 842)” along with the practical expedients provided by ASU No. 2018-01, “Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842,” and ASU No. 2018-11, “Leases (Topic 842): Targeted Improvements.”  See Note 1 to the financial statements in the Form 10-K for further discussion of ASU No. 2016-02. Power Purchase Agreements As of December 31, 2018, Entergy Texas had a power purchase agreement that is accounted for as an operating lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory treatment. The minimum lease payments under the power purchase agreement are as follows: Year   Entergy Texas (a)   Entergy     (In Thousands) 2019   $31,159   $31,159 2020   31,876   31,876 2021   32,609   32,609 2022   10,180   10,180 Minimum lease payments   $105,824   $105,824 (a) Amounts reflect 100% of minimum payments. Under a separate contract, which expires May 31, 2022, Entergy Louisiana purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas. Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was $30.5 million in 2018, $34.1 million in 2017, and $26.1 million in 2016. Sales and Leaseback Transactions Waterford 3 Lease Obligation In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back undivided interests in Waterford 3 for the aggregate sum of $353.6 million.  The leases were scheduled to expire in July 2017.  Entergy Louisiana was required to report the sale-leaseback as a financing transaction in its financial statements. In December 2015, Entergy Louisiana agreed to purchase the undivided interests in Waterford 3 that were previously being leased. The purchase was accomplished in a two-step transaction in which Entergy Louisiana first acquired the equity participant’s beneficial interest in the leased assets, followed by a termination of the leases and transfer of the leased assets to Entergy Louisiana when the outstanding lessor debt is paid. In March 2016, Entergy Louisiana completed the first step in the two-step transaction by acquiring the equity participant’s beneficial interest in the leased assets. Entergy Louisiana paid $60 million in cash and $52 million through the issuance of a non-interest bearing collateral trust mortgage note, payable in installments through July 2017. Entergy Louisiana continued to make payments on the lessor debt that remained outstanding and which matured in January 2017. The combination of payments on the $52 million collateral trust mortgage note issued and the debt service on the lessor debt was equal in timing and amount to the remaining lease payments due from the closing of the transaction through the end of the lease term in July 2017. Throughout the term of the lease, Entergy Louisiana had accrued a liability for the amount it expected to pay to retain the use of the undivided interests in Waterford 3 at the end of the lease term. Since the sale-leaseback transaction was accounted for as a financing transaction, the accrual of this liability was accounted for as additional interest expense. As of December 2015, the balance of this liability was $62.7 million. Upon entering into the agreement to purchase the equity participant’s beneficial interest in the undivided interests, Entergy Louisiana reduced the balance of the liability to $60 million, and recorded the $2.7 million difference as a credit to interest expense. The $60 million remaining liability was eliminated upon payment of the cash portion of the purchase price in 2016. As of December 31, 2016, Entergy Louisiana, in connection with the Waterford 3 lease obligation, had a future minimum lease payment (reflecting an interest rate of 8.09%) of $57.5 million, including $2.3 million in interest, due January 2017 that was recorded as long-term debt. In February 2017 the leases were terminated and the leased assets were conveyed to Entergy Louisiana. Grand Gulf Lease Obligations In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million.  The initial term of the leases expired in July 2015.  System Energy renewed the leases in December 2013 for fair market value with renewal terms expiring in July 2036. At the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf or renew the leases at fair market value.  In the event that System Energy does not renew or purchase the interests, System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy. System Energy is required to report the sale-leaseback as a financing transaction in its financial statements.  For financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant depreciation.  However, operating revenues include the recovery of the lease payments because the transactions are accounted for as a sale and leaseback for ratemaking purposes.  Consistent with a recommendation contained in a FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of the lease term.  The amount was a net regulatory liability of $55.6 million as of December 31, 2018 and 2017. As of December 31, 2018, System Energy, in connection with the Grand Gulf sale and leaseback transactions, had future minimum lease payments that are recorded as long-term debt, as follows, which reflects the effect of the December 2013 renewal:   Amount   (In Thousands)     2019 $17,188 2020 17,188 2021 17,188 2022 17,188 2023 17,188 Years thereafter 223,437 Total 309,377 Less: Amount representing interest 275,025 Present value of net minimum lease payments $34,352

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v3.19.3

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income	$ 369,459	$ 539,818	$ 868,639	$ 924,877
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)	(20,103)	(32,004)	62,453	(1,645)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	25,464	15,265	48,510	47,404
Net unrealized investment gains	5,271	(1,745)	33,244	(37,242)
Other comprehensive income (loss)	10,632	(18,484)	144,207	8,517
Total comprehensive income	380,091	521,334	1,012,846	933,394
Net Income (Loss) Attributable to Noncontrolling Interest, Preferred Unit Holders	4,219	3,439	12,438	10,317
Comprehensive Income Attributable to Entergy Corporation	375,872	517,895	1,000,408	923,077
Entergy Louisiana [Member]
Net income	255,260	218,308	565,977	514,260
Other comprehensive income (loss)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax	(969)	(500)	(2,907)	(1,502)
Other comprehensive income (loss)	(969)	(500)	(2,907)	(1,502)
Total comprehensive income	$ 254,291	$ 217,808	$ 563,070	$ 512,758

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- Definition Amount after tax of increase (decrease) in equity from transactions and other events and circumstances from net income and other comprehensive income, attributable to parent entity. Excludes changes in equity resulting from investments by owners and distributions to owners. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 5 -URI http://asc.fasb.org/extlink&oid=114867106&loc=d3e557-108580 Reference 2: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1B -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669625-108580 Reference 3: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 220 -SubTopic 10 -Section 45 -Paragraph 1A -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=114867106&loc=SL7669619-108580 + Details Name: us-gaap_ComprehensiveIncomeNetOfTax Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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v3.19.3

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Proceeds from Sale of Productive Assets	$ 19,801	$ 12,915
OPERATING ACTIVITIES
Consolidated net income	868,639	924,877
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	1,634,677	1,517,344
Deferred income taxes, investment tax credits, and non-current taxes accrued	373,723	82,641
Impairment of Long-Lived Assets Held-for-use	225,175	210,263
Changes in working capital:
Receivables	(231,005)	(153,703)
Fuel inventory	(14,399)	49,728
Accounts payable	(175,246)	79,949
Taxes accrued	(2,420)	43,510
Interest accrued	(2,314)	(9,398)
Deferred fuel costs	90,319	(25,284)
Other working capital accounts	(19,232)	(86,063)
Changes in provisions for estimated losses	14,114	28,599
Changes in other regulatory assets	(92,861)	207,135
Increase (Decrease) in Regulatory Liabilities	(19,115)	(413,684)
Changes in pensions and other postretirement liabilities	(132,044)	(345,526)
Other Noncash Income (Expense)	(400,064)	(250,884)
Net cash flow provided by operating activities	2,117,947	1,859,504
INVESTING ACTIVITIES
Construction/capital expenditures	(3,079,726)	(2,883,047)
Allowance for equity funds used during construction	108,867	92,829
Nuclear fuel purchases	(55,176)	(170,819)
Payments for Nuclear Fuel	(55,176)	(170,819)
Payments to storm reserve escrow account	(6,184)	(4,515)
Decrease (increase) in other investments	30,370	(36,140)
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	2,369	0
Proceeds from nuclear decommissioning trust fund sales	3,518,616	4,177,919
Investment in nuclear decommissioning trust funds	(3,566,690)	(4,187,161)
Proceeds from insurance	7,040	10,523
Changes in securitization account	(4,213)	(12,985)
Net cash flow used in investing activities	(3,024,926)	(3,000,481)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	7,133,571	5,604,131
Proceeds from Issuance of Preferred Stock and Preference Stock	33,486	0
Common stock and treasury stock	89,303	24,646
Proceeds from Issuance of Common Stock	607,650	0
Retirement of long-term debt	(5,859,714)	(4,181,820)
Changes in credit borrowings and commercial paper - net	(24,550)	368,370
Payments for Repurchase of Preferred Stock and Preference Stock	50,000	0
Dividends paid:
Common stock	(526,408)	(482,865)
Preferred stock	(12,328)	(10,317)
Other	(9,175)	25,540
Net cash flow provided by financing activities	1,381,835	1,347,685
Net increase in cash and cash equivalents	474,856	206,708
Cash and cash equivalents at beginning of period	480,975	781,273
Cash and cash equivalents at end of period	955,831	987,981
Cash paid / (received) during the period for:
Interest - net of amount capitalized	584,622	558,381
Income taxes	(8,649)	18,200
Entergy Arkansas [Member]
OPERATING ACTIVITIES
Consolidated net income	239,136	247,701
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	351,390	335,939
Deferred income taxes, investment tax credits, and non-current taxes accrued	85,246	28,463
Changes in working capital:
Receivables	(70,395)	(33,422)
Fuel inventory	(5,350)	7,523
Accounts payable	(24,766)	(20,904)
Taxes accrued	(18,608)	30,686
Interest accrued	20,206	13,558
Deferred fuel costs	52,468	24,463
Other working capital accounts	44,803	(8,827)
Changes in provisions for estimated losses	8,841	10,013
Changes in other regulatory assets	(55,749)	22,574
Increase (Decrease) in Regulatory Liabilities	32,537	(218,518)
Changes in pensions and other postretirement liabilities	(26,136)	(64,461)
Other Noncash Income (Expense)	(57,011)	(12,203)
Net cash flow provided by operating activities	576,612	362,585
INVESTING ACTIVITIES
Construction/capital expenditures	(488,487)	(517,882)
Allowance for equity funds used during construction	11,016	12,572
Change in money pool receivable - net	(6,896)	(13,421)
Nuclear fuel purchases	(26,732)	(79,142)
Payments for Nuclear Fuel	(26,732)	(79,142)
Proceeds from sale of nuclear fuel	22,834	31,897
Change in other investments	(1)	1
Proceeds from nuclear decommissioning trust fund sales	199,031	259,331
Investment in nuclear decommissioning trust funds	(214,205)	(269,913)
Proceeds from insurance	0	7,043
Changes in securitization account	(3,238)	(4,821)
Net cash flow used in investing activities	(506,676)	(574,337)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	781,510	658,427
Retirement of long-term debt	(473,827)	(372,447)
Change in money pool payable - net	(182,738)	(166,137)
Changes in credit borrowings and commercial paper - net	0	(49,974)
Dividends paid:
Common stock	(115,000)	0
Preferred stock	0	(1,071)
Other	(2,931)	8,520
Net cash flow provided by financing activities	7,014	427,318
Net increase in cash and cash equivalents	76,950	215,566
Cash and cash equivalents at beginning of period	119	6,216
Cash and cash equivalents at end of period	77,069	221,782
Cash paid / (received) during the period for:
Interest - net of amount capitalized	80,644	74,966
Proceeds from Contributions from Parent	0	350,000
Entergy Louisiana [Member]
OPERATING ACTIVITIES
Consolidated net income	565,977	514,260
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	498,397	490,638
Deferred income taxes, investment tax credits, and non-current taxes accrued	174,825	167,603
Changes in working capital:
Receivables	(72,018)	(61,281)
Fuel inventory	(1,752)	6,120
Accounts payable	(40,131)	(20,481)
Taxes accrued	78,910	(22,893)
Interest accrued	5,102	2,382
Deferred fuel costs	(11,459)	(25,781)
Other working capital accounts	(62,332)	(5,086)
Changes in provisions for estimated losses	9,748	7,800
Changes in other regulatory assets	(103,635)	49,245
Increase (Decrease) in Regulatory Liabilities	(26,115)	(29,943)
Changes in pensions and other postretirement liabilities	(15,761)	(59,305)
Other Noncash Income (Expense)	(37,313)	(69,978)
Net cash flow provided by operating activities	962,443	943,300
INVESTING ACTIVITIES
Construction/capital expenditures	(1,277,108)	(1,322,633)
Allowance for equity funds used during construction	59,194	57,292
Change in money pool receivable - net	35,485	(2,444)
Nuclear fuel purchases	(63,157)	(32,362)
Payments for Nuclear Fuel	(63,157)	(32,362)
Proceeds from sale of nuclear fuel	11,608	54,088
Payments to storm reserve escrow account	(5,013)	(3,297)
Proceeds from nuclear decommissioning trust fund sales	307,164	943,306
Investment in nuclear decommissioning trust funds	(331,138)	(973,218)
Proceeds from insurance	7,040	3,480
Changes in securitization account	(6,467)	(8,056)
Payment For Proceed From Other Investing Activities	2,369	0
Net cash flow used in investing activities	(1,260,023)	(1,283,844)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	2,332,003	1,950,482
Retirement of long-term debt	(1,798,014)	(1,338,227)
Changes in credit borrowings and commercial paper - net	0	(43,540)
Dividends paid:
Common stock	(155,000)	(56,000)
Other	3,272	5,507
Net cash flow provided by financing activities	382,261	518,222
Net increase in cash and cash equivalents	84,681	177,678
Cash and cash equivalents at beginning of period	43,364	35,907
Cash and cash equivalents at end of period	128,045	213,585
Cash paid / (received) during the period for:
Interest - net of amount capitalized	219,323	208,028
Income taxes	0	(2,973)
Entergy Mississippi [Member]
OPERATING ACTIVITIES
Consolidated net income	98,302	111,818
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	123,145	114,293
Deferred income taxes, investment tax credits, and non-current taxes accrued	32,596	40,537
Changes in working capital:
Receivables	(37,843)	(49,456)
Fuel inventory	(3,872)	33,705
Accounts payable	(574)	(9,845)
Taxes accrued	(26,556)	(24,280)
Interest accrued	2,093	(4,767)
Deferred fuel costs	47,569	9,826
Other working capital accounts	533	(8,348)
Changes in provisions for estimated losses	(3,099)	7,894
Changes in other regulatory assets	(923)	26,060
Increase (Decrease) in Regulatory Liabilities	(16,615)	(139,063)
Changes in pensions and other postretirement liabilities	(6,930)	(15,987)
Other Noncash Income (Expense)	(4,387)	125,637
Net cash flow provided by operating activities	203,439	218,024
INVESTING ACTIVITIES
Construction/capital expenditures	(314,622)	(275,189)
Allowance for equity funds used during construction	6,341	6,351
Change in money pool receivable - net	32,481	1,633
Decrease (increase) in other investments	(507)	(960)
Net cash flow used in investing activities	(276,307)	(268,165)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	292,763	0
Retirement of long-term debt	(150,000)	0
Change in money pool payable - net	0	33,816
Dividends paid:
Preferred stock	0	(715)
Other	(7,913)	10,989
Net cash flow provided by financing activities	134,850	44,090
Net increase in cash and cash equivalents	61,982	(6,051)
Cash and cash equivalents at beginning of period	36,954	6,096
Cash and cash equivalents at end of period	98,936	45
Cash paid / (received) during the period for:
Interest - net of amount capitalized	41,753	44,781
Entergy New Orleans [Member]
OPERATING ACTIVITIES
Consolidated net income	46,934	50,558
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	43,146	41,756
Deferred income taxes, investment tax credits, and non-current taxes accrued	20,427	25,605
Changes in working capital:
Receivables	(14,741)	(15,310)
Fuel inventory	(374)	495
Accounts payable	(11,654)	8,868
Taxes accrued	242	(8,743)
Interest accrued	14	564
Deferred fuel costs	8,328	(59)
Other working capital accounts	(8,737)	(5,062)
Changes in provisions for estimated losses	1,423	417
Changes in other regulatory assets	(14,435)	19,068
Increase (Decrease) in Regulatory Liabilities	(15,371)	(5,353)
Changes in pensions and other postretirement liabilities	(5,784)	(12,956)
Other Noncash Income (Expense)	28,015	479
Net cash flow provided by operating activities	77,433	100,327
INVESTING ACTIVITIES
Construction/capital expenditures	(162,177)	(142,585)
Allowance for equity funds used during construction	7,769	3,762
Change in money pool receivable - net	22,016	10,607
Payments to storm reserve escrow account	(1,382)	(905)
Receipts from storm reserve escrow account	0	3
Changes in securitization account	(3,043)	(4,115)
Net cash flow used in investing activities	(136,817)	(133,233)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	0	59,590
Retirement of long-term debt	(5,420)	(5,342)
Change in money pool payable - net	46,318	0
Dividends paid:
Common stock	0	(23,750)
Other	(1,165)	2,587
Net cash flow provided by financing activities	39,733	33,085
Net increase in cash and cash equivalents	(19,651)	179
Cash and cash equivalents at beginning of period	19,677	32,741
Cash and cash equivalents at end of period	26	32,920
Cash paid / (received) during the period for:
Interest - net of amount capitalized	17,211	14,584
Income taxes	(4,899)	0
Entergy Texas [Member]
OPERATING ACTIVITIES
Consolidated net income	133,502	113,985
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	113,071	93,272
Deferred income taxes, investment tax credits, and non-current taxes accrued	21,898	640
Changes in working capital:
Receivables	21,578	(40,287)
Fuel inventory	(1,476)	1,045
Accounts payable	(58,792)	(12,864)
Taxes accrued	3,545	24,476
Interest accrued	(11,478)	(6,084)
Deferred fuel costs	(6,588)	(33,734)
Other working capital accounts	(13,740)	891
Changes in provisions for estimated losses	(3,470)	1,006
Changes in other regulatory assets	63,793	64,311
Increase (Decrease) in Regulatory Liabilities	(83,674)	15,313
Changes in pensions and other postretirement liabilities	(7,209)	(20,999)
Other Noncash Income (Expense)	3,921	(3,294)
Net cash flow provided by operating activities	174,881	197,677
INVESTING ACTIVITIES
Construction/capital expenditures	(622,342)	(291,118)
Allowance for equity funds used during construction	19,029	5,820
Proceeds from Sale of Other Assets, Investing Activities	0	3,753
Change in money pool receivable - net	(8,299)	43,686
Changes in securitization account	8,535	4,009
Net cash flow used in investing activities	(603,077)	(233,850)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	986,477	0
Proceeds from Issuance of Preferred Stock and Preference Stock	33,486	0
Retirement of long-term debt	(563,246)	(60,500)
Change in money pool payable - net	(22,389)	0
Dividends paid:
Other	(1,410)	1,657
Net cash flow provided by financing activities	520,418	(58,843)
Net increase in cash and cash equivalents	92,222	(95,016)
Cash and cash equivalents at beginning of period	56	115,513
Cash and cash equivalents at end of period	92,278	20,497
Cash paid / (received) during the period for:
Interest - net of amount capitalized	73,752	69,669
Income taxes	2,292	(624)
Proceeds from Contributions from Parent	87,500	0
System Energy [Member]
OPERATING ACTIVITIES
Consolidated net income	73,081	68,667
Adjustments to reconcile consolidated net income to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization	163,069	133,877
Deferred income taxes, investment tax credits, and non-current taxes accrued	(2,426)	14,159
Changes in working capital:
Receivables	(7,456)	20,806
Accounts payable	2,935	22,637
Taxes accrued	14,579	(1,017)
Interest accrued	(1,478)	2,311
Other working capital accounts	3,411	(52,524)
Changes in other regulatory assets	(9,121)	(4,773)
Increase (Decrease) in Regulatory Liabilities	90,118	(36,119)
Changes in pensions and other postretirement liabilities	(5,013)	(11,629)
Other Noncash Income (Expense)	(97,024)	(24,839)
Net cash flow provided by operating activities	224,675	131,556
INVESTING ACTIVITIES
Construction/capital expenditures	(92,228)	(166,458)
Allowance for equity funds used during construction	5,518	7,032
Change in money pool receivable - net	92,347	95,302
Nuclear fuel purchases	(2,046)	(110,485)
Payments for Nuclear Fuel	(2,046)	(110,485)
Proceeds from sale of nuclear fuel	26,272	12,867
Proceeds from nuclear decommissioning trust fund sales	348,606	357,209
Investment in nuclear decommissioning trust funds	(362,573)	(365,040)
Net cash flow used in investing activities	15,896	(169,573)
Proceeds from the issuance of:
Proceeds from the issuance of long-term debt	1,007,775	211,985
Retirement of long-term debt	(1,069,206)	(124,304)
Changes in credit borrowings and commercial paper - net	0	(17,830)
Dividends paid:
Common stock	(110,500)	(64,480)
Net cash flow provided by financing activities	(171,931)	5,371
Net increase in cash and cash equivalents	68,640	(32,646)
Cash and cash equivalents at beginning of period	95,685	287,187
Cash and cash equivalents at end of period	164,325	254,541
Cash paid / (received) during the period for:
Interest - net of amount capitalized	$ 21,052	$ 10,308

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- Definition Change in money pool payable - net. + References No definition available. + Details Name: etr_ChangeInMoneyPoolPayableNet Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Change in money pool receivable - net. + References No definition available. + Details Name: etr_ChangeInMoneyPoolReceivableNet Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Change in other investments + References No definition available. + Details Name: etr_Changeinotherinvestments Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Changes in credit line borrowings net. + References No definition available. + Details Name: etr_ChangesInCreditLineBorrowingsNet Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Changes In Working Capital. + References No definition available. + Details Name: etr_ChangesInWorkingCapitalAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Changes in the account in which recoveries from customers through a transition charge are deposited and from which payments are made to service the securitization bonds issued by the entity's securitization company + References No definition available. + Details Name: etr_Changesinsecuritizationaccount Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow. + References No definition available. + Details Name: etr_ConsolidatedNetIncomeAdjustmentsToReconcileConsolidatedNetIncomeToNetCashFlowAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Dividends Paid. + References No definition available. + Details Name: etr_DividendsPaidAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Litigation proceeds for reimbursement of spent nuclear fuel storage costs. + References No definition available. + Details Name: etr_LitigationProceedsForReimbursementOfSpentNuclearFuelStorageCosts Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The net cash outflow (inflow) from other investing activities. This element is used when there is not a more specific and appropriate element in the taxonomy. + References No definition available. + Details Name: etr_PaymentForProceedFromOtherInvestingActivities Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Proceeds From Issuance Of. + References No definition available. + Details Name: etr_ProceedsFromIssuanceOfAbstract Namespace Prefix: etr_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition The net cash inflow from any material that is commonly used in the generation of nuclear energy. + References No definition available. + Details Name: etr_ProceedsFromSaleLeasebackOfNuclearFuel Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Cash inflow due to change during the period in the allowance for other funds used during construction classified as an investing activity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -SubTopic 360 -Section 25 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6500269&loc=d3e45485-110386 + Details Name: us-gaap_AllowanceForFundsUsedDuringConstructionInvestingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Excludes cash and cash equivalents within disposal group and discontinued operation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3044-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=82887183&loc=d3e6676-107765 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.1) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details Name: us-gaap_CashAndCashEquivalentsAtCarryingValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of increase (decrease) in cash and cash equivalents. Cash and cash equivalents are the amount of currency on hand as well as demand deposits with banks or financial institutions. Includes other kinds of accounts that have the general characteristics of demand deposits. Also includes short-term, highly liquid investments that are both readily convertible to known amounts of cash and so near their maturity that they present insignificant risk of changes in value because of changes in interest rates. Includes effect from exchange rate changes. + References No definition available. + Details Name: us-gaap_CashAndCashEquivalentsPeriodIncreaseDecrease Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of deferred income tax expense (benefit) and income tax credits. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_DeferredIncomeTaxesAndTaxCredits Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The aggregate net amount of depreciation, amortization, and accretion recognized during an accounting period. As a noncash item, the net amount is added back to net income when calculating cash provided by or used in operations using the indirect method. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_DepreciationAmortizationAndAccretionNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The aggregate amount of write-downs for impairments recognized during the period for long lived assets held for use (including those held for disposal by means other than sale). + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109226691&loc=d3e2921-110230 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 958 -SubTopic 220 -Section 45 -Paragraph 11 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=114873921&loc=SL114875236-224282 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109226348&loc=d3e2420-110228 + Details Name: us-gaap_ImpairmentOfLongLivedAssetsHeldForUse Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The amount of cash paid during the current period to foreign, federal, state, and local authorities as taxes on income, net of any cash received during the current period as refunds for the overpayment of taxes. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=98513485&loc=d3e4297-108586 + Details Name: us-gaap_IncomeTaxesPaidNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The increase (decrease) during the reporting period in the aggregate amount of liabilities incurred (and for which invoices have typically been received) and payable to vendors for goods and services received that are used in an entity's business. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInAccountsPayable Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The increase (decrease) during the period in the amount due for taxes based on the reporting entity's earnings or attributable to the entity's income earning process (business presence) within a given jurisdiction. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInAccruedIncomeTaxesPayable Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The increase (decrease) during the reporting period in carrying amount of capitalized fuel costs of a regulated entity that are expected to be recoverable through rate adjustments within one year or the normal operating cycle, if longer. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInDeferredFuelCosts Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The increase (decrease) during the reporting period in the value of fuel held in inventory. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInFuelInventories Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The increase (decrease) during the reporting period in interest payable, which represents the amount owed to note holders, bond holders, and other parties for interest earned on loans or credit extended to the reporting entity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInInterestPayableNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of increase (decrease) in operating assets after deduction of operating liabilities classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInOtherOperatingCapitalNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The increase (decrease) during the reporting period in the value of other assets that are created when regulatory agencies permits public utilities to defer costs to the balance sheet. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInOtherRegulatoryAssets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of increase (decrease) in obligation for pension and other postretirement benefits. Includes, but is not limited to, defined benefit and defined contribution plans. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInPensionAndPostretirementObligations Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The increase (decrease) during the reporting period in the total amount due within one year (or one operating cycle) from all parties, associated with underlying transactions that are classified as operating activities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInReceivables Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The increase (decrease) during the reporting period in regulated liabilities. Regulated liabilities are created when regulatory agency permits an entity to defer revenues to the balance sheet. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_IncreaseDecreaseInRegulatoryLiabilities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of cash paid for interest capitalized, classified as investing activity. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=98513485&loc=d3e4297-108586 + Details Name: us-gaap_InterestPaidCapitalized Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cash inflow (outflow) from financing activities, including discontinued operations. Financing activity cash flows include obtaining resources from owners and providing them with a return on, and a return of, their investment; borrowing money and repaying amounts borrowed, or settling the obligation; and obtaining and paying for other resources obtained from creditors on long-term credit. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 24 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3521-108585 + Details Name: us-gaap_NetCashProvidedByUsedInFinancingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of cash inflow (outflow) from investing activities, including discontinued operations. Investing activity cash flows include making and collecting loans and acquiring and disposing of debt or equity instruments and property, plant, and equipment and other productive assets. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 24 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3521-108585 + Details Name: us-gaap_NetCashProvidedByUsedInInvestingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- References No definition available. + Details Name: us-gaap_NetCashProvidedByUsedInInvestingActivitiesAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Amount of cash inflow (outflow) from operating activities, including discontinued operations. Operating activity cash flows include transactions, adjustments, and changes in value not defined as investing or financing activities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 25 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3536-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 24 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3521-108585 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_NetCashProvidedByUsedInOperatingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: na Period Type: duration

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- References No definition available. + Details Name: us-gaap_NetCashProvidedByUsedInOperatingActivitiesAbstract Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Definition Amount of income (expense) included in net income that results in no cash inflow (outflow), classified as other. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_OtherNoncashIncomeExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash outflow for acquisition of or capital improvements to properties held for investment (operating, managed, leased) or for use. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 + Details Name: us-gaap_PaymentsForCapitalImprovements Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Cash outflow associated with the purchase of any material that is commonly used in the generation of nuclear energy. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 + Details Name: us-gaap_PaymentsForNuclearFuel Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cash (inflow) outflow from investing activities classified as other. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section S99 -Paragraph 3 -Subparagraph (SX 210.12-04(a)) -URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e24072-122690 Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_PaymentsForProceedsFromOtherInvestingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash outflow to reacquire preferred stock during the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_PaymentsForRepurchaseOfPreferredStockAndPreferenceStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cash outflow in the form of ordinary dividends to common shareholders of the parent entity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_PaymentsOfDividendsCommonStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Amount of cash outflow in the form of ordinary dividends to preferred shareholders of the parent entity. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 15 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3291-108585 + Details Name: us-gaap_PaymentsOfDividendsPreferredStockAndPreferenceStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash outflow to acquire investments (not to include restricted cash) that are pledged or subject to withdrawal restrictions. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 + Details Name: us-gaap_PaymentsToAcquireRestrictedInvestments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash outflow for the purchase of investments that will be held in a decommissioning trust fund. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 13 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3213-108585 + Details Name: us-gaap_PaymentsToInvestInDecommissioningFund Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The cash inflow from parent as a source of financing that is recorded as additional paid in capital. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 14 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3255-108585 + Details Name: us-gaap_ProceedsFromContributionsFromParent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The cash inflow from the sale of assets held in a decommissioning trust fund. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_ProceedsFromDecommissioningFund Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of cash inflow for proceeds from settlement of insurance claim, classified as investing activities. Excludes insurance settlement classified as operating activities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 21B -URI http://asc.fasb.org/extlink&oid=109223946&loc=SL94080549-108585 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_ProceedsFromInsuranceSettlementInvestingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Proceeds from issuance of capital stock which provides for a specific dividend that is paid to the shareholders before any dividends to common stockholders and which takes precedence over common stockholders in the event of liquidation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 14 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3255-108585 + Details Name: us-gaap_ProceedsFromIssuanceOfPreferredStockAndPreferenceStock Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of cash inflow from the sale of other assets recognized in investing activities. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_ProceedsFromSaleOfOtherAssetsInvestingActivities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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v3.19.3

Property, Plant, And Equipment	9 Months Ended
	Sep. 30, 2019
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
Entergy Arkansas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
Entergy Louisiana [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
Entergy Mississippi [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
Entergy New Orleans [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
Entergy Texas [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.
System Energy [Member]
Property, Plant, And Equipment	PROPERTY, PLANT, AND EQUIPMENT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Construction Expenditures in Accounts Payable Construction expenditures included in accounts payable at September 30, 2019 are $306 million for Entergy, $41.7 million for Entergy Arkansas, $74 million for Entergy Louisiana, $14.7 million for Entergy Mississippi, $13.9 million for Entergy New Orleans, $81.6 million for Entergy Texas, and $24.6 million for System Energy.  Construction expenditures included in accounts payable at December 31, 2018 are $311 million for Entergy, $35.7 million for Entergy Arkansas, $104.6 million for Entergy Louisiana, $13.6 million for Entergy Mississippi, $5.8 million for Entergy New Orleans, $55.6 million for Entergy Texas, and $26.3 million for System Energy.

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v3.19.3

Business Segment Information	9 Months Ended
	Sep. 30, 2019
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Arkansas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Louisiana [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Mississippi [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy New Orleans [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
Entergy Texas [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.
System Energy [Member]
Business Segment Information	BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy Corporation Entergy’s reportable segments as of September 30, 2019 are Utility and Entergy Wholesale Commodities.  Utility includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana.  Entergy Wholesale Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.  “All Other” includes the parent company, Entergy Corporation, and other business activity. Entergy’s segment financial information for the third quarters of 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $2,840,222   $300,363   $9   ($19 )   $3,140,575 Income taxes   $71,698   ($30,855 )   ($11,642 )   $—   $29,201 Consolidated net income (loss)   $581,964   ($140,501 )   ($40,105 )   ($31,899 )   $369,459 2018                     Operating revenues   $2,724,279   $380,080   $—   ($40 )   $3,104,319 Income taxes   ($137,035 )   ($135,659 )   ($10,312 )   $—   ($283,006 ) Consolidated net income (loss)   $507,745   $105,571   ($41,601 )   ($31,897 )   $539,818 Entergy’s segment financial information for the nine months ended September 30, 2019 and 2018 is as follows:     Utility   Entergy Wholesale Commodities   All Other   Eliminations   Entergy     (In Thousands) 2019                     Operating revenues   $7,392,641   $1,023,757   $11   ($42 )   $8,416,367 Income taxes   $81,283   $25,763   ($33,616 )   $—   $73,430 Consolidated net income (loss)   $1,150,863   ($68,804 )   ($117,725 )   ($95,695 )   $868,639 Total assets as of September 30, 2019   $48,348,371   $4,122,007   $501,983   ($2,466,093 )   $50,506,268 2018                     Operating revenues   $7,389,477   $1,107,606   $—   ($113 )   $8,496,970 Income taxes   ($325,134 )   ($166,882 )   ($27,921 )   $—   ($519,937 ) Consolidated net income (loss)   $1,104,078   $31,456   ($114,962 )   ($95,695 )   $924,877 Total assets as of December 31, 2018   $44,777,167   $5,459,275   $733,366   ($2,694,742 )   $48,275,066 The Entergy Wholesale Commodities business is sometimes referred to as the “competitive businesses.”  Eliminations are primarily intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment. As discussed in Note 13 to the financial statements in the Form 10-K, Entergy management has undertaken a strategy to manage and reduce the risk of the Entergy Wholesale Commodities business, which includes taking actions to shut down and sell all of the remaining plants in the merchant nuclear fleet. These decisions and transactions resulted in asset impairments; employee retention and severance expenses and other benefits-related costs; and contracted economic development contributions. Total restructuring charges for the third quarters of 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of July 1, $181   $14   $195   $143   $14   $157 Restructuring costs accrued 14   —   14   43   —   43 Cash paid out 86   —   86   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $8 million in the third quarter 2019 and $155 million in the third quarter 2018 of impairment and other related charges associated with these strategic decisions and transactions. Total restructuring charges for the nine months ended September 30, 2019 and 2018 were comprised of the following:   2019   2018   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   Employee retention and severance expenses and other benefits-related costs   Contracted economic development costs   Total   (In Millions) Balance as of January 1, $179   $14   $193   $83   $14   $97 Restructuring costs accrued 70   —   70   103   —   103 Cash paid out 140   —   140   —   —   — Balance as of September 30, $109   $14   $123   $186   $14   $200 In addition, Entergy Wholesale Commodities incurred $98 million in the nine months ended September 30, 2019 and $297 million in the nine months ended September 30, 2018 of impairment and other related charges associated with these strategic decisions and transactions. Going forward, Entergy Wholesale Commodities expects to incur employee retention and severance expenses associated with management’s strategy to exit the merchant power business of approximately $100 million in 2019, of which $70 million has been incurred as of September 30, 2019, and a total of approximately $135 million from 2020 through 2022. Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business.  Each of the Registrant Subsidiaries’ operations is managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results.

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- Definition The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 280 -URI http://asc.fasb.org/topic&trid=2134510 + Details Name: us-gaap_SegmentReportingDisclosureTextBlock Namespace Prefix: us-gaap_ Data Type: nonnum:textBlockItemType Balance Type: na Period Type: duration

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Equity	9 Months Ended
	Sep. 30, 2019
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:   For the Three Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $365.2   198.9   $1.84   $536.4   181.0   $2.96 Average dilutive effect of:                       Stock options     0.7   (0.01 )       0.4   (0.01 ) Other equity plans     0.9   (0.01 )       0.8   (0.01 ) Equity forwards     —   —       1.5   (0.02 ) Diluted earnings per share $365.2   200.5   $1.82   $536.4   183.7   $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018.   For the Nine Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $856.2   193.9   $4.42   $914.6   180.8   $5.06 Average dilutive effect of:                       Stock options     0.5   (0.01 )       0.3   (0.01 ) Other equity plans     0.7   (0.02 )       0.7   (0.01 ) Equity forwards     0.6   (0.01 )       0.9   (0.03 ) Diluted earnings per share $856.2   195.7   $4.38   $914.6   182.7   $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018. Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018. Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million. In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million. Treasury Stock During the nine months ended September 30, 2019, Entergy Corporation issued 1,582,916 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2019. Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2019 $51,736   ($508,876 )   $26,736   ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 )   —   8,350   3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 )   25,464   (3,079 )   7,472 Net other comprehensive income (loss) for the period (20,103 )   25,464   5,271   10,632 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2018 ($14,874 )   ($589,926 )   ($8,842 )   ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 )   —   (7,173 )   (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397   15,265   5,428   29,090 Net other comprehensive income (loss) for the period (32,004 )   15,265   (1,745 )   (18,484 ) Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2018 ($23,135 )   ($531,922 )   ($2,116 )   ($557,173 ) Implementation of accounting standards (7,685 )   —   879   (6,806 ) Beginning balance, January 1, 2019 ($30,820 )   ($531,922 )   ($1,237 )   ($563,979 )                 Other comprehensive income (loss) before reclassifications 122,481   —   37,724   160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 )   48,510   (4,480 )   (15,998 ) Net other comprehensive income (loss) for the period 62,453   48,510   33,244   144,207 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2017 ($37,477 )   ($531,099 )   $545,045   ($23,531 ) Implementation of accounting standards —   —   (632,617 )   (632,617 ) Beginning balance, January 1, 2018 ($37,477 )   ($531,099 )   ($87,572 )   ($656,148 )                 Other comprehensive income (loss) before reclassifications (31,816 )   —   (50,958 )   (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171   47,404   13,716   91,291 Net other comprehensive income (loss) for the period (1,645 )   47,404   (37,242 )   8,517                 Reclassification pursuant to ASU 2018-02 (7,756 )   (90,966 )   114,227   15,505                 Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, July 1,   ($8,091 )   ($57,451 ) Amounts reclassified from accumulated other comprehensive income (loss)   (969 )   (500 ) Net other comprehensive income (loss) for the period   (969 )   (500 ) Ending balance, September 30,   ($9,060 )   ($57,951 )      The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, January 1,   ($6,153 )   ($46,400 ) Amounts reclassified from accumulated other comprehensive income (loss)   (2,907 )   (1,502 ) Net other comprehensive income (loss) for the period   (2,907 )   (1,502 )           Reclassification pursuant to ASU 2018-02   —   (10,049 )           Ending balance, September 30,   ($9,060 )   ($57,951 )      Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location   2019   2018     (In Thousands) Cash flow hedges net unrealized gain (loss)        Power contracts $18,925   ($10,566 ) Competitive business operating revenues    Interest rate swaps (48 )   (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877   (10,629 ) (3,964 )   2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913   ($8,397 )     Pension and other postretirement liabilities        Amortization of prior-service credit $5,325   $5,425 (a)    Amortization of loss (20,919 )   (24,740 ) (a)    Settlement loss (16,630 )   (76 ) (a) Total amortization (32,224 )   (19,391 ) 6,760   4,126 Income taxes Total amortization (net of tax) ($25,464 )   ($15,265 )     Net unrealized investment gain (loss)     Realized gain (loss) $4,872   ($8,589 ) Interest and investment income (1,793 )   3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079   ($5,428 )     Total reclassifications for the period (net of tax) ($7,472 )   ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows:   Amounts reclassified from AOCI   Income Statement Location   2019   2018       (In Thousands)     Cash flow hedges net unrealized gain (loss)              Power contracts $76,129   ($37,913 )   Competitive business operating revenues    Interest rate swaps (145 )   (278 )   Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984   (38,191 )       (15,956 )   8,020   Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028   ($30,171 )                 Pension and other postretirement liabilities              Amortization of prior-service credit $15,977   $16,278   (a)    Amortization of loss (58,888 )   (74,503 )   (a)    Settlement loss (18,685 )   (2,098 )   (a) Total amortization (61,596 )   (60,323 )       13,086   12,919   Income taxes Total amortization (net of tax) ($48,510 )   ($47,404 )                 Net unrealized investment gain (loss)           Realized gain (loss) $7,088   ($21,703 )   Interest and investment income   (2,608 )   7,987   Income taxes Total realized investment gain (loss) (net of tax) $4,480   ($13,716 )                 Total reclassifications for the period (net of tax) $15,998   ($91,291 )     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $1,837   $1,934   (a)    Amortization of loss   (526 )   (1,257 )   (a) Total amortization   1,311   677         (342 )   (177 )   Income taxes Total amortization (net of tax)   969   500                   Total reclassifications for the period (net of tax)   $969   $500     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $5,511   $5,802   (a)    Amortization of loss   (1,578 )   (3,770 )   (a) Total amortization   3,933   2,032         (1,026 )   (530 )   Income taxes Total amortization (net of tax)   2,907   1,502                   Total reclassifications for the period (net of tax)   $2,907   $1,502     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.
Entergy Texas [Member]
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:   For the Three Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $365.2   198.9   $1.84   $536.4   181.0   $2.96 Average dilutive effect of:                       Stock options     0.7   (0.01 )       0.4   (0.01 ) Other equity plans     0.9   (0.01 )       0.8   (0.01 ) Equity forwards     —   —       1.5   (0.02 ) Diluted earnings per share $365.2   200.5   $1.82   $536.4   183.7   $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018.   For the Nine Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $856.2   193.9   $4.42   $914.6   180.8   $5.06 Average dilutive effect of:                       Stock options     0.5   (0.01 )       0.3   (0.01 ) Other equity plans     0.7   (0.02 )       0.7   (0.01 ) Equity forwards     0.6   (0.01 )       0.9   (0.03 ) Diluted earnings per share $856.2   195.7   $4.38   $914.6   182.7   $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018. Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018. Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million. In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million. Treasury Stock During the nine months ended September 30, 2019, Entergy Corporation issued 1,582,916 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2019. Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2019 $51,736   ($508,876 )   $26,736   ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 )   —   8,350   3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 )   25,464   (3,079 )   7,472 Net other comprehensive income (loss) for the period (20,103 )   25,464   5,271   10,632 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2018 ($14,874 )   ($589,926 )   ($8,842 )   ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 )   —   (7,173 )   (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397   15,265   5,428   29,090 Net other comprehensive income (loss) for the period (32,004 )   15,265   (1,745 )   (18,484 ) Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2018 ($23,135 )   ($531,922 )   ($2,116 )   ($557,173 ) Implementation of accounting standards (7,685 )   —   879   (6,806 ) Beginning balance, January 1, 2019 ($30,820 )   ($531,922 )   ($1,237 )   ($563,979 )                 Other comprehensive income (loss) before reclassifications 122,481   —   37,724   160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 )   48,510   (4,480 )   (15,998 ) Net other comprehensive income (loss) for the period 62,453   48,510   33,244   144,207 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2017 ($37,477 )   ($531,099 )   $545,045   ($23,531 ) Implementation of accounting standards —   —   (632,617 )   (632,617 ) Beginning balance, January 1, 2018 ($37,477 )   ($531,099 )   ($87,572 )   ($656,148 )                 Other comprehensive income (loss) before reclassifications (31,816 )   —   (50,958 )   (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171   47,404   13,716   91,291 Net other comprehensive income (loss) for the period (1,645 )   47,404   (37,242 )   8,517                 Reclassification pursuant to ASU 2018-02 (7,756 )   (90,966 )   114,227   15,505                 Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, July 1,   ($8,091 )   ($57,451 ) Amounts reclassified from accumulated other comprehensive income (loss)   (969 )   (500 ) Net other comprehensive income (loss) for the period   (969 )   (500 ) Ending balance, September 30,   ($9,060 )   ($57,951 )      The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, January 1,   ($6,153 )   ($46,400 ) Amounts reclassified from accumulated other comprehensive income (loss)   (2,907 )   (1,502 ) Net other comprehensive income (loss) for the period   (2,907 )   (1,502 )           Reclassification pursuant to ASU 2018-02   —   (10,049 )           Ending balance, September 30,   ($9,060 )   ($57,951 )      Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location   2019   2018     (In Thousands) Cash flow hedges net unrealized gain (loss)        Power contracts $18,925   ($10,566 ) Competitive business operating revenues    Interest rate swaps (48 )   (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877   (10,629 ) (3,964 )   2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913   ($8,397 )     Pension and other postretirement liabilities        Amortization of prior-service credit $5,325   $5,425 (a)    Amortization of loss (20,919 )   (24,740 ) (a)    Settlement loss (16,630 )   (76 ) (a) Total amortization (32,224 )   (19,391 ) 6,760   4,126 Income taxes Total amortization (net of tax) ($25,464 )   ($15,265 )     Net unrealized investment gain (loss)     Realized gain (loss) $4,872   ($8,589 ) Interest and investment income (1,793 )   3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079   ($5,428 )     Total reclassifications for the period (net of tax) ($7,472 )   ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows:   Amounts reclassified from AOCI   Income Statement Location   2019   2018       (In Thousands)     Cash flow hedges net unrealized gain (loss)              Power contracts $76,129   ($37,913 )   Competitive business operating revenues    Interest rate swaps (145 )   (278 )   Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984   (38,191 )       (15,956 )   8,020   Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028   ($30,171 )                 Pension and other postretirement liabilities              Amortization of prior-service credit $15,977   $16,278   (a)    Amortization of loss (58,888 )   (74,503 )   (a)    Settlement loss (18,685 )   (2,098 )   (a) Total amortization (61,596 )   (60,323 )       13,086   12,919   Income taxes Total amortization (net of tax) ($48,510 )   ($47,404 )                 Net unrealized investment gain (loss)           Realized gain (loss) $7,088   ($21,703 )   Interest and investment income   (2,608 )   7,987   Income taxes Total realized investment gain (loss) (net of tax) $4,480   ($13,716 )                 Total reclassifications for the period (net of tax) $15,998   ($91,291 )     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $1,837   $1,934   (a)    Amortization of loss   (526 )   (1,257 )   (a) Total amortization   1,311   677         (342 )   (177 )   Income taxes Total amortization (net of tax)   969   500                   Total reclassifications for the period (net of tax)   $969   $500     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $5,511   $5,802   (a)    Amortization of loss   (1,578 )   (3,770 )   (a) Total amortization   3,933   2,032         (1,026 )   (530 )   Income taxes Total amortization (net of tax)   2,907   1,502                   Total reclassifications for the period (net of tax)   $2,907   $1,502     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.
Entergy Louisiana [Member]
Equity	EQUITY (Entergy Corporation, Entergy Louisiana, and Entergy Texas) Common Stock Earnings per Share The following table presents Entergy’s basic and diluted earnings per share calculations included on the consolidated income statements:   For the Three Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $365.2   198.9   $1.84   $536.4   181.0   $2.96 Average dilutive effect of:                       Stock options     0.7   (0.01 )       0.4   (0.01 ) Other equity plans     0.9   (0.01 )       0.8   (0.01 ) Equity forwards     —   —       1.5   (0.02 ) Diluted earnings per share $365.2   200.5   $1.82   $536.4   183.7   $2.92 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 1.1 million for the three months ended September 30, 2018.   For the Nine Months Ended September 30,   2019   2018   (In Millions, Except Per Share Data)   Income   Shares   $/share   Income   Shares   $/share Basic earnings per share                       Net income attributable to Entergy Corporation $856.2   193.9   $4.42   $914.6   180.8   $5.06 Average dilutive effect of:                       Stock options     0.5   (0.01 )       0.3   (0.01 ) Other equity plans     0.7   (0.02 )       0.7   (0.01 ) Equity forwards     0.6   (0.01 )       0.9   (0.03 ) Diluted earnings per share $856.2   195.7   $4.38   $914.6   182.7   $5.01 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 0.2 million for the nine months ended September 30, 2019 and approximately 1.1 million for the nine months ended September 30, 2018. Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K. Dividends declared per common share were $0.91 for the three months ended September 30, 2019 and $0.89 for the three months ended September 30, 2018. Dividends declared per common share were $2.73 for the nine months ended September 30, 2019 and $2.67 for the nine months ended September 30, 2018. Equity Forward Sale Agreements As discussed in Note 7 to the financial statements in the Form 10-K, in June 2018, Entergy marketed an equity offering of 15.3 million shares of common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with various investment banks. In December 2018, Entergy physically settled a portion of its obligations under the forward sale agreements by delivering 6,834,221 shares of common stock in exchange for cash proceeds of approximately $500 million. In May 2019, Entergy physically settled the remaining 8,448,171 shares of common stock in exchange for cash proceeds of approximately $608 million. Treasury Stock During the nine months ended September 30, 2019, Entergy Corporation issued 1,582,916 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the nine months ended September 30, 2019. Retained Earnings On October 25, 2019, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.93 per share, payable on December 2, 2019, to holders of record as of November 7, 2019. Entergy implemented ASU No. 2017-12 “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities” effective January 1, 2019. The ASU makes a number of amendments to hedge accounting, most significantly changing the recognition and presentation of highly effective hedges. Entergy implemented this standard using a modified retrospective method, and recorded an adjustment increasing retained earnings and increasing accumulated other comprehensive loss by approximately $8 million as of January 1, 2019 for the cumulative effect of the ineffectiveness portion of designated hedges on nuclear power sales. Entergy implemented ASU 2017-08 “Receivables (Topic 310): Nonrefundable Fees and Other Costs” effective January 1, 2019. The ASU amends the amortization period for certain purchased callable debt securities held at a premium to the earliest call date. Entergy implemented this standard using the modified retrospective approach, and recorded an adjustment decreasing retained earnings and decreasing accumulated other comprehensive loss by approximately $1 million as of January 1, 2019 for the cumulative effect of the amended amortization period. Comprehensive Income Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2019 $51,736   ($508,876 )   $26,736   ($430,404 ) Other comprehensive income (loss) before reclassifications (5,190 )   —   8,350   3,160 Amounts reclassified from accumulated other comprehensive income (loss) (14,913 )   25,464   (3,079 )   7,472 Net other comprehensive income (loss) for the period (20,103 )   25,464   5,271   10,632 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Beginning balance, July 1, 2018 ($14,874 )   ($589,926 )   ($8,842 )   ($613,642 ) Other comprehensive income (loss) before reclassifications (40,401 )   —   (7,173 )   (47,574 ) Amounts reclassified from accumulated other comprehensive income (loss) 8,397   15,265   5,428   29,090 Net other comprehensive income (loss) for the period (32,004 )   15,265   (1,745 )   (18,484 ) Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2019 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2018 ($23,135 )   ($531,922 )   ($2,116 )   ($557,173 ) Implementation of accounting standards (7,685 )   —   879   (6,806 ) Beginning balance, January 1, 2019 ($30,820 )   ($531,922 )   ($1,237 )   ($563,979 )                 Other comprehensive income (loss) before reclassifications 122,481   —   37,724   160,205 Amounts reclassified from accumulated other comprehensive income (loss) (60,028 )   48,510   (4,480 )   (15,998 ) Net other comprehensive income (loss) for the period 62,453   48,510   33,244   144,207 Ending balance, September 30, 2019 $31,633   ($483,412 )   $32,007   ($419,772 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the nine months ended September 30, 2018 by component:   Cash flow hedges net unrealized gain (loss)   Pension and other postretirement liabilities   Net unrealized investment gain (loss)   Total Accumulated Other Comprehensive Income (Loss)   (In Thousands) Ending balance, December 31, 2017 ($37,477 )   ($531,099 )   $545,045   ($23,531 ) Implementation of accounting standards —   —   (632,617 )   (632,617 ) Beginning balance, January 1, 2018 ($37,477 )   ($531,099 )   ($87,572 )   ($656,148 )                 Other comprehensive income (loss) before reclassifications (31,816 )   —   (50,958 )   (82,774 ) Amounts reclassified from accumulated other comprehensive income (loss) 30,171   47,404   13,716   91,291 Net other comprehensive income (loss) for the period (1,645 )   47,404   (37,242 )   8,517                 Reclassification pursuant to ASU 2018-02 (7,756 )   (90,966 )   114,227   15,505                 Ending balance, September 30, 2018 ($46,878 )   ($574,661 )   ($10,587 )   ($632,126 ) The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the three months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, July 1,   ($8,091 )   ($57,451 ) Amounts reclassified from accumulated other comprehensive income (loss)   (969 )   (500 ) Net other comprehensive income (loss) for the period   (969 )   (500 ) Ending balance, September 30,   ($9,060 )   ($57,951 )      The following table presents changes in accumulated other comprehensive income (loss) for Entergy Louisiana for the nine months ended September 30, 2019 and 2018:     Pension and Other Postretirement Liabilities     2019   2018     (In Thousands) Beginning balance, January 1,   ($6,153 )   ($46,400 ) Amounts reclassified from accumulated other comprehensive income (loss)   (2,907 )   (1,502 ) Net other comprehensive income (loss) for the period   (2,907 )   (1,502 )           Reclassification pursuant to ASU 2018-02   —   (10,049 )           Ending balance, September 30,   ($9,060 )   ($57,951 )      Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the three months ended September 30, 2019 and 2018 are as follows: Amounts reclassified from AOCI Income Statement Location   2019   2018     (In Thousands) Cash flow hedges net unrealized gain (loss)        Power contracts $18,925   ($10,566 ) Competitive business operating revenues    Interest rate swaps (48 )   (63 ) Miscellaneous - net Total realized gain (loss) on cash flow hedges 18,877   (10,629 ) (3,964 )   2,232 Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $14,913   ($8,397 )     Pension and other postretirement liabilities        Amortization of prior-service credit $5,325   $5,425 (a)    Amortization of loss (20,919 )   (24,740 ) (a)    Settlement loss (16,630 )   (76 ) (a) Total amortization (32,224 )   (19,391 ) 6,760   4,126 Income taxes Total amortization (net of tax) ($25,464 )   ($15,265 )     Net unrealized investment gain (loss)     Realized gain (loss) $4,872   ($8,589 ) Interest and investment income (1,793 )   3,161 Income taxes Total realized investment gain (loss) (net of tax) $3,079   ($5,428 )     Total reclassifications for the period (net of tax) ($7,472 )   ($29,090 ) (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy for the nine months ended September 30, 2019 and 2018 are as follows:   Amounts reclassified from AOCI   Income Statement Location   2019   2018       (In Thousands)     Cash flow hedges net unrealized gain (loss)              Power contracts $76,129   ($37,913 )   Competitive business operating revenues    Interest rate swaps (145 )   (278 )   Miscellaneous - net Total realized gain (loss) on cash flow hedges 75,984   (38,191 )       (15,956 )   8,020   Income taxes Total realized gain (loss) on cash flow hedges (net of tax) $60,028   ($30,171 )                 Pension and other postretirement liabilities              Amortization of prior-service credit $15,977   $16,278   (a)    Amortization of loss (58,888 )   (74,503 )   (a)    Settlement loss (18,685 )   (2,098 )   (a) Total amortization (61,596 )   (60,323 )       13,086   12,919   Income taxes Total amortization (net of tax) ($48,510 )   ($47,404 )                 Net unrealized investment gain (loss)           Realized gain (loss) $7,088   ($21,703 )   Interest and investment income   (2,608 )   7,987   Income taxes Total realized investment gain (loss) (net of tax) $4,480   ($13,716 )                 Total reclassifications for the period (net of tax) $15,998   ($91,291 )     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the three months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $1,837   $1,934   (a)    Amortization of loss   (526 )   (1,257 )   (a) Total amortization   1,311   677         (342 )   (177 )   Income taxes Total amortization (net of tax)   969   500                   Total reclassifications for the period (net of tax)   $969   $500     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) into income for Entergy Louisiana for the nine months ended September 30, 2019 and 2018 are as follows:     Amounts reclassified from AOCI   Income Statement Location     2019   2018         (In Thousands)     Pension and other postretirement liabilities                Amortization of prior-service credit   $5,511   $5,802   (a)    Amortization of loss   (1,578 )   (3,770 )   (a) Total amortization   3,933   2,032         (1,026 )   (530 )   Income taxes Total amortization (net of tax)   2,907   1,502                   Total reclassifications for the period (net of tax)   $2,907   $1,502     (a) These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details. Preferred Stock In September 2019, Entergy Texas issued $35 million of 5.375% Series A preferred stock, a total of 1,400,000 shares with a liquidation value of $25 per share, all of which are outstanding as of September 30, 2019. The dividends are cumulative and payable quarterly. The preferred stock is redeemable on or after October 15, 2024 at Entergy Texas’s option, at a fixed redemption price of $25 per share. Accounting standards regarding the classification and measurement of redeemable securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem their securities, even if the likelihood of occurrence of these circumstances is considered remote. The outstanding preferred stock of Entergy Texas has protective rights with respect to unpaid dividends but provides for the election of board members that would not constitute a majority of the board, and the preferred stock of Entergy Texas is therefore classified as a component of equity.

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v3.19.3

Decommissioning Trust Funds (Tables)	9 Months Ended
	Sep. 30, 2019
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities (a)   $2,462   $114   $2               2018             Debt Securities (a)   $2,495   $19   $35 (a) Debt securities presented herein do not include the $506 million and $389 million of debt securities held in the wholly-owned registered investment company as of September 30, 2019 and December 31, 2018, respectively, which are not accounted for as available-for-sale.
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $236   $2 More than 12 months   67   — Total   $303   $2 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $652   $9 More than 12 months 782   26 Total $1,434   $35
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $165   $199 1 year - 5 years 870   1,066 5 years - 10 years 636   544 10 years - 15 years 89   77 15 years - 20 years 98   78 20 years+ 604   531 Total $2,462   $2,495
Entergy Arkansas [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $407.7   $11.8   $0.9               2018             Debt Securities   $381.3   $0.6   $8.2
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $51.5   $0.8 More than 12 months   21.0   0.1 Total   $72.5   $0.9 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $65.8   $0.5 More than 12 months 231.1   7.7 Total $296.9   $8.2
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $50.3   $32.5 1 year - 5 years 120.4   170.3 5 years - 10 years 144.5   114.0 10 years - 15 years 24.3   10.3 15 years - 20 years 14.2   8.1 20 years+ 54.0   46.1 Total $407.7   $381.3
Entergy Louisiana [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $593.4   $32.6   $0.3               2018             Debt Securities   $532.9   $4.1   $6.0
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses     (In Millions) Less than 12 months   $49.3   $0.3 More than 12 months   12.9   — Total   $62.2   $0.3 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $170.1   $2.1 More than 12 months 145.8   3.9 Total $315.9   $6.0
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $56.6   $31.1 1 year - 5 years 138.2   130.5 5 years - 10 years 118.4   111.0 10 years - 15 years 34.7   29.0 15 years - 20 years 45.0   37.1 20 years+ 200.5   194.2 Total $593.4   $532.9
System Energy [Member]
Securities Held	The available-for-sale securities held as of September 30, 2019 and December 31, 2018 are summarized as follows:     Fair Value   Total Unrealized Gains   Total Unrealized Losses     (In Millions) 2019             Debt Securities   $395.3   $19.7   $0.1               2018             Debt Securities   $364.2   $2.9   $5.8
Available For Sale Securities Continuous Unrealized Loss Position Fair Value	The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of September 30, 2019:     Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months   $38.8   $0.1 More than 12 months   4.3   — Total   $43.1   $0.1 The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities have been in a continuous loss position, are as follows as of December 31, 2018:   Fair Value   Gross Unrealized Losses   (In Millions) Less than 12 months $89.7   $2.4 More than 12 months 79.8   3.4 Total $169.5   $5.8
Fair Value Of Debt Securities By Contractual Maturities	The fair value of available-for-sale debt securities, summarized by contractual maturities, as of September 30, 2019 and December 31, 2018 are as follows:   2019   2018   (In Millions) Less than 1 year $11.2   $22.8 1 year - 5 years 187.7   188.0 5 years - 10 years 92.7   73.4 10 years - 15 years 3.0   5.2 15 years - 20 years 5.9   10.2 20 years+ 94.8   64.6 Total $395.3   $364.2

X

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v3.19.3

Commitments and Contingencies Commitments and Contingencies (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Aug. 31, 2019	Sep. 30, 2019	Sep. 30, 2018
Loss Contingencies [Line Items]
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		$ 2,369	$ 0
Entergy Louisiana [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 19,000
Litigation proceeds for reimbursement of spent nuclear fuel storage costs	12,000
Damages awarded for previously recorded operation and maintenance	5,000
Damages awarded for previously recorded nuclear fuel expense	$ 2,000
System Energy [Member]
Loss Contingencies [Line Items]
Minimum Rate Of Equity Capital		35.00%

X

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- Definition Damages awarded for previously recorded operation and maintenance expenses + References No definition available. + Details Name: etr_Damagesawardedforpreviouslyrecordedoperationandmaintenance Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Litigation proceeds for reimbursement of spent nuclear fuel storage costs. + References No definition available. + Details Name: etr_LitigationProceedsForReimbursementOfSpentNuclearFuelStorageCosts Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Minimum rate of equity capital. + References No definition available. + Details Name: etr_MinimumRateOfEquityCapital Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Amount awarded from other party in judgment or settlement of litigation. + References No definition available. + Details Name: us-gaap_LitigationSettlementAmountAwardedFromOtherParty Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_LossContingenciesLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Retirement And Other Postretirement Benefits (Reclassification Out Of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	$ 5,325	$ 5,425	$ 15,977	$ 16,278
Amortization of loss	(20,919)	(24,740)	(58,888)	(74,503)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(16,630)	(76)	(18,685)	(2,098)
Total	(32,224)	(19,391)	(61,596)	(60,323)
Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	5,511	5,802
Amortization of loss	(526)	(1,257)	(1,578)	(3,770)
Total	1,311	677	3,933	2,032
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	(99)	0	(297)
Amortization of loss	(20,686)	(21,958)	(58,156)	(65,870)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(16,257)	0	(17,557)	0
Total	(36,943)	(22,057)	(75,713)	(66,167)
Pension Plans Defined Benefit [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(699)	(867)	(2,096)	(2,601)
Total	(699)	(867)	(2,096)	(2,601)
Other Postretirement [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	5,375	5,595	16,125	16,786
Amortization of loss	308	(1,932)	923	(5,801)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	0	0	0	0
Total	5,683	3,663	17,048	10,985
Other Postretirement [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	1,837	1,934	5,511	5,802
Amortization of loss	174	(388)	522	(1,164)
Total	2,011	1,546	6,033	4,638
Non Qualified Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	(50)	(71)	(148)	(211)
Amortization of loss	(541)	(850)	(1,655)	(2,832)
Recognized Net Gain (Loss) Due To Settlements, Pre Tax	(373)	(76)	(1,128)	(2,098)
Total	(964)	(997)	(2,931)	(5,141)
Non Qualified Pension Plans [Member] | Entergy Louisiana [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service cost	0	0	0	0
Amortization of loss	(1)	(2)	(4)	(5)
Total	$ (1)	$ (2)	$ (4)	$ (5)

X

- Definition The amount of gains or losses recognized in net periodic benefit cost, pre tax and including amounts capitalized. + References No definition available. + Details Name: etr_AmortizationOfGainsLossesPreTax Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition The amount of the prior service cost or credit recognized in net periodic benefit cost relating to benefit changes attributable to plan participants' prior service pursuant to a plan amendment or a plan initiation, pre tax and including amounts capitalized. + References No definition available. + Details Name: etr_AmortizationOfPriorServiceCostCreditPreTax Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of net gain (loss) recognized in net periodic benefit cost as a result of an irrevocable action that relieves the employer (or the plan) of primary responsibility for a benefit obligation and eliminates significant risks related to the obligation and the assets used to effect the settlement. Examples of transactions that constitute a settlement include, but are not limited to, lump-sum cash payments to plan participants in exchange for their rights to receive specified benefits and purchasing nonparticipating annuity contracts to cover vested benefits, pre tax and including amounts capitalized + References No definition available. + Details Name: etr_RecognizedNetGainLossDueToSettlementsPreTax Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_DefinedBenefitPlanDisclosureLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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v3.19.3

Stock-Based Compensation (Financial Information For Other Equity Plans) (Details) - Other Equity Awards [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Employee service share-based compensation, aggregate disclosures
Compensation expense included in Entergy's net income	$ 8.4	$ 8.5	$ 25.6	$ 26.0
Tax benefit recognized in Entergy's net income	2.1	2.2	6.5	6.6
Compensation cost capitalized as part of fixed assets and inventory	$ 3.0	$ 2.5	$ 8.8	$ 7.3

X

- Definition Represents the expense recognized during the period arising from equity-based compensation arrangements (for example, shares of stock, unit, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5047-113901 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SAB Topic 14.F) -URI http://asc.fasb.org/extlink&oid=115993241&loc=d3e301413-122809 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(i) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_AllocatedShareBasedCompensationExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Represents the compensation cost capitalized during the period arising from equity-based compensation arrangements (for example, shares of stock, units, stock options or other equity instruments) with employees, directors and certain consultants qualifying for treatment as employees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(ii) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_EmployeeServiceShareBasedCompensationAllocationOfRecognizedPeriodCostsCapitalizedAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition The total recognized tax benefit related to compensation cost for equity-based payment arrangements recognized in income during the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 718 -SubTopic 10 -Section 50 -Paragraph 2 -Subparagraph (h)(1)(i) -URI http://asc.fasb.org/extlink&oid=109197908&loc=d3e5070-113901 + Details Name: us-gaap_EmployeeServiceShareBasedCompensationTaxBenefitFromCompensationExpense Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

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v3.19.3

Decommissioning Trust Funds (Available For Sale Securities Continuous Unrealized Loss Position Fair Value) (Details) - Debt Securities [Member] - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	$ 236.0	$ 652.0
More than 12 months Fair Value	67.0	782.0
Total Fair Value	303.0	1,434.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	2.0	9.0
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	26.0
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	2.0	35.0
Entergy Arkansas [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	51.5	65.8
More than 12 months Fair Value	21.0	231.1
Total Fair Value	72.5	296.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.8	0.5
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.1	7.7
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.9	8.2
Entergy Louisiana [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	49.3	170.1
More than 12 months Fair Value	12.9	145.8
Total Fair Value	62.2	315.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.3	2.1
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	3.9
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	0.3	6.0
System Energy [Member]
Debt Securities, Available-for-sale [Line Items]
Less than 12 months Fair Value	38.8	89.7
More than 12 months Fair Value	4.3	79.8
Total Fair Value	43.1	169.5
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than 12 Months, Accumulated Loss	0.1	2.4
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Accumulated Loss	0.0	3.4
Available-for-sale Securities, Continuous Unrealized Loss Position, Accumulated Loss	$ 0.1	$ 5.8

X

- Definition Amount of accumulated unrealized loss on investments in debt and equity securities classified as available-for-sale that have been in a continuous loss position for twelve months or longer. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPosition12MonthsOrLongerAccumulatedLoss Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of accumulated unrealized loss on investments in debt and equity securities classified as available-for-sale in a continuous loss position. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 320 -SubTopic 10 -Section 50 -Paragraph 7 -URI http://asc.fasb.org/extlink&oid=82897076&loc=d3e27337-111563 + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPositionAccumulatedLoss Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition This item represents the aggregate fair value of investments in debt and equity securities in an unrealized loss position which are categorized neither as held-to-maturity nor trading securities. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPositionFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of accumulated unrealized loss on investments in debt and equity securities classified as available-for-sale that have been in a continuous loss position for less than twelve months. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPositionLessThan12MonthsAccumulatedLoss Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition This item represents the aggregate fair value of investments in debt and equity securities categorized neither as held-to-maturity nor trading securities that have been in a continuous unrealized loss position for less than twelve months. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPositionLessThanTwelveMonthsFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition This item represents the aggregate fair value of investments in debt and equity securities categorized neither as held-to-maturity nor trading securities that have been in a continuous unrealized loss position for twelve months or longer. + References No definition available. + Details Name: us-gaap_AvailableForSaleSecuritiesContinuousUnrealizedLossPositionTwelveMonthsOrLongerFairValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_ScheduleOfAvailableForSaleSecuritiesLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

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v3.19.3

Leases Leases (Lease, Assets) (Details) $ in Thousands	Sep. 30, 2019 USD ($)
Operating Lease, Right-of-Use Asset	$ 236,000
Finance Lease, Right-of-Use Asset	60,000
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset	49,503
Finance Lease, Right-of-Use Asset	11,094
Entergy Louisiana [Member]
Operating Lease, Right-of-Use Asset	34,248
Finance Lease, Right-of-Use Asset	16,795
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset	18,149
Finance Lease, Right-of-Use Asset	6,994
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset	3,894
Finance Lease, Right-of-Use Asset	2,913
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset	13,074
Finance Lease, Right-of-Use Asset	$ 5,515

X

- Definition Amount of lessee's right to use underlying asset under finance lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_FinanceLeaseRightOfUseAsset Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of lessee's right to use underlying asset under operating lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_OperatingLeaseRightOfUseAsset Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

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v3.19.3

Leases Leases (Operating And Capital Leases Future Minimum Payments Due) (Details) $ in Thousands	Dec. 31, 2018 USD ($)
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 94,043
Capital Leases, Future Minimum Payments Due, Next Twelve Months	2,887
Operating Leases, Future Minimum Payments, Due in Two Years	82,191
Capital Leases, Future Minimum Payments Due in Two Years	2,887
Operating Leases, Future Minimum Payments, Due in Three Years	75,147
Capital Leases, Future Minimum Payments Due in Three Years	2,887
Operating Leases, Future Minimum Payments, Due in Four Years	60,808
Capital Leases, Future Minimum Payments Due in Four Years	2,887
Operating Leases, Future Minimum Payments, Due in Five Years	47,391
Capital Leases, Future Minimum Payments Due in Five Years	2,887
Operating Leases, Future Minimum Payments, Due Thereafter	88,004
Capital Leases, Future Minimum Payments Due Thereafter	16,117
Operating Leases, Future Minimum Payments Due	447,584
Capital Leases, Future Minimum Payments Due	30,552
Capital Leases, Future Minimum Payments, Interest Included in Payments	8,555
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments	21,997
Entergy Arkansas [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	20,421
Operating Leases, Future Minimum Payments, Due in Two Years	13,918
Operating Leases, Future Minimum Payments, Due in Three Years	11,931
Operating Leases, Future Minimum Payments, Due in Four Years	9,458
Operating Leases, Future Minimum Payments, Due in Five Years	7,782
Operating Leases, Future Minimum Payments, Due Thereafter	23,297
Operating Leases, Future Minimum Payments Due	86,807
Entergy Louisiana [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	25,970
Operating Leases, Future Minimum Payments, Due in Two Years	21,681
Operating Leases, Future Minimum Payments, Due in Three Years	19,514
Operating Leases, Future Minimum Payments, Due in Four Years	15,756
Operating Leases, Future Minimum Payments, Due in Five Years	12,092
Operating Leases, Future Minimum Payments, Due Thereafter	22,003
Operating Leases, Future Minimum Payments Due	117,016
Entergy Mississippi [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	9,344
Operating Leases, Future Minimum Payments, Due in Two Years	8,763
Operating Leases, Future Minimum Payments, Due in Three Years	7,186
Operating Leases, Future Minimum Payments, Due in Four Years	5,675
Operating Leases, Future Minimum Payments, Due in Five Years	2,946
Operating Leases, Future Minimum Payments, Due Thereafter	4,417
Operating Leases, Future Minimum Payments Due	38,331
Entergy New Orleans [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	2,493
Operating Leases, Future Minimum Payments, Due in Two Years	2,349
Operating Leases, Future Minimum Payments, Due in Three Years	1,901
Operating Leases, Future Minimum Payments, Due in Four Years	1,314
Operating Leases, Future Minimum Payments, Due in Five Years	1,043
Operating Leases, Future Minimum Payments, Due Thereafter	2,323
Operating Leases, Future Minimum Payments Due	11,423
Entergy Texas [Member]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	5,744
Operating Leases, Future Minimum Payments, Due in Two Years	4,431
Operating Leases, Future Minimum Payments, Due in Three Years	3,625
Operating Leases, Future Minimum Payments, Due in Four Years	2,218
Operating Leases, Future Minimum Payments, Due in Five Years	1,561
Operating Leases, Future Minimum Payments, Due Thereafter	2,726
Operating Leases, Future Minimum Payments Due	$ 20,305

X

- Definition Amount of minimum lease payments for capital leases. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due in the next fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due in the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueInFiveYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due in the fourth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueInFourYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due in the third fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueInThreeYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due in the second fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueInTwoYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of minimum lease payments for capital leases due after the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsDueThereafter Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount necessary to reduce net minimum lease payments to present value for capital leases. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsInterestIncludedInPayments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Present value of minimum lease payments for capital leases net of executory costs, including amounts paid by the lessee to the lessor for insurance, maintenance and taxes. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_CapitalLeasesFutureMinimumPaymentsPresentValueOfNetMinimumPayments Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for leases having an initial or remaining non-cancelable letter-terms in excess of one year. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due in the next fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueCurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due in the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueInFiveYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due in the fourth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueInFourYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due in the third fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueInThreeYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due in the second fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueInTwoYears Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of required minimum rental payments for operating leases having an initial or remaining non-cancelable lease term in excess of one year due after the fifth fiscal year following the latest fiscal year. Excludes interim and annual periods when interim periods are reported on a rolling approach, from latest balance sheet date. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41502-112717 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 10 -Section 55 -Paragraph 40 -Subparagraph (Note 3) -URI http://asc.fasb.org/extlink&oid=82846649&loc=d3e38371-112697 + Details Name: us-gaap_OperatingLeasesFutureMinimumPaymentsDueThereafter Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Property, Plant, And Equipment (Narrative) (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Construction expenditures in accounts payable	$ 306.0	$ 311.0
Entergy Arkansas [Member]
Construction expenditures in accounts payable	41.7	35.7
Entergy Louisiana [Member]
Construction expenditures in accounts payable	74.0	104.6
Entergy Mississippi [Member]
Construction expenditures in accounts payable	14.7	13.6
Entergy New Orleans [Member]
Construction expenditures in accounts payable	13.9	5.8
Entergy Texas [Member]
Construction expenditures in accounts payable	81.6	55.6
System Energy [Member]
Construction expenditures in accounts payable	$ 24.6	$ 26.3

X

- Definition Carrying value as of the balance sheet date of obligations incurred and payable for the acquisition of merchandise, materials, supplies and services pertaining to construction projects such as a housing development or factory expansion not classified as trade payables. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03.15(5)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03.15(a)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_ConstructionPayableCurrentAndNoncurrent Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Details Name: dei_LegalEntityAxis=etr_EntergyNewOrleansMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyTexasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Leases Leases (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2016	Sep. 30, 2019	Sep. 30, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Jan. 31, 2019	Dec. 31, 2015	Dec. 31, 1989	Dec. 31, 1988
Short-term Lease, Cost		$ 15,000	$ 15,000
Operating Lease, Right-of-Use Asset		236,000,000	236,000,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							$ 263,000,000
Operating Leases, Rent Expense, Net				$ 47,800,000	$ 53,100,000	$ 44,400,000
Finance Lease, Right-of-Use Asset		60,000,000	60,000,000
Entergy Arkansas [Member]
Operating Lease, Right-of-Use Asset		49,503,000	49,503,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							59,000,000
Operating Leases, Rent Expense, Net				6,200,000	7,500,000	8,000,000.0
Payments For Railcar Operating Lease				2,800,000	4,000,000	3,400,000
Finance Lease, Right-of-Use Asset		11,094,000	11,094,000
Entergy Louisiana [Member]
Short-term Lease, Cost		15,000	15,000
Operating Lease, Right-of-Use Asset		34,248,000	34,248,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							51,000,000
Operating Leases, Rent Expense, Net				$ 20,200,000	23,000,000.0	17,800,000
Percentage Of Capacity And Energy Purchased Under Purchased Power Agreement				50.00%
Cash payment representing the purchase price to acquire the undivided interests in Waterford 3	$ 60,000,000
Portion of Waterford 3 purchase price satisfied through issuance of debt	$ 52,000,000
Payments For Railcar Operating Lease				$ 400,000	300,000	300,000
Finance Lease, Right-of-Use Asset		16,795,000	16,795,000
Entergy Mississippi [Member]
Operating Lease, Right-of-Use Asset		18,149,000	18,149,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							26,000,000
Operating Leases, Rent Expense, Net				4,600,000	5,600,000	4,000,000.0
Oil Tank Facilities Lease Payments				100,000	1,600,000	1,600,000
Finance Lease, Right-of-Use Asset		6,994,000	6,994,000
Entergy New Orleans [Member]
Operating Lease, Right-of-Use Asset		3,894,000	3,894,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							7,000,000
Operating Leases, Rent Expense, Net				2,500,000	2,500,000	900,000
Finance Lease, Right-of-Use Asset		2,913,000	2,913,000
Entergy Texas [Member]
Operating Lease, Right-of-Use Asset		13,074,000	13,074,000
Operating and Finance Lease Right of Use Asset and Lease Liabilities at Implementation							$ 16,000,000
Operating Leases, Rent Expense, Net				$ 3,100,000	3,400,000	2,800,000
Percent of minimum payments				100.00%
Capacity expense under purchase power agreements accounted for as operating leases				$ 30,500,000	34,100,000	26,100,000
Finance Lease, Right-of-Use Asset		$ 5,515,000	$ 5,515,000
System Energy [Member]
Operating Leases, Rent Expense, Net				1,900,000	2,200,000	$ 1,600,000
Grand Gulf [Member] | System Energy [Member]
Sale Leaseback Transaction, Net Book Value										$ 500,000,000
Regulatory Assets				0
Regulatory Liabilities				$ 55,600,000	$ 55,600,000
Waterford Three [Member] | Entergy Louisiana [Member]
Liability related to undivided interests in Waterford 3								$ 62,700,000
Reduced liability related to undivided interests in Waterford 3								60,000,000
Reduction in liability related to undivided interest in Waterford 3 recorded as credit to interest expense								$ 2,700,000
Implicit Rate Of Future Minimum Lease Payments						8.09%
Minimum Lease Payments, Sale Leaseback Transactions						$ 57,500,000
Interest Portion of Minimum Lease Payments, Sale Leaseback Transactions						$ 2,300,000
Sale Leaseback Transaction, Net Book Value									$ 353,600,000

X

- Definition Capacity expense under purchase power agreements accounted for as operating leases + References No definition available. + Details Name: etr_Capacityexpenseunderpurchasepoweragreementsaccountedforasoperatingleases Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Cash payment representing the purchase price to acquire the undivided interests in Waterford 3 + References No definition available. + Details Name: etr_CashpaymentrepresentingthepurchasepricetoacquiretheundividedinterestsinWaterford3 Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Implicit rate of future minimum lease payments + References No definition available. + Details Name: etr_ImplicitRateOfFutureMinimumLeasePayments Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Liability related to undivided interests in Waterford 3 + References No definition available. + Details Name: etr_LiabilityrelatedtoundividedinterestsinWaterford3 Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Oil Tank Facilities Lease Payments + References No definition available. + Details Name: etr_OilTankFacilitiesLeasePayments Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Amount of lessee's right to use underlying asset and liability under operating and finance leases. + References No definition available. + Details Name: etr_OperatingandFinanceLeaseRightofUseAssetandLeaseLiabilitiesatImplementation Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Payments for railcar operating lease + References No definition available. + Details Name: etr_PaymentsForRailcarOperatingLease Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition Percentage Of Capacity And Energy Purchased Under Purchased Power Agreement + References No definition available. + Details Name: etr_PercentageOfCapacityAndEnergyPurchasedUnderPurchasedPowerAgreement Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Percent of minimum payments + References No definition available. + Details Name: etr_Percentofminimumpayments Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: duration

X

- Definition Portion of Waterford 3 purchase price satisfied through issuance of debt + References No definition available. + Details Name: etr_PortionofWaterford3purchasepricesatisfiedthroughissuanceofdebt Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Reduced liability related to undivided interests in Waterford 3. Represents remaining liability that will be eliminated upon payment of the cash portion of the purchase price. + References No definition available. + Details Name: etr_ReducedliabilityrelatedtoundividedinterestsinWaterford3 Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Reduction in liability related to undivided interest in Waterford 3 recorded as credit to interest expense + References No definition available. + Details Name: etr_ReductioninliabilityrelatedtoundividedinterestinWaterford3recordedascredittointerestexpense Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of lessee's right to use underlying asset under finance lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_FinanceLeaseRightOfUseAsset Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount necessary to reduce minimum lease payments to present value for sale-leaseback transactions accounted for using the deposit method or as a financing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 30 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=84164817&loc=d3e45280-112737 + Details Name: us-gaap_InterestPortionOfMinimumLeasePaymentsSaleLeasebackTransactions Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of minimum lease payments for sale-leaseback transactions accounted for using the deposit method or as a financing. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 40 -Section 50 -Paragraph 2 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77914019&loc=d3e50824-112756 + Details Name: us-gaap_MinimumLeasePaymentsSaleLeasebackTransactions Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition Amount of lessee's right to use underlying asset under operating lease. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 45 -Paragraph 1 -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=77888419&loc=SL77918627-209977 + Details Name: us-gaap_OperatingLeaseRightOfUseAsset Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Rental expense for the reporting period incurred under operating leases, including minimum and any contingent rent expense, net of related sublease income. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=77902758&loc=d3e41499-112717 + Details Name: us-gaap_OperatingLeasesRentExpenseNet Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition The amount for the individual regulatory asset as itemized in a table of regulatory assets as of the end of the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -SubTopic 340 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6499975&loc=d3e44250-110382 + Details Name: us-gaap_RegulatoryAssets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition The amount for the individual regulatory liability as itemized in a table of regulatory liabilities as of the end of the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -SubTopic 405 -Section 25 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6500807&loc=d3e48068-110394 + Details Name: us-gaap_RegulatoryLiabilities Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition The net book value of the asset(s) sold in connection with the sale of the property to another party and lease back to the seller. + References Reference 1: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 40 -Section 55 -Paragraph 51 -URI http://asc.fasb.org/extlink&oid=82846721&loc=d3e51840-112757 Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 40 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=77888430&loc=SL77919786-209982 Reference 3: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 40 -Section 55 -Paragraph 52 -URI http://asc.fasb.org/extlink&oid=82846721&loc=d3e51843-112757 Reference 4: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 840 -SubTopic 40 -Section 55 -Paragraph 50 -URI http://asc.fasb.org/extlink&oid=82846721&loc=d3e51831-112757 + Details Name: us-gaap_SaleLeasebackTransactionNetBookValue Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount of short-term lease cost, excluding expense for lease with term of one month or less. + References Reference 1: http://www.xbrl.org/2003/role/disclosureRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 50 -Paragraph 4 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=77888426&loc=SL77918686-209980 Reference 2: http://www.xbrl.org/2003/role/exampleRef -Publisher FASB -Name Accounting Standards Codification -Topic 842 -SubTopic 20 -Section 55 -Paragraph 53 -URI http://asc.fasb.org/extlink&oid=77888399&loc=SL77918982-209971 + Details Name: us-gaap_ShortTermLeaseCost Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_EntergyArkansasMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyLouisianaMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyMississippiMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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X

- Details Name: dei_LegalEntityAxis=etr_SystemEnergyMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_SaleLeasebackTransactionDescriptionAxis=etr_GrandGulfMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: us-gaap_SaleLeasebackTransactionDescriptionAxis=etr_WaterfordThreeMember Namespace Prefix: Data Type: na Balance Type: Period Type:

v3.19.3

Dispositions Dispositions (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended
	Aug. 31, 2019	Sep. 30, 2019	Mar. 31, 2019	Jan. 31, 2019	Dec. 31, 2018	Jul. 31, 2018
Business Acquisition [Line Items]
Amount Drawn/ Outstanding		$ 155,000,000
Discontinued Operation, Tax Effect of Discontinued Operation			$ 29,000,000
Restructuring Costs and Asset Impairment Charges			5,400,000
After-Tax Asset Impairment Charge			$ 4,200,000
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment		52,705,142,000			$ 49,831,486,000
Entergy Nuclear Vermont Yankee [Member]
Business Acquisition [Line Items]
Percentage of Undivided Ownership Interest				100.00%
Amount Drawn/ Outstanding		139,000,000		$ 139,000,000
Entergy Nuclear Generation Company [Member]
Business Acquisition [Line Items]
Percentage of Undivided Ownership Interest						100.00%
Proceeds from Divestiture of Businesses	$ 1,000
Gain (Loss) on Disposition of Property Plant Equipment, Excluding Oil and Gas Property and Timber Property		191,000,000
Gain (Loss) on Sale of Properties, Net of Applicable Income Taxes		$ 156,000,000
Decommissioning Fund Investments, Fair Value	1,030,000,000
Asset Retirement Obligation	837,000,000
Public Utilities, Property, Plant and Equipment, Other Property, Plant and Equipment	$ 0

X

- Definition After-tax asset impairment charge + References No definition available. + Details Name: etr_AfterTaxAssetImpairmentCharge Namespace Prefix: etr_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

X

- Definition Percentage of Undivided Ownership Interest + References No definition available. + Details Name: etr_PercentageofUndividedOwnershipInterest Namespace Prefix: etr_ Data Type: num:percentItemType Balance Type: na Period Type: instant

X

- Definition The carrying amount of a liability for an asset retirement obligation. An asset retirement obligation is a legal obligation associated with the disposal or retirement of a tangible long-lived asset that results from the acquisition, construction or development, or the normal operations of a long-lived asset, except for certain obligations of lessees. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 410 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849 + Details Name: us-gaap_AssetRetirementObligation Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

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- Definition Line items represent financial concepts included in a table. These concepts are used to disclose reportable information associated with domain members defined in one or many axes to the table. + References No definition available. + Details Name: us-gaap_BusinessAcquisitionLineItems Namespace Prefix: us-gaap_ Data Type: xbrli:stringItemType Balance Type: na Period Type: duration

X

- Definition The fair value of investments held in a trust fund to pay for the costs of decontaminating and decommissioning facilities, whether such amount is presented as a separate caption or as a parenthetical disclosure on the balance sheet. Additionally, this element may be used in connection with the fair value disclosures required in the footnote disclosures to the financial statements. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 410 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6392692&loc=d3e7535-110849 + Details Name: us-gaap_DecommissioningTrustAssetsAmount Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

X

- Definition Amount of tax expense (benefit) related to a discontinued operation. Includes, but is not limited to, tax expense (benefit) related to income (loss) from operations during the phase-out period, tax expense (benefit) related to gain (loss) on disposal, tax expense (benefit) related to gain (loss) for reversal of write-down (write-down) to fair value, less cost to sell, and tax expense (benefit) related to adjustments of a prior period gain (loss) on disposal. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 3B -URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721525-107759 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 20 -Section 45 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=109238882&loc=d3e38679-109324 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 50 -Paragraph 10 -URI http://asc.fasb.org/extlink&oid=84230637&loc=d3e32672-109319 Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 4 -URI http://asc.fasb.org/extlink&oid=109222160&loc=d3e1012-107759 Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 1 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1361-107760 Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 45 -Paragraph 3A -URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721523-107759 Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 5C -Subparagraph (b)(2) -URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721675-107760 Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 205 -SubTopic 20 -Section 50 -Paragraph 5B -Subparagraph (a) -URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721673-107760 + Details Name: us-gaap_DiscontinuedOperationTaxEffectOfDiscontinuedOperation Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Amount of gain (loss) on sale or disposal of property, plant and equipment assets, excluding oil and gas property and timber property. + References Reference 1: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 45 -Paragraph 5 -URI http://asc.fasb.org/extlink&oid=109226348&loc=d3e2443-110228 Reference 3: http://www.xbrl.org/2009/role/commonPracticeRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 50 -Paragraph 3 -Subparagraph (c) -URI http://asc.fasb.org/extlink&oid=109226691&loc=d3e2941-110230 + Details Name: us-gaap_GainLossOnDispositionOfAssets Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition This element represents the amount of gain (loss) on sale of properties during the reporting period net of the applicable income taxes realized. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 974 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.3-15.(a)(1)(ii)) -URI http://asc.fasb.org/extlink&oid=6875705&loc=d3e641549-123027 + Details Name: us-gaap_GainLossOnSaleOfPropertiesNetOfApplicableIncomeTaxes Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: duration

X

- Definition The carrying value as of the balance sheet date of the current and noncurrent portions of long-term obligations drawn from a line of credit, which is a bank's commitment to make loans up to a specific amount. Examples of items that might be included in the application of this element may consist of letters of credit, standby letters of credit, and revolving credit arrangements, under which borrowings can be made up to a maximum amount as of any point in time conditional on satisfaction of specified terms before, as of and after the date of drawdowns on the line. Includes short-term obligations that would normally be classified as current liabilities but for which (a) postbalance sheet date issuance of a long term obligation to refinance the short term obligation on a long term basis, or (b) the enterprise has entered into a financing agreement that clearly permits the enterprise to refinance the short-term obligation on a long term basis and the following conditions are met (1) the agreement does not expire within 1 year and is not cancelable by the lender except for violation of an objectively determinable provision, (2) no violation exists at the BS date, and (3) the lender has entered into the financing agreement is expected to be financially capable of honoring the agreement. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02(22)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 942 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.9-03(16)) -URI http://asc.fasb.org/extlink&oid=6876686&loc=d3e534808-122878 Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 944 -SubTopic 210 -Section S99 -Paragraph 1 -Subparagraph (SX 210.7-03(16)) -URI http://asc.fasb.org/extlink&oid=6879938&loc=d3e572229-122910 + Details Name: us-gaap_LineOfCredit Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: credit Period Type: instant

X

- Definition The cash inflow associated with the amount received from the sale of a portion of the company's business, for example a segment, division, branch or other business, during the period. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 12 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3179-108585 + Details Name: us-gaap_ProceedsFromDivestitureOfBusinesses Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Definition Period end book value of other property, plant and equipment (PPE) owned (but not classified elsewhere) by the public utility. + References No definition available. + Details Name: us-gaap_PublicUtilitiesPropertyPlantAndEquipmentOtherPropertyPlantAndEquipment Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: instant

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- Definition Amount, after cash payment, of expenses associated with exit or disposal activities pursuant to an authorized plan and expenses resulting from the write-down of assets. Excludes expenses related to a business combination, a discontinued operation or an asset retirement obligation. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 230 -SubTopic 10 -Section 45 -Paragraph 28 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=109223946&loc=d3e3602-108585 + Details Name: us-gaap_RestructuringCostsAndAssetImpairmentCharges Namespace Prefix: us-gaap_ Data Type: xbrli:monetaryItemType Balance Type: debit Period Type: duration

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- Details Name: dei_LegalEntityAxis=etr_EntergyNuclearVermontYankeeMember Namespace Prefix: Data Type: na Balance Type: Period Type:

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- Details Name: dei_LegalEntityAxis=etr_EntergyNuclearGenerationCompanyMember Namespace Prefix: Data Type: na Balance Type: Period Type: