UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

For the quarterly period ended September 30, 2020

OR

For the transition period from                      to                      

Commission File Number: 001-35333

PERMIANVILLE ROYALTY TRUST

(Exact name of registrant as specified in its charter)

1-512-236-6555

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant (1) has 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 registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨

Indicate by check mark whether the registrant has 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 registrant was required to submit such files).    Yes  ¨    No  ¨

Indicate by check mark whether the 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 Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has 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 registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x

As of November 6, 2020, 33,000,000 units of beneficial interest in Permianville Royalty Trust were outstanding.

TABLE OF CONTENTS

GLOSSARY OF CERTAIN OIL AND NATURAL GAS TERMS

The following are definitions of significant terms used in this report.

Bbl—One barrel of 42 U.S. gallons liquid volume, used herein in reference to crude oil and other liquid hydrocarbons.

Boe—One barrel of oil equivalent, computed on an approximate energy equivalent basis that one Bbl of crude oil equals approximately six Mcf of natural gas.

Btu—A British Thermal Unit, a common unit of energy measurement.

Completion—The installation of permanent equipment for the production of oil or natural gas, or in the case of a dry hole, the reporting of abandonment to the appropriate agency.

Differential—The difference between a benchmark price of oil and natural gas, such as the NYMEX crude oil spot, and the wellhead price received.

Field—An area consisting of either a single reservoir or multiple reservoirs, all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

GAAP—Accounting principles generally accepted in the United States of America.

Gross acres or gross wells—The total acres or wells, as the case may be, in which a working interest is owned.

MBbl—One thousand barrels of crude oil or condensate.

MBoe—One thousand barrels of oil equivalent.

Mcf—One thousand cubic feet of natural gas.

MMBoe—One million barrels of oil equivalent.

MMcf—One million cubic feet of natural gas.

Net acres or net wells—The sum of the fractional working interests owned in gross acres or wells, as the case may be.

Net profits interest—A nonoperating interest that creates a share in gross production from an operating or working interest in oil and natural gas properties. The share is measured by net profits from the sale of production after deducting costs associated with that production.

NYMEX—New York Mercantile Exchange.

NYSE—New York Stock Exchange.

Plugging and abandonment—Activities to remove production equipment and seal off a well at the end of a well’s economic life.

Reservoir—A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

Working interest—The right granted to the lessee of a property to explore for and to produce and own oil, natural gas, or other minerals. The working interest owners bear the exploration, development, and operating costs on either a cash, penalty, or carried basis.

PART I—FINANCIAL INFORMATION

PERMIANVILLE ROYALTY TRUST

Statements of Assets, Liabilities and Trust Corpus

The accompanying notes are an integral part of these financial statements.

PERMIANVILLE ROYALTY TRUST

Statements of Distributable Income

(unaudited)

The accompanying notes are an integral part of these financial statements.

PERMIANVILLE ROYALTY TRUST

Statements of Changes in Trust Corpus

(unaudited)

The accompanying notes are an integral part of these financial statements.

PERMIANVILLE ROYALTY TRUST
NOTES TO FINANCIAL STATEMENTS
(unaudited)

1.       TRUST ORGANIZATION AND PROVISIONS

Permianville Royalty Trust (the “Trust”), previously known as Enduro Royalty Trust, is a Delaware statutory trust formed in May 2011 pursuant to a trust agreement (the “Trust Agreement”) among Enduro Resource Partners LLC (“Enduro”), as trustor, The Bank of New York Mellon Trust Company, N.A. (the “Trustee”), as trustee, and Wilmington Trust Company (the “Delaware Trustee”), as Delaware Trustee.

The Trust was created to acquire and hold for the benefit of the Trust unitholders a net profits interest representing the right to receive 80% of the net profits from the sale of oil and natural gas production from certain properties in the states of Texas, Louisiana and New Mexico held by Enduro as of the date of the conveyance of the net profits interest to the Trust (the “Net Profits Interest”). The properties in which the Trust holds the Net Profits Interest are referred to as the “Underlying Properties.”

In connection with the closing of the initial public offering in November 2011, Enduro contributed the Net Profits Interest to the Trust in exchange for 33,000,000 units of beneficial interest in the Trust (the “Trust Units”). On August 31, 2018, COERT Holdings 1 LLC (“COERT” or the “Sponsor”) acquired from Enduro the Underlying Properties and all of the outstanding Trust Units owned by Enduro (the “Sale Transaction”). In connection with the Sale Transaction, COERT assumed all of Enduro’s obligations under the Trust Agreement and other instruments to which Enduro and the Trustee were parties. As of September 30, 2020, the Sponsor owned 8,600,000 Trust Units, or 26% of the issued and outstanding Trust Units.

The Net Profits Interest is passive in nature and neither the Trust nor the Trustee has any management control over or responsibility for costs relating to the operation of the Underlying Properties. The Amended and Restated Trust Agreement provides, among other provisions, that:

PERMIANVILLE ROYALTY TRUST
NOTES TO FINANCIAL STATEMENTS - Continued
(unaudited)

2.       BASIS OF PRESENTATION

The Statement of Assets, Liabilities and Trust Corpus as of December 31, 2019, which has been derived from audited financial statements, and the unaudited interim financial statements as of September 30, 2020 and for the three and nine months ended September 30, 2020 and 2019 have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain information and disclosures normally included in annual financial statements have been condensed or omitted pursuant to those rules and regulations. Therefore, these financial statements should be read in conjunction with the financial statements and notes thereto included in the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2019 (the “2019 Annual Report on Form 10-K”).

In the opinion of the Trustee, the accompanying unaudited financial statements reflect all adjustments, consisting only of normal, recurring accrual adjustments, that are necessary for a fair presentation of the interim periods presented and include all the disclosures necessary to make the information presented not misleading. These interim results are not necessarily indicative of results for a full year.

The preparation of financial statements requires the Trustee to make estimates and assumptions that affect reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Although the Trustee believes that these estimates are reasonable, actual results could differ from those estimates.

The Trust uses the modified cash basis of accounting to report Trust receipts of income from the Net Profits Interest and payments of expenses incurred. The Net Profits Interest represents the right to receive revenues (oil and natural gas sales), less direct operating expenses (lease operating expenses and production and property taxes) and development expenses of the Underlying Properties, multiplied by 80%. Cash distributions of the Trust are made based on the amount of cash received by the Trust pursuant to terms of the Conveyance creating the Net Profits Interest.

Under the terms of the Conveyance, the monthly Net Profits Interest calculation includes oil and natural gas revenues received during the relevant month. Monthly operating expenses and capital expenditures represent estimated incurred expenses and, as a result, represent accrued expenses as well as expenses paid during the period.

The financial statements of the Trust are prepared on the following basis:

(a) Income from Net Profits Interest is recorded when distributions are received by the Trust;

(b) Distributions to Trust unitholders are recorded when paid by the Trust;

(c) Trust general and administrative expenses (which includes the Trustee’s fees as well as accounting, engineering, legal, and other professional fees) are recorded when paid;

(d) Cash reserves for Trust expenses may be established by the Trustee for certain future expenditures that would not be recorded as contingent liabilities under accounting principles generally accepted in the United States of America (“GAAP”);

(e) Amortization of the Net Profits Interest in oil and natural gas properties is calculated on a unit-of-production basis and is charged directly to the Trust corpus; and

(f) The Net Profits Interest in oil and natural gas properties is periodically assessed whenever events or circumstances indicate that the aggregate value may have been impaired below its total capitalized cost based on the Underlying Properties. If an impairment loss is indicated by the carrying amount of the assets exceeding the sum of the undiscounted expected future net cash flows of the Net Profits Interest, then an impairment loss is recognized for the amount by which the carrying amount of the asset exceeds its estimated fair value determined using discounted cash flows.

The financial statements of the Trust differ from financial statements prepared in accordance with GAAP because revenues are not accrued; certain cash reserves may be established for contingencies which would not be accrued in financial statements prepared in accordance with GAAP; general and administrative expenses are recorded when paid instead of when incurred; and amortization of the net profits interest calculated on a unit-of-production basis is charged directly to trust corpus instead of as an expense. While these statements differ from financial statements prepared in accordance with GAAP, the modified cash basis of reporting is considered to be the most meaningful because monthly distributions to the Trust unitholders are based on net cash receipts.

This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the SEC as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

PERMIANVILLE ROYALTY TRUST
NOTES TO FINANCIAL STATEMENTS - Continued
(unaudited)

3.        NET PROFITS INTEREST IN OIL AND NATURAL GAS PROPERTIES

The Net Profits Interest in oil and natural gas properties was recorded at its fair value on the date of conveyance. Amortization of the Net Profits Interest in oil and natural gas properties is calculated on a unit-of-production basis based on the Underlying Properties’ production and reserves. As the Trust uses the modified cash basis of accounting, amortization is recognized only in those months in which income from net profits interest exceeds capital expenditures. The reserves upon which the amortization rate is based are quantity estimates that are subject to numerous uncertainties inherent in the estimation of proved reserves. The volumes considered to be commercially recoverable fluctuate with changes in commodity prices and operating costs. These estimates are expected to change as additional information becomes available in the future. Downward revisions in proved reserves may result in an increased rate of amortization. Amortization is charged directly to the Trust corpus balance and does not affect the distributable income of the Trust. Accumulated amortization as of September 30, 2020 and December 31, 2019 was $283,986,545 and $279,925,202, respectively.

The Net Profits Interest is periodically assessed for impairment whenever events or circumstances indicate that the current fair value based on expected future cash flows of the Underlying Properties may be less than the carrying value of the Net Profits Interest. While the Trust did not record an impairment during the nine months ended September 30, 2020 or 2019, future downward revisions in actual production volumes relative to current forecasts, higher than expected operating costs, or lower than anticipated commodity prices could result in recognition of impairment in future periods.

4.       INCOME TAXES

Federal Income Taxes

For federal income tax purposes, the Trust is a grantor trust and therefore is not subject to tax at the trust level. Trust unitholders are treated as owning a direct interest in the assets of the Trust, and each Trust unitholder is taxed directly on his or her pro rata share of the income and gain attributable to the assets of the Trust and entitled to claim his or her pro rata share of the deductions and expenses attributable to the assets of the Trust. The income of the Trust is deemed to have been received or accrued by each unitholder at the time such income is received or accrued by the Trust rather than when distributed by the Trust.

The deductions of the Trust consist of severance taxes and administrative expenses. In addition, each unitholder is entitled to depletion deductions because the Net Profits Interest constitutes “economic interests” in oil and natural gas properties for federal income tax purposes. Each unitholder is entitled to amortize the cost of the Trust Units through cost depletion over the life of the Net Profits Interest or, if greater, through percentage depletion. Unlike cost depletion, percentage depletion is not limited to a unitholder’s depletable tax basis in the Trust Units. Rather, a unitholder could be entitled to percentage depletion as long as the applicable Underlying Properties generate gross income.

Some Trust Units are held by a middleman, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in street name). Therefore, the Trustee considers the Trust to be a non-mortgage widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. The Bank of New York Mellon Trust Company, N.A., 601 Travis, 16^th Floor, Houston, Texas 77002, telephone number (512) 236-6545, is the representative of the Trust that will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT. Tax information is also posted by the Trustee at www.permianvilleroyaltytrust.com. Notwithstanding the foregoing, the middlemen holding units on behalf of unitholders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the U.S. Treasury Regulations with respect to such units, including the issuance of IRS Forms 1099 and certain written tax statements. Unitholders whose units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the Trust Units.

The tax consequences to a unitholder of ownership of Trust Units will depend in part on the unitholder’s tax circumstances. Unitholders should consult their tax advisors about the federal tax consequences relating to owning the Trust Units.

State Taxes

The Trust’s revenues are from sources in the states of Louisiana, New Mexico and Texas. Because it distributes all of its net income to unitholders, the Trust is not taxed at the trust level in Louisiana or New Mexico. Although the Trust does not owe tax, the Trustee is required to file a return with Louisiana reflecting the income and deductions of the Trust attributable to properties located in that state. Presently, Louisiana and New Mexico tax nonresident income from real property located within that state. Louisiana and New Mexico impose a corporate income tax which may apply to unitholders organized as corporations.

Texas does not impose a state income tax, so the Trust’s income is not subject to income tax at the trust level in Texas. Texas imposes a franchise tax at a rate of 0.75% on gross revenues less certain deductions for returns originally due on or after January 1, 2016, as specifically set forth in the Texas franchise tax statutes. Entities subject to tax generally include trusts unless otherwise exempt. Trusts that receive at least 90% of their federal gross income from designated passive sources, including royalties from mineral properties and other income from other non-operating mineral interests, and do not receive more than 10% of their income from operating an active trade or business, generally are exempt from the Texas franchise tax as “passive entities.” Although the Trust is intended to be exempt from Texas franchise tax at the trust level as a passive entity, each unitholder that is considered a taxable entity under the Texas franchise tax would generally be required to include its portion of Trust net income in its own Texas franchise tax computation.

Each unitholder should consult his or her own tax advisor regarding state tax requirements, if any, applicable to such person’s ownership of Trust Units.

5.       DISTRIBUTIONS TO UNITHOLDERS

Each month, the Trustee determines the amount of funds available for distribution to the Trust unitholders. Available funds are the excess cash, if any, received by the Trust from the Net Profits Interest and other sources (such as interest earned on any amounts reserved by the Trustee) that month, over the Trust’s liabilities for that month, subject to adjustments for changes made by the Trustee during the month in any cash reserves established for future liabilities of the Trust. Distributions are made to the holders of Trust Units as of the applicable record date (generally the last business day of each calendar month) and are payable on or before the 10th business day after the record date.

The following table provides information regarding the Trust’s distributions per unit paid during the periods indicated:

In July and August 2020, the direct operating and development expenses exceeded revenues, causing the net profits to be negative. As a result, there were no distributions to the Trust unitholders in August and September 2020, respectively.

In December 2018, the direct operating and development expenses exceeded revenues, causing the net profits to be negative. This was primarily due to the delay in transitioning operator reporting for the Underlying Properties to the Sponsor, thus reducing the cash receipts to the Trust for this period. As a result, there were no net profits reported in December 2018 to be distributed to the Trust unitholders in January 2019. In January 2019, net profits from the Underlying Properties were positive, and the aggregate shortfall in net profits of $667,227 from December 2018 was deducted from such net profits when calculating the distribution paid in February 2019.

6.       ADVANCES TO THE TRUST

From time to time, if the Trust’s cash on hand (including available cash reserves, if any) is not sufficient to pay the Trust’s ordinary course administrative expenses that are due prior to the monthly payment to the Trust of proceeds from the Net Profits Interest, COERT may advance funds to the Trust to pay such expenses. Such advances are recorded as a liability on the Statements of Assets, Liabilities and Trust Corpus until repaid. As of September 30, 2020 and December 31, 2019, advances to the Trust were $159,071 and $34,818, respectively.

7.       TRUSTEE FEES

Under the terms of the Trust Agreement, the Trust pays an administrative fee of $200,000 per year to the Trustee and an annual fee of $2,000 to the Delaware Trustee. During the three- and nine-month periods ended September 30, 2020 and 2019, the Trust paid $50,000 and $150,000, respectively, to the Trustee pursuant to the terms of the Trust Agreement. During the three- and nine-month periods ended September 30, 2020 and 2019, the Trust paid $0 and $2,000, respectively, to the Delaware Trustee pursuant to the terms of the Trust Agreement.

8.       2017 DIVESTITURE PROPERTIES HOLDBACK AMOUNT

In September 2017, Enduro completed the sale of certain properties in the Permian Basin. In connection with the sale, Enduro withheld $750,000 (the “Holdback Amount”) from the net proceeds allocable to the Trust to cover possible indemnification obligations under the related purchase and sale agreements arising within 25 months of the closing of the transactions, or by the end of October 2019 (the “Indemnification Term”). In connection with the Sale Transaction, Enduro released the Holdback Amount to the Trustee on September 4, 2018, with the Trustee announcing that it would continue to retain the Holdback Amount for the remainder of the Indemnification Term. The Trustee announced in September 2019 that it would release the Holdback Amount, totaling approximately $752,000, including interest, as part of the Trust distribution to unitholders payable in October 2019.

9.       SUBSEQUENT EVENTS

On October 15, 2020, the Trust announced that there would be no distribution to the Trust unitholders in November 2020 as a result of the cumulative outstanding net profits shortfall.

References to the “Trust” in this document refer to Permianville Royalty Trust, previously known as Enduro Royalty Trust, while references to “COERT” or the “Sponsor” in this document refer to COERT Holdings 1 LLC. References to “Enduro” in this document refer to Enduro Resource Partners LLC, the original sponsor of the Trust. The following review of the Trust’s financial condition and results of operations should be read in conjunction with the financial statements and notes thereto, as well as Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the Trust’s 2019 Annual Report on Form 10-K. The Trust’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all other filings with the SEC are available on the SEC’s website at www.sec.gov.

Forward-Looking Statements

This Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included in this Form 10-Q, including without limitation the statements under this “Trustee’s Discussion and Analysis of Financial Condition and Results of Operations” are forward-looking statements. Such statements may be influenced by factors that could cause actual outcomes and results to differ materially from those projected. No assurance can be given that such expectations will prove to have been correct. When used in this document, the words “believes,” “expects,” “anticipates,” “intends” or similar expressions are intended to identify such forward-looking statements. The following important factors, in addition to those discussed elsewhere in this Form 10-Q, in the Trust’s 2019 Annual Report on Form 10-K and the Trust’s other filings with the SEC could affect the future results of the energy industry in general, and COERT and the Trust in particular, and could cause actual results to differ materially from those expressed in such forward-looking statements:

You should not place undue reliance on these forward-looking statements. All forward-looking statements speak only as of the date of this Form 10-Q. The Trust does not undertake any obligation to release publicly any revisions to the forward-looking statements to reflect events or circumstances after the date of this Form 10-Q or to reflect the occurrence of unanticipated events, unless the securities laws require us to do so.

This Form 10-Q describes other important factors that could cause actual results to differ materially from expectations of the Sponsor and the Trust, including under the caption “Risk Factors.” All forward-looking statements in this report and all subsequent written and oral forward-looking statements attributable to the Sponsor or the Trust or persons acting on behalf of the Sponsor or the Trust are expressly qualified in their entirety by such factors. The Trust assumes no obligation, and disclaims any duty, to update these forward-looking statements.

Overview

Permianville Royalty Trust, a statutory trust created in May 2011, completed its initial public offering in November 2011. The Trust’s only asset and source of income is the Net Profits Interest, which entitles the Trust to receive 80% of the net profits from oil and natural gas production from the Underlying Properties. The Net Profits Interest is passive in nature and neither the Trust nor the Trustee has any management control over or responsibility for costs relating to the operation of the Underlying Properties. Additionally, third parties operate substantially all of the wells on the Underlying Properties and, therefore, the Sponsor is not in a position to control the timing of development efforts, associated costs, or the rate of production of the reserves.

On August 31, 2018, COERT completed the acquisition from Enduro of the Underlying Properties and all of the outstanding Trust Units owned by Enduro (the “Sale Transaction”). In connection with the Sale Transaction, COERT assumed all of Enduro’s obligations under the Amended and Restated Trust Agreement of the Trust and other instruments to which Enduro and the Trustee were parties.

The Trust is required to make monthly cash distributions of substantially all of its monthly cash receipts, after deducting the Trust’s administrative expenses, to the holders of Trust Units as of the applicable record date (generally the last business day of each calendar month) on or before the 10^th business day after the record date. The Net Profits Interest is entitled to a share of the profits from and after July 1, 2011 attributable to production occurring on or after June 1, 2011. The amount of Trust revenues and cash distributions to Trust unitholders depends on, among other things:

Generally, the Sponsor receives cash payment for oil production 30 to 60 days after it is produced and for natural gas production 60 to 90 days after it is produced.

New York Stock Exchange Listing Status.

As previously disclosed, on September 25, 2020, the Trust received written notification from the New York Stock Exchange (“NYSE”) that the Trust no longer satisfied the continued listing compliance standards set forth under Section 802.01C of the NYSE Listed Company Manual because the average closing price of the Trust’s units of beneficial interest fell below $1.00 over a 30 consecutive trading-day period that ended September 24, 2020. If the Trust is unable to regain compliance with the applicable standards within a six-month cure period, the NYSE will commence suspension and delisting procedures. If delisted by the NYSE, the Trust units may be transferred to the over-the-counter market. During the cure period, the Trust units will continue to trade on the NYSE, subject to compliance with other continued listing requirements.

Outlook

The outlook for development activity for the Underlying Properties during the remainder of 2020 remains uncertain given the significant oil and natural gas price volatility experienced since the beginning of 2020. The West Texas Intermediate spot price of crude oil has dropped sharply from $61.17 per barrel on January 2, 2020 to $35.79 per barrel on October 30, 2020, but in the interim ranged widely in response to the economic effects of the COVID-19 pandemic and the dispute over production levels between Russia and the members of OPEC. COVID-19 has resulted in widespread and localized health crises that adversely affect general commercial activity, the economies and financial markets of many countries and localities, as well as global demand for oil and natural gas. COVID-19 also has resulted in significant business and operational disruptions, including business closures, disruptions to supply chains, travel restrictions and limitations on the availability of workforces. The full impact of COVID-19 is unknown and is rapidly evolving, and it is not possible to reliably estimate the impact that these developments will have on future periods. While oil prices have recently stabilized and the demand for oil and refined products has improved from the lows experienced earlier this year, a prolonged period of low crude oil and natural gas prices will adversely affect the operators of the Underlying Properties. If commodity prices for crude oil and natural gas remain volatile and below historical levels, monthly cash distributions to unitholders will be substantially lower than historical distributions, and in certain periods there may be no distribution to unitholders.

In response to the drop in commodity prices, a number of the operators on the Underlying Properties elected to defer production sales or temporarily shut-in some of the producing wells on the Underlying Properties, which negatively affected recent reported production. However, the Sponsor has reported to the Trustee that various operators of the Underlying Properties have indicated plans to return production to prior, pre-shut-in levels.

As previously disclosed, the Sponsor anticipated 2020 capital expenditures to range from $4 million to $6 million attributable to the properties in which the Trust owns a net profits interest, or $3 million to $5 million net to the Trust’s 80% net profits interest. Given publicly announced reduced capital spending plans by a number of the operators of the Underlying Properties in response to current crude oil prices, the Sponsor now expects the previously anticipated capital expenditures to be at the low end or below the projected range. The Sponsor maintains significant liquidity and financial flexibility to respond to the operational and capital spending changes of the operators of the Underlying Properties. The Underlying Properties also have exposure to natural gas reserves in the Haynesville shale and other properties, where commodity prices and capital markets activity have held up in contrast to oil prices. The Sponsor will continue to monitor and possibly participate in future capital projects in 2020 as operators shift from oil weighted to gas weighted projects.

Results of Operations

Three Months Ended September 30, 2020 Compared to Three Months Ended September 30, 2019

The Trust’s net profits income consists of monthly net profits attributable to the Net Profits Interest, which was determined as shown in the following table:

During the three months ended September 30, 2020, there were two months in which direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative. As a result, there were no distributions to Trust unitholders in August and September 2020, respectively. This resulted in an aggregate net profits shortfall of $2.7 million, prior to repayment of Sponsor advances, as of August 30, 2020. For September 2020, excluding prior net profits interest shortfalls, income from the distributable net profits interest was approximately $0.5 million which would have been distributed in October 2020. The $0.5 million reduced the aggregate shortfall to approximately $2.2 million, prior to repayment of Sponsor advances, as of September 30, 2020. This aggregate shortfall will be carried forward to be deducted from future net profits generated by the Underlying Properites. As net profits for the two months were negative and therefore no distributions were paid to unitholders with respect to these two months, the corresponding revenues and associated direct operating and development expenses are excluded from the calculation of distributable income for the three months ended September 30, 2020 detailed in the table above as well as the related sales volumes detailed below.

The following table displays reported oil and natural gas sales volumes and average prices from the Underlying Properties, representing the amounts included in the net profits calculation for distributions paid during the three months ended September 30, 2020 and 2019:

Income from Net Profits Interest for the three months ended September 30, 2020 is calculated from the following:

Net profits attributable to the Underlying Properties for the three months ended September 30, 2020 were $0.2 million compared to $3.7 million for the three months ended September 30, 2019. As a result of direct operating expenses and development expenses exceeding oil and natural gas sales for two months during the period, the Trust did not pay a distribution to unitholders in August and September 2020. Accordingly, under the modified cash basis of accounting, the oil and natural gas sales, direct operating expenses and development expenses for such periods were not included in the three months ended September 30, 2020 and instead will be included in a future period once the shortfall has been recouped. Therefore, several variances between the periods are due to the inclusion of only one month of results in the three months ended September 30, 2020 compared to three months during the quarter ended September 30, 2019. The $3.5 million decrease in net profits attributable to the Underlying Properties from the 2019 period to the 2020 period was primarily due to the following items:

For the three months ended September 30, 2020, the Trust withheld $0.1 million, and paid $0.1 million for general and administrative expenses. Expenses paid during the period primarily consisted of fees for the preparation of the Trust’s monthly press releases, financial statement audit fees, and Trustee fees. For the three months ended September 30, 2019, the Trust withheld $0.2 million, and paid $0.2 million for general and administrative expenses.

Nine Months Ended September 30, 2020 Compared to Nine Months Ended September 30, 2019

The Trust’s net profits income consists of monthly net profits attributable to the Net Profits Interest, which was determined as shown in the following table:

During the nine months ended September 30, 2020, there were two months in which direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative. As a result, there were no distributions to Trust unitholders in August and September 2020, respectively. This resulted in an aggregate net profits shortfall of $2.7 million, prior to repayment of Sponsor advances, as of August 30, 2020. For September 2020, excluding prior net profits interest shortfalls, income from the distributable net profits interest was approximately $0.5 million which would have been distributed in October 2020. The $0.5 million reduced the aggregate shortfall to approximately $2.2 million, prior to repayment of Sponsor advances, as of September 30, 2020. This aggregate shortfall will be carried forward to be deducted from future net profits generated by the Underlying Properites. As net profits for the two months were negative and therefore no distributions were paid to unitholders with respect to these two months, the corresponding revenues and associated direct operating and development expenses are excluded from the calculation of distributable income for the nine months ended September 30, 2020 detailed in the table above as well as the related sales volumes detailed below.

During the nine months ended September 30, 2019, some third-party operators of the Underlying Properties encountered delays in transitioning their reporting processes from Enduro to the Sponsor, which reduced the reported cash receipts to the Trust for this period when compared to the nine months ended September 30, 2020. A majority of these reporting issues were addressed, with a majority of the revenues held in suspense as a result of these delays having been distributed to the Trust as part of the March 2019 distribution of $0.076357 per unit, which was paid on April 15, 2019.

The following table displays reported oil and natural gas sales volumes and average prices from the Underlying Properties, representing the amounts included in the net profits calculation for distributions paid during the nine months ended September 30, 2020 and 2019:

Income from Net Profits Interest for the nine months ended September 30, 2020 is calculated from the following:

Net profits attributable to the Underlying Properties for the nine months ended September 30, 2020 were $7.0 million compared to $9.6 million for the nine months ended September 30, 2019. As a result of direct operating expenses and development expenses exceeding oil and natural gas sales for two months during the period, the Trust did not pay a distribution to unitholders in August and September 2020. Accordingly, under the modified cash basis of accounting, the oil and natural gas sales, direct operating expenses and development expenses for such periods were not included in the nine months ended September 30, 2020 and instead will be included in a future period once the net profits shortfall has been recouped. Therefore, several variances between the periods are due to the inclusion of only seven months of results in the nine months ended September 30, 2020 compared to nine months during the nine-month period ended September 30, 2019. The $2.7 million decrease in net profits attributable to the Underlying Properties from the 2019 period to the 2020 period was primarily due to the following items:

As previously disclosed, in January 2019, the Sponsor completed the sale of certain of the Underlying Properties located in Glasscock County, Texas for a total purchase price of approximately $62,000 (approximately $49,000 net to the Trust’s 80% net profits interest). Also in January 2019, the Sponsor entered into a lease arrangement with a private equity backed operator with respect to a portion of the mineral rights relating to certain of the Underlying Properties located in Gaines County, Texas (no current production is associated with these mineral acres), for total proceeds of $160,000 ($128,000 net to the Trust’s 80% net profits interest).

For the nine months ended September 30, 2020, the Trust withheld $0.5 million, and paid $0.7 million for general and administrative expenses. Expenses paid during the period primarily consisted of fees for the preparation of the Trust’s monthly press releases, financial statement audit fees, and Trustee fees. For the nine months ended September 30, 2019, the Trust withheld $0.6 million, and paid $0.8 million for general and administrative expenses.

Liquidity and Capital Resources

The Trust’s principal sources of liquidity are cash flow generated from the Net Profits Interest and borrowing capacity under the letter of credit described below. Other than Trust administrative expenses, including any reserves established by the Trustee for future liabilities, the Trust’s only use of cash is for distributions to Trust unitholders. Available funds are the excess cash, if any, received by the Trust from the Net Profits Interest and other sources (such as interest earned on any amounts reserved by the Trustee) in any given month, over the Trust’s expenses paid for that month. Available funds are reduced by any cash the Trustee determines to hold as a reserve against future expenses.

The Trustee may create a cash reserve to pay for future liabilities of the Trust. If the Trustee determines that the cash on hand and the cash to be received are, or will be, insufficient to cover the Trust’s liabilities, the Trustee may authorize the Trust to borrow money to pay administrative or incidental expenses of the Trust that exceed cash held by the Trust. The Trustee may authorize the Trust to borrow from any person, including the Trustee or the Delaware Trustee or an affiliate thereof, although none of the Trustee, the Delaware Trustee or any affiliate thereof intends to lend funds to the Trust. The Trustee may also cause the Trust to mortgage its assets to secure payment of the indebtedness. The terms of such indebtedness and security interest, if funds were to be loaned by the entity serving as Trustee or Delaware Trustee or an affiliate thereof, would be similar to the terms which such entity would grant to a similarly situated commercial customer with whom it did not have a fiduciary relationship. In addition, COERT has provided the Trust with a $1.2 million letter of credit to be used by the Trust if its cash on hand (including available cash reserves) is insufficient to pay ordinary course administrative expenses. Further, if the Trust requires more than the $1.2 million under the letter of credit to pay administrative expenses, COERT has agreed to loan funds to the Trust necessary to pay such expenses. Any loan made by COERT to the Trust would be evidenced by a written promissory note, be on an unsecured basis, and have terms that are no less favorable to COERT than those that would be obtained in an arm’s length transaction between COERT and an unaffiliated third party. If the Trust borrows funds or draws on the letter of credit, no further distributions will be made to Trust unitholders until such amounts borrowed or drawn are repaid. Except for the foregoing, the Trust has no source of liquidity or capital resources. The Trustee has no current plans to authorize the Trust to borrow any funds. At September 30, 2020 and December 31, 2019, the Trust held cash of $63,598 and $90,665, respectively, for future Trust expenses. Since its formation, the Trust has not borrowed any funds and no amounts have been drawn on the letter of credit.

From time to time, if the Trust’s cash on hand (including available cash reserves, if any) is not sufficient to pay the Trust’s ordinary course administrative expenses that are due prior to the monthly payment to the Trust of proceeds from the Net Profits Interest, COERT may advance funds to the Trust to pay such expenses. At September 30, 2020 and December 31, 2019, there was an outstanding advance of $159,071 and $34,818, respectively. The full amount of the advance to the Trust will be repaid out of the funds payable to the Trust relating to the monthly operational update announced on September 18, 2020.

In connection with Enduro’s sale of certain properties in the Permian Basin completed in September 2017, Enduro withheld $750,000 (the “Holdback Amount”) from the net proceeds allocable to the Trust to cover possible indemnification obligations under the related purchase and sale agreements arising within 25 months of the closing of the transactions, or by the end of October 2019 (the “Indemnification Term”). In connection with the Sale Transaction, Enduro released the Holdback Amount to the Trustee on September 4, 2018, with the Trustee announcing that it would continue to retain the Holdback Amount for the remainder of the Indemnification Term. In September 2019, the Trustee announced the release of the Holdback Amount, totaling approximately $752,000, including interest, which was distributed to unitholders in October 2019.

Cash held by the Trustee as a reserve against future liabilities or for distribution at the next distribution date may be held in a noninterest-bearing account or may be invested in:

The Trust pays the Trustee an annual administrative fee of $200,000 and the Delaware Trustee an annual fee of $2,000. The Trust also incurs, either directly or as a reimbursement to the Trustee, legal, accounting, tax and engineering fees, printing costs and other expenses that are deducted by the Trust before distributions are made to Trust unitholders. The Trust also is responsible for paying other expenses incurred as a result of being a publicly traded entity, including costs associated with annual and quarterly reports to Trust unitholders, tax return and Form 1099 preparation and distribution, NYSE listing fees, independent auditor fees and registrar and transfer agent fees.

The Trust does not have any transactions, arrangements or other relationships with unconsolidated entities or persons that could materially affect the Trust’s liquidity or the availability of capital resources.

Distributions Declared After Quarter End

The Trust did not declare any distributions after the end of the quarter.

Off-Balance Sheet Arrangements

The Trust has no off-balance sheet arrangements. The Trust has not guaranteed the debt of any other party, nor does the Trust have any other arrangements or relationships with other entities that could potentially result in unconsolidated debt, losses or contingent obligations.

Critical Accounting Policies and Estimates

Please read “Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates” of the Trust’s 2019 Annual Report on Form 10-K for additional information regarding the Trust’s critical accounting policies and estimates. There were no material changes to the Trust’s critical accounting policies or estimates during the nine months ended September 30, 2020.

Subsequent Events

On October 15, 2020, the Trust announced that there would be no distribution to the Trust unitholders in November 2020 as a result of the cumulative outstanding net profits shortfall.

As a “smaller reporting company” as defined in Item 10(f)(1) of Regulation S-K, the Trust is not required to provide information required by this Item.

Evaluation of Disclosure Controls and Procedures

The Trustee conducted an evaluation of the Trust’s disclosure controls and procedures (as defined in Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)). Based on this evaluation, the Trustee has concluded that the disclosure controls and procedures of the Trust were effective, as of the end of the period covered by this report, in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Exchange Act is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure.

Due to the nature of the Trust as a passive entity and in light of the contractual arrangements pursuant to which the Trust was created, including the provisions of (i) the Trust Agreement and (ii) the Conveyance, the Trustee’s disclosure controls and procedures related to the Trust necessarily rely on (A) information provided by the Sponsor, including information relating to results of operations, the costs and revenues attributable to the Trust’s interest under the Conveyance and other operating and historical data, plans for future operating and capital expenditures, reserve information, information relating to projected production, and other information relating to the status and results of operations of the Underlying Properties and the Net Profits Interest, and (B) conclusions and reports regarding reserves by the Trust’s independent reserve engineers.

Changes in Internal Control over Financial Reporting

As of the end of the period covered by this report, there were no changes in the Trust’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Trust’s internal control over financial reporting. The Trustee notes for purposes of clarification that it has no authority over, and makes no statement concerning, the internal control over financial reporting of the Sponsor.

PART II—OTHER INFORMATION

Except as provided below, there have been no material changes to the risk factors contained in Item 1A of the Trust’s 2019 Annual Report on Form 10-K.

The COVID-19 pandemic could materially adversely affect proceeds to the Trust and cash distributions to unitholders.

The recent outbreak of the novel form of coronavirus known as COVID-19 and its development into a global pandemic has had, and continues to have, a negative impact on worldwide economic and commercial activity and financial markets, as well as global demand for crude oil and natural gas.  The West Texas Intermediate spot price of crude oil has dropped sharply from $61.17 per barrel on January 2, 2020 to $35.79 per barrel on October 30, 2020, but in the interim ranged widely in response to the economic effects of the COVID-19 pandemic and the dispute over production levels between Russia and the members of OPEC. COVID-19 has resulted in widespread and localized health crises that adversely affect general commercial activity, the economies and financial markets of many countries and localities, as well as global demand for oil and natural gas. COVID-19 also has resulted in significant business and operational disruptions, including business closures, disruptions to supply chains, travel restrictions and limitations on the availability of workforces. The full impact of COVID-19 is unknown and is rapidly evolving, and it is not possible to reliably estimate the impact that these developments will have on future periods. The extent to which the COVID-19 pandemic negatively affects the operators of and production from the Underlying Properties will depend on the severity, location and duration of the effects and spread of COVID-19, the actions undertaken by federal, state and local governments and health officials to contain the virus or treat its effects, and how quickly and to what extent economic conditions improve and normal business and operating conditions resume. A prolonged period of low crude oil and natural gas prices will adversely affect the operators of the Underlying Properties. If commodity prices for crude oil and natural gas remain volatile and below historical levels, monthly cash distributions to unitholders will be substantially lower than historical distributions, and in certain periods there may be no distribution to unitholders. Continued low oil and natural gas prices may ultimately reduce the amount of oil and natural gas that is economically viable to produce from the Underlying Properties. As a result, the operators of the Underlying Properties could determine during periods of low commodity prices to shut-in or curtail production from wells on the Underlying Properties, or even plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. Specifically, an operator may abandon any well or property if it reasonably believes that the well or property can no longer produce oil or natural gas in commercially paying quantities, which could result in termination of the Net Profits Interest relating to the abandoned well or property. Future downward revisions in actual production volumes relative to current forecasts, higher than expected operating costs, or lower than anticipated commodity prices could result in recognition of impairment in future periods.

To the extent COVID-19 adversely affects production from the Underlying Properties or the business, results of operations and financial condition of the operators of the Underlying Properties, it may also have the effect of heightening many of the other risks described in the Trust’s 2019 Annual Report on Form 10-K.

The ability or willingness of OPEC and other oil exporting nations to set and maintain production levels has a significant impact on oil and natural gas commodity prices, which could reduce the amount of cash available for distribution to Trust unitholders.

OPEC is an intergovernmental organization that seeks to manage the price and supply of oil on the global energy market. Actions taken by OPEC members, including those taken alongside other oil exporting nations, have a significant impact on global oil supply and pricing. For example, OPEC and certain other oil exporting nations have previously agreed to take measures, including production cuts, to support crude oil prices. In March 2020, members of OPEC and Russia considered extending and potentially increasing these oil production cuts. However, those negotiations were unsuccessful. As a result, Saudi Arabia announced an immediate reduction in export prices and Russia announced that all previously agreed upon oil production cuts would expire on April 1, 2020. These actions led to an immediate and steep decrease in oil prices, which briefly reached a closing NYMEX price low of negative $37.63 per Bbl of crude oil in April 2020. Although OPEC has since agreed to certain production cuts, prices in the oil and gas market have remained depressed, as the oversupply and lack of demand in the market persist. There can be no assurance that OPEC members and other oil exporting nations will agree to future production cuts or other actions to support and stabilize oil prices, nor can there be any assurance that they will not further reduce oil prices or increase production. Uncertainty regarding future actions to be taken by OPEC members or other oil exporting countries could lead to increased volatility in the price of oil, which could adversely affect the financial condition and economic performance of the operators of the underlying properties and may reduce the net proceeds to which the Trust is entitled, which could materially reduce or completely eliminate the amount of cash available for distribution to Trust unitholders.

If the Trust cannot meet the New York Stock Exchange continued listing requirements, the NYSE may delist the Trust units.

Under the continued listing requirements of the NYSE, a company will be considered to be out of compliance with the exchange’s minimum price requirement if the company’s average closing price over a consecutive 30 trading day period (“Average Closing Price”) is less than $1.00 (the “Minimum Price Requirement”).  Under NYSE rules, a company that is out of compliance with the Minimum Price Requirement has a cure period of six months to regain compliance if it notifies the NYSE within 10 business days of receiving a deficiency notice of its intention to cure the deficiency. A company may regain compliance if on the last trading day of any calendar month during the cure period the company has a closing share price of at least $1.00 and an average closing share price of at least $1.00 over the 30-trading-day period ending on the last trading day of that month. If at the expiration of the cure period, both a $1.00 closing share price on the last trading day of the cure period and a $1.00 average closing share price over the 30-trading-day period ending on the last trading day of the cure period are not attained, the NYSE will commence suspension and delisting procedures. If delisted by the NYSE, a company’s shares may be transferred to the over-the-counter (“OTC”) market, a significantly more limited market than the NYSE, which could affect the market price, trading volume, liquidity and resale price of such shares. Securities that trade on the OTC markets also typically experience more volatility compared to securities that trade on a national securities exchange. During the cure period, the company’s shares would continue to trade on the NYSE, subject to compliance with other continued listing requirements.

On September 25, 2020, the Trust received written notification from the NYSE that the Trust was not in compliance with the Minimum Price Requirement. Neither the Trust nor the Trustee has any control over the trading price of the Trust units, nor does the Trust have the authority to cause a reverse split of the units or to take similar action designed to affect the trading price of the units without a vote from the Trust unitholders. Even if the Trust does regain compliance, it might be unable to maintain compliance, and would again become subject to the NYSE delisting procedures.

The exhibits listed in the following index to exhibits are filed or furnished as part of this Form 10-Q.

INDEX TO EXHIBITS

SIGNATURE

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: November 6, 2020

The Registrant, Permianville Royalty Trust, has no principal executive officer, principal financial officer, board of directors or persons performing similar functions. Accordingly, no additional signatures are available, and none have been provided. In signing the report above, the Trustee does not imply that it has performed any such function or that such function exists pursuant to the terms of the Trust.