2021 INVESTOR DAY Virtual Webcast / 03.03.212021 INVESTOR DAY Virtual Webcast / 03.03.21

CAUTIONARY STATEMENT FORWARD-LOOKING STATEMENTS. Outlooks; projections; goals; estimates; discussions of earnings, cash flow, margins, and resource potential; descriptions of strategic plans and objectives; planned capital and cash operating expense reductions and the ability to meet or exceed announced reduction objectives; plans to reduce future emissions intensity and the expected resulting absolute emissions reductions; emission profiles of future developments; carbon capture results and the impact of operational and technology efforts; future business markets like carbon capture or hydrogen; the impacts of the COVID-19 pandemic and corresponding market impacts on ExxonMobil’s businesses and results; price and market recoveries; energy market evolution; recovery and production rates; rates of return; drilling programs and improvements; asset sales; reserve and resource additions; proved reserves and other resource volumes; development plans; future distributions; asset carrying values and any increases or impairments; integration benefits; and other statements of future events or conditions in this presentation or the subsequent discussion period are forward-looking statements. Actual future results could differ materially due to a number of factors. These include global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil, gas, petroleum, petrochemicals and feedstocks; company actions to protect the health and safety of employees, vendors, customers, and communities; the ability to access short- and long-term debt markets on a timely and affordable basis; the severity, length and ultimate impact of COVID-19 and government responses on people and economies; global population and economic growth; reservoir performance and depletion rates; the outcome of exploration projects and the timely completion of development and construction projects; regional differences in product concentration and demand; war, trade agreements, shipping blockades or harassment and other political, public health or security concerns; changes in law, taxes or regulation, including environmental regulations, taxes, political sanctions and international treaties; the timely granting or freeze, suspension or revocation of government permits; the resolution of contingencies and uncertain tax positions; the impact of fiscal and commercial terms and the outcome of commercial negotiations; feasibility and timing for regulatory approval of potential investments or divestments; the actions of competitors and preferences of customers; the capture of efficiencies between business lines; unexpected technological developments; general economic conditions, including the occurrence and duration of economic recessions; unforeseen technical or operating difficulties; the ability to bring new technologies to commercial scale on a cost- competitive basis, including large-scale hydraulic fracturing projects and carbon capture projects; and other factors discussed here, in Item 1A. Risk Factors in our Form 10-K for the year ended December 31, 2020 and under the heading Factors Affecting Future Results on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. The forward-looking statements and dates used in this presentation are based on management’s good faith plans and objectives as of the March 3, 2021 date of this presentation, unless otherwise stated. We assume no duty to update these statements as of any future date and neither future distribution of this material nor the continued availability of this material in archive form on our website should be deemed to constitute an update or re-affirmation of these figures as of any future date. Any future update of these figures will be provided only through a public disclosure indicating that fact. SUPPLEMENTAL INFORMATION. See the Supplemental Information included on pages 64 through 74 of this presentation for additional important information required by Regulation G for non-GAAP measures or that the company considers is useful to investors as well as definitions of terms used in the materials, including future earnings, cash flow, margins, ROCE, returns, rate of return, addressable markets, available cash from operations, operating cash flow, cash operating expenses, net cash margin, free cash, free cash flow, and resource potential. Supplemental Information also includes information on the assumptions used in these materials, including assumptions on future crude oil prices and product margins used to develop outlooks regarding future potential outcomes of current management plans. 2CAUTIONARY STATEMENT FORWARD-LOOKING STATEMENTS. Outlooks; projections; goals; estimates; discussions of earnings, cash flow, margins, and resource potential; descriptions of strategic plans and objectives; planned capital and cash operating expense reductions and the ability to meet or exceed announced reduction objectives; plans to reduce future emissions intensity and the expected resulting absolute emissions reductions; emission profiles of future developments; carbon capture results and the impact of operational and technology efforts; future business markets like carbon capture or hydrogen; the impacts of the COVID-19 pandemic and corresponding market impacts on ExxonMobil’s businesses and results; price and market recoveries; energy market evolution; recovery and production rates; rates of return; drilling programs and improvements; asset sales; reserve and resource additions; proved reserves and other resource volumes; development plans; future distributions; asset carrying values and any increases or impairments; integration benefits; and other statements of future events or conditions in this presentation or the subsequent discussion period are forward-looking statements. Actual future results could differ materially due to a number of factors. These include global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil, gas, petroleum, petrochemicals and feedstocks; company actions to protect the health and safety of employees, vendors, customers, and communities; the ability to access short- and long-term debt markets on a timely and affordable basis; the severity, length and ultimate impact of COVID-19 and government responses on people and economies; global population and economic growth; reservoir performance and depletion rates; the outcome of exploration projects and the timely completion of development and construction projects; regional differences in product concentration and demand; war, trade agreements, shipping blockades or harassment and other political, public health or security concerns; changes in law, taxes or regulation, including environmental regulations, taxes, political sanctions and international treaties; the timely granting or freeze, suspension or revocation of government permits; the resolution of contingencies and uncertain tax positions; the impact of fiscal and commercial terms and the outcome of commercial negotiations; feasibility and timing for regulatory approval of potential investments or divestments; the actions of competitors and preferences of customers; the capture of efficiencies between business lines; unexpected technological developments; general economic conditions, including the occurrence and duration of economic recessions; unforeseen technical or operating difficulties; the ability to bring new technologies to commercial scale on a cost- competitive basis, including large-scale hydraulic fracturing projects and carbon capture projects; and other factors discussed here, in Item 1A. Risk Factors in our Form 10-K for the year ended December 31, 2020 and under the heading Factors Affecting Future Results on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. The forward-looking statements and dates used in this presentation are based on management’s good faith plans and objectives as of the March 3, 2021 date of this presentation, unless otherwise stated. We assume no duty to update these statements as of any future date and neither future distribution of this material nor the continued availability of this material in archive form on our website should be deemed to constitute an update or re-affirmation of these figures as of any future date. Any future update of these figures will be provided only through a public disclosure indicating that fact. SUPPLEMENTAL INFORMATION. See the Supplemental Information included on pages 64 through 74 of this presentation for additional important information required by Regulation G for non-GAAP measures or that the company considers is useful to investors as well as definitions of terms used in the materials, including future earnings, cash flow, margins, ROCE, returns, rate of return, addressable markets, available cash from operations, operating cash flow, cash operating expenses, net cash margin, free cash, free cash flow, and resource potential. Supplemental Information also includes information on the assumptions used in these materials, including assumptions on future crude oil prices and product margins used to develop outlooks regarding future potential outcomes of current management plans. 2

AGENDA • Welcome Stephen Littleton Vice President, Investor Relations and Secretary • Growing shareholder value Darren Woods Chairman of the Board and Chief Executive Officer in a lower-carbon future • Upstream Neil Chapman Senior Vice President • Downstream and Chemical Jack Williams Senior Vice President • Financial plan Andrew Swiger Senior Vice President • Closing Darren Woods Chairman of the Board and Chief Executive Officer 3AGENDA • Welcome Stephen Littleton Vice President, Investor Relations and Secretary • Growing shareholder value Darren Woods Chairman of the Board and Chief Executive Officer in a lower-carbon future • Upstream Neil Chapman Senior Vice President • Downstream and Chemical Jack Williams Senior Vice President • Financial plan Andrew Swiger Senior Vice President • Closing Darren Woods Chairman of the Board and Chief Executive Officer 3

2021 INVESTOR DAY 2021 INVESTOR DAY

2020 PERSPECTIVE Delivered on commitments in a challenging environment while preserving long-term value • Managed global operations to supply essential energy and products with best-ever safety and reliability performance • Improved cash Opex by more than 15 percent with $3 billion of structural savings versus 2019 • Reduced capital investments by more than 30 percent while maintaining advantages and project value • Achieved 2020 emission-reduction goals and established new 2025 plans consistent with the goals of the Paris Agreement • Advanced key projects and achieved operational milestones in Guyana and the Permian Basin 52020 PERSPECTIVE Delivered on commitments in a challenging environment while preserving long-term value • Managed global operations to supply essential energy and products with best-ever safety and reliability performance • Improved cash Opex by more than 15 percent with $3 billion of structural savings versus 2019 • Reduced capital investments by more than 30 percent while maintaining advantages and project value • Achieved 2020 emission-reduction goals and established new 2025 plans consistent with the goals of the Paris Agreement • Advanced key projects and achieved operational milestones in Guyana and the Permian Basin 5

GROWING LONG-TERM SHAREHOLDER VALUE Progressing actions to highgrade portfolio and improve earnings and cash flow • Committed to delivering sustainable shareholder value • Competitively advantaged assets and investments drive strong cash flow to sustain dividend, reduce debt, and invest in the future • Significant structural cost savings and flexible Capex resilient to price cycles • Focused on industry-leading safety, reliability, and environmental performance; executing plans to deliver aggressive 2025 emission reductions • Strategy leverages experience and competitive advantages to deliver value while transitioning to a lower-carbon future, consistent with the goals of the Paris Agreement See Supplemental Information for definitions. 6GROWING LONG-TERM SHAREHOLDER VALUE Progressing actions to highgrade portfolio and improve earnings and cash flow • Committed to delivering sustainable shareholder value • Competitively advantaged assets and investments drive strong cash flow to sustain dividend, reduce debt, and invest in the future • Significant structural cost savings and flexible Capex resilient to price cycles • Focused on industry-leading safety, reliability, and environmental performance; executing plans to deliver aggressive 2025 emission reductions • Strategy leverages experience and competitive advantages to deliver value while transitioning to a lower-carbon future, consistent with the goals of the Paris Agreement See Supplemental Information for definitions. 6

GROWING SHAREHOLDER VALUE IN A LOWER-CARBON FUTUREGROWING SHAREHOLDER VALUE IN A LOWER-CARBON FUTURE

IPCC EXPECTS A DIVERSE ENERGY MIX IN ACHIEVING 2°C Multiple potential pathways to 2°C lead to wide range of projections 2040 ENERGY MIX IN IPCC LOWER 2°C SCENARIOS Quadrillion BTUs (Quads) High IPCC 2040 Wind/Solar Lower 2°C energy demand Bioenergy • Substantial efficiency gains range 19% Low-carbon Wind Other needed to offset population energy Solar demand and economic growth grows 44% Low Bioenergy Coal • Significant growth in low- Other carbon energy Coal • Oil and natural gas remain Oil / Oil & Oil / 55% Natural gas Natural gas essential 48% Natural gas still integral 2019 IAv PCC era 2 g 0 e40 IEA 2019 IPCC 2040 total energy demand average estimated demand Average Source: (left) IEA World Energy Outlook 2020; (right) IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. 8 See Supplemental Information for definitions.IPCC EXPECTS A DIVERSE ENERGY MIX IN ACHIEVING 2°C Multiple potential pathways to 2°C lead to wide range of projections 2040 ENERGY MIX IN IPCC LOWER 2°C SCENARIOS Quadrillion BTUs (Quads) High IPCC 2040 Wind/Solar Lower 2°C energy demand Bioenergy • Substantial efficiency gains range 19% Low-carbon Wind Other needed to offset population energy Solar demand and economic growth grows 44% Low Bioenergy Coal • Significant growth in low- Other carbon energy Coal • Oil and natural gas remain Oil / Oil & Oil / 55% Natural gas Natural gas essential 48% Natural gas still integral 2019 IAv PCC era 2 g 0 e40 IEA 2019 IPCC 2040 total energy demand average estimated demand Average Source: (left) IEA World Energy Outlook 2020; (right) IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. 8 See Supplemental Information for definitions.

IPCC OIL & GAS DEMAND DRIVEN BY ECONOMIC GROWTH Hard-to-decarbonize sectors meet demands from increasing population and growing prosperity GLOBAL ENERGY DEMAND IN IPCC LOWER 2°C SCENARIOS Quads • 80% of demand for oil and natural gas Wind Fuel driven by three sectors Other 21% Solar 20% Industrial Bioenergy • Natural gas into power generation and Feed industrial furnaces Power Other 13% Generation 22% Coal 24% • Oil required as industrial feedstock for Commercial consumer goods Natural Transport gas • Oil / distillate for commercial transport Oil IPCC 2040 IPCC 2040 average estimated demand Average Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios and ExxonMobil analysis. See Supplemental Information for definitions. 9 See Supplemental Information for footnotes.IPCC OIL & GAS DEMAND DRIVEN BY ECONOMIC GROWTH Hard-to-decarbonize sectors meet demands from increasing population and growing prosperity GLOBAL ENERGY DEMAND IN IPCC LOWER 2°C SCENARIOS Quads • 80% of demand for oil and natural gas Wind Fuel driven by three sectors Other 21% Solar 20% Industrial Bioenergy • Natural gas into power generation and Feed industrial furnaces Power Other 13% Generation 22% Coal 24% • Oil required as industrial feedstock for Commercial consumer goods Natural Transport gas • Oil / distillate for commercial transport Oil IPCC 2040 IPCC 2040 average estimated demand Average Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios and ExxonMobil analysis. See Supplemental Information for definitions. 9 See Supplemental Information for footnotes.

REDUCING EMISSIONS REQUIRES INNOVATION Available alternatives do not fully meet sector needs POWER GENERATION TRANSPORTATION INDUSTRIAL Need: 24/7 on-demand electricity Need: rapid refueling of energy-dense fuels Need: fuel for high-temperature processes Electricity Oil and Bioenergy Gas Wind Electricity Coal Oil and Other Gas IPCC IPCC IPCC 2040 2040 2040 Nuclear Oil and Solar Other Gas renewables Coal (e.g. hydro, geo) Other Limits of Solar / wind limited in poor resource areas Temperature intensity required for heavy Battery weight and long charging time alternatives and by intermittency manufacturing Innovations • Lower-cost CCS and hydrogen• Lower-cost biofuels and hydrogen• Lower-cost CCS and hydrogen required • Battery energy-density breakthroughs• Battery energy-density breakthroughs• Less energy-intensive processes Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios and ExxonMobil analysis of IPCC Fifth Assessment Report and Special Report 1.5. 10REDUCING EMISSIONS REQUIRES INNOVATION Available alternatives do not fully meet sector needs POWER GENERATION TRANSPORTATION INDUSTRIAL Need: 24/7 on-demand electricity Need: rapid refueling of energy-dense fuels Need: fuel for high-temperature processes Electricity Oil and Bioenergy Gas Wind Electricity Coal Oil and Other Gas IPCC IPCC IPCC 2040 2040 2040 Nuclear Oil and Solar Other Gas renewables Coal (e.g. hydro, geo) Other Limits of Solar / wind limited in poor resource areas Temperature intensity required for heavy Battery weight and long charging time alternatives and by intermittency manufacturing Innovations • Lower-cost CCS and hydrogen• Lower-cost biofuels and hydrogen• Lower-cost CCS and hydrogen required • Battery energy-density breakthroughs• Battery energy-density breakthroughs• Less energy-intensive processes Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios and ExxonMobil analysis of IPCC Fifth Assessment Report and Special Report 1.5. 10

EXXONMOBIL INNOVATIONS TO REDUCE EMISSIONS Focused on solutions for hard-to-decarbonize sectors TODAY TOMORROW • Switching coal to natural gas POWER • Cogeneration• Fuel cells for lower-cost CCS and hydrogen GENERATION • Lubricants for wind turbines • Fuels and lubricants to improve fuel COMMERCIAL efficiency TRANSPORT • Biofuels blending and distribution• Advanced biofuels long-haul trucks, • Lightweight plastics to improve vehicle aviation, marine efficiency • New materials with lower-emission • Fuel cells for lower-cost CCS and hydrogen INDUSTRIAL footprint • Less energy-intense manufacturing steel, cement, • Energy-efficient process redesign textiles, plastics processes • Carbon capture 11EXXONMOBIL INNOVATIONS TO REDUCE EMISSIONS Focused on solutions for hard-to-decarbonize sectors TODAY TOMORROW • Switching coal to natural gas POWER • Cogeneration• Fuel cells for lower-cost CCS and hydrogen GENERATION • Lubricants for wind turbines • Fuels and lubricants to improve fuel COMMERCIAL efficiency TRANSPORT • Biofuels blending and distribution• Advanced biofuels long-haul trucks, • Lightweight plastics to improve vehicle aviation, marine efficiency • New materials with lower-emission • Fuel cells for lower-cost CCS and hydrogen INDUSTRIAL footprint • Less energy-intense manufacturing steel, cement, • Energy-efficient process redesign textiles, plastics processes • Carbon capture 11

PROVEN RECORD IN ADVANCING LOW-CARBON TECHNOLOGIES Focused on solutions aligned with competitive strengths and experience Controlled Freeze LaBarge Zone™ Gorgon expansion commercial demonstration Low Carbon Solutions LaBarge created Qatar Qatar expansion CCS Low-emission LaBarge Sleipner Venture Fuels Venture plant offshore field created created C O M M E R C I A L I Z A T I O N 1986 2000 2010 2020 R & D C O L L A B O R A T I O N S Strategic Fuel cells Direct air capture Stanford Global Climate & Georgia Algae CCS alliance Energy Project Tech biofuels process Cellulosic biodiesel U.S. DOE / National labs Energy Centers Carbon capture and storage (CCS) Stanford Low-emissions fuels Strategic Energy Alliance Low-carbon technologies 12 2014 2015 2016 2018 2018PROVEN RECORD IN ADVANCING LOW-CARBON TECHNOLOGIES Focused on solutions aligned with competitive strengths and experience Controlled Freeze LaBarge Zone™ Gorgon expansion commercial demonstration Low Carbon Solutions LaBarge created Qatar Qatar expansion CCS Low-emission LaBarge Sleipner Venture Fuels Venture plant offshore field created created C O M M E R C I A L I Z A T I O N 1986 2000 2010 2020 R & D C O L L A B O R A T I O N S Strategic Fuel cells Direct air capture Stanford Global Climate & Georgia Algae CCS alliance Energy Project Tech biofuels process Cellulosic biodiesel U.S. DOE / National labs Energy Centers Carbon capture and storage (CCS) Stanford Low-emissions fuels Strategic Energy Alliance Low-carbon technologies 12 2014 2015 2016 2018 2018

SIGNIFICANT VALUE IN GROWING MARKETS ExxonMobil well positioned to capitalize across value chains through 2040 and beyond Total Addressable Production Manufacturing Markets / Sectors 1 Market: 2040 Fuels ~$6T Transport Power gen Industrial Biofuels ~$400B Transport Hydrogen ~$1T 3 Oil and Natural gas Transport Power gen Industrial 48% of energy mix 5-7% depletion per year Chemicals ~$4T Infrastructure Goods/products CO 2 Utilization Storage Carbon to CO Carbon products 2 ~$2T Carbon 1 Grows ~35% per year Capture 2 Mitigates 15% of emissions See Supplemental Information for footnotes. 13 13SIGNIFICANT VALUE IN GROWING MARKETS ExxonMobil well positioned to capitalize across value chains through 2040 and beyond Total Addressable Production Manufacturing Markets / Sectors 1 Market: 2040 Fuels ~$6T Transport Power gen Industrial Biofuels ~$400B Transport Hydrogen ~$1T 3 Oil and Natural gas Transport Power gen Industrial 48% of energy mix 5-7% depletion per year Chemicals ~$4T Infrastructure Goods/products CO 2 Utilization Storage Carbon to CO Carbon products 2 ~$2T Carbon 1 Grows ~35% per year Capture 2 Mitigates 15% of emissions See Supplemental Information for footnotes. 13 13

POSITIONED TO SUCCEED IN CARBON CAPTURE Leveraging position as the global CCS leader in a ~$2 trillion addressable market by 2040 1 TOTAL CO₂ CAPTURE Million tonnes • Leverages history and experience at scale 2 − #1 in the world for CO capture; 9 Mta capacity 2 3 − #2 in the world for CO pipelines 2 4 − #2 in the world for CO geologic storage 2 • Consistent with core capabilities and advantages − Subsurface and reservoir expertise − Project development and execution − Responsible and efficient operations 2020 2030 2040 ~$2 trillion addressable market • Advancing plans for >20 new CCS opportunities ~35% projected growth per year Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes. 14POSITIONED TO SUCCEED IN CARBON CAPTURE Leveraging position as the global CCS leader in a ~$2 trillion addressable market by 2040 1 TOTAL CO₂ CAPTURE Million tonnes • Leverages history and experience at scale 2 − #1 in the world for CO capture; 9 Mta capacity 2 3 − #2 in the world for CO pipelines 2 4 − #2 in the world for CO geologic storage 2 • Consistent with core capabilities and advantages − Subsurface and reservoir expertise − Project development and execution − Responsible and efficient operations 2020 2030 2040 ~$2 trillion addressable market • Advancing plans for >20 new CCS opportunities ~35% projected growth per year Source: IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes. 14

IMPROVING ENVIRONMENT FOR CCS DEPLOYMENT Increasing government and market recognition of CCS importance Policy support is growing Technology for hard-to-abate sectors Offsets market >$200 billion is underfunded potential by 2040 % Billion USD per year 800 100 ◄$20 billion Buildings Africa annual Transport ◄100 $/T cost Asia Pacific Industrial 400 50 North 68% America ◄30 $/T Power cost generation Europe 19% Europe 0 0 Global emissions Climate tech 2030 2040 2011-2015 2016-2020 2017 venture funding 2013-2019 NEW CCS POLICIES INTRODUCED EMISSIONS AND VENTURE FUNDING OFFSETS MARKET Source: IEA Policies Database (as of Feb 24, 2021). Source: Emissions from ExxonMobil 2019 Outlook for Energy. Venture funding Source: ExxonMobil analysis of “The Economic Potential of Article 6 of the based on ExxonMobil analysis of IEA (2020), Energy Technology Perspectives Paris Agreement and Implementation Challenges”, IETA, University of 2020, IEA, Paris https://www.iea.org/reports/energy-technology-perspectives- Maryland and CPLC. Washington, D.C. License: Creative Commons Attribution 15 2020 and PwC The State of Climate Tech 2020. CC BY 3.0 IGO.IMPROVING ENVIRONMENT FOR CCS DEPLOYMENT Increasing government and market recognition of CCS importance Policy support is growing Technology for hard-to-abate sectors Offsets market >$200 billion is underfunded potential by 2040 % Billion USD per year 800 100 ◄$20 billion Buildings Africa annual Transport ◄100 $/T cost Asia Pacific Industrial 400 50 North 68% America ◄30 $/T Power cost generation Europe 19% Europe 0 0 Global emissions Climate tech 2030 2040 2011-2015 2016-2020 2017 venture funding 2013-2019 NEW CCS POLICIES INTRODUCED EMISSIONS AND VENTURE FUNDING OFFSETS MARKET Source: IEA Policies Database (as of Feb 24, 2021). Source: Emissions from ExxonMobil 2019 Outlook for Energy. Venture funding Source: ExxonMobil analysis of “The Economic Potential of Article 6 of the based on ExxonMobil analysis of IEA (2020), Energy Technology Perspectives Paris Agreement and Implementation Challenges”, IETA, University of 2020, IEA, Paris https://www.iea.org/reports/energy-technology-perspectives- Maryland and CPLC. Washington, D.C. License: Creative Commons Attribution 15 2020 and PwC The State of Climate Tech 2020. CC BY 3.0 IGO.

CCS MORE COST EFFECTIVE THAN OTHER TECHNOLOGIES Cost of CCS is well below many carbon reduction policies 1,2 CCS COSTS FOR MITIGATING INDUSTRIAL EMISSIONS $/tonne CO for conventional technology 2 • Two-thirds of emissions from point sources 3 U.S. EV Tax Credit (2020) 450 300 conducive to CCS IPCC Carbon Price (2040) for Lower 2°C Scenarios • Mitigates emissions at costs below policy support in California Low Carbon other sectors Fuel Credit (2020) 200 • Costs well below average carbon price projected in IPCC Lower 2°C 4 − Projected to reduce cost of 2°C by >50% 100 U.S. 45Q Tax • Potential to generate tradeable carbon offsets Credit (2026) 0 Natural gas Hydrogen Steel / iron Industrial production plant plant furnace Source: National Petroleum Council report: A Roadmap to At-Scale Deployment of Carbon Capture, Use, and Storage (2019). See Supplemental Information for footnotes and definitions. 16CCS MORE COST EFFECTIVE THAN OTHER TECHNOLOGIES Cost of CCS is well below many carbon reduction policies 1,2 CCS COSTS FOR MITIGATING INDUSTRIAL EMISSIONS $/tonne CO for conventional technology 2 • Two-thirds of emissions from point sources 3 U.S. EV Tax Credit (2020) 450 300 conducive to CCS IPCC Carbon Price (2040) for Lower 2°C Scenarios • Mitigates emissions at costs below policy support in California Low Carbon other sectors Fuel Credit (2020) 200 • Costs well below average carbon price projected in IPCC Lower 2°C 4 − Projected to reduce cost of 2°C by >50% 100 U.S. 45Q Tax • Potential to generate tradeable carbon offsets Credit (2026) 0 Natural gas Hydrogen Steel / iron Industrial production plant plant furnace Source: National Petroleum Council report: A Roadmap to At-Scale Deployment of Carbon Capture, Use, and Storage (2019). See Supplemental Information for footnotes and definitions. 16

EXXONMOBIL RESEARCH TO FURTHER REDUCE CCS COSTS Targeting one-third lower cost by 2030 COST OF CCS $/tonne CO 2 • >10 years of CCS-related R&D • R&D focused on effectiveness and efficiency improvements − Advanced materials for improved capture and concentration − Design optimized for capital efficiency • Fuel cell technology concept delivers step-change in cost − Same emissions reduction with less energy − Opportunity to co-produce hydrogen or power • Deploying technology key to experience curve and Current CCS Fuel cell Other Transport & Objective lower cost technology concept R&D storage Source: ExxonMobil analysis of potential cost reduction for large scale natural gas combined cycle power generation. 17EXXONMOBIL RESEARCH TO FURTHER REDUCE CCS COSTS Targeting one-third lower cost by 2030 COST OF CCS $/tonne CO 2 • >10 years of CCS-related R&D • R&D focused on effectiveness and efficiency improvements − Advanced materials for improved capture and concentration − Design optimized for capital efficiency • Fuel cell technology concept delivers step-change in cost − Same emissions reduction with less energy − Opportunity to co-produce hydrogen or power • Deploying technology key to experience curve and Current CCS Fuel cell Other Transport & Objective lower cost technology concept R&D storage Source: ExxonMobil analysis of potential cost reduction for large scale natural gas combined cycle power generation. 17

POSITIONED TO SUCCEED IN HYDROGEN Leveraging position as a global leader in a ~$1 trillion addressable market by 2040 1 GLOBAL ENERGY DEMAND SUPPLIED BY HYDROGEN Quads • Hydrogen can decarbonize hard-to-abate sectors − Transportation (60%), power and buildings (20%), 2 and industry (20%) • Producing 1.3 Mta and advancing technology to produce low-carbon hydrogen at scale • Low-carbon hydrogen from natural gas with CCS has cost and scale advantages versus alternatives 2020 2030 2040 • Developing Rotterdam hydrogen project to ~$1 trillion addressable market demonstrate fuel cell CCS technology ~30% projected growth per year Source: IAMC 1.5°C Scenario Explorer and Data, ExxonMobil analysis of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes. 18POSITIONED TO SUCCEED IN HYDROGEN Leveraging position as a global leader in a ~$1 trillion addressable market by 2040 1 GLOBAL ENERGY DEMAND SUPPLIED BY HYDROGEN Quads • Hydrogen can decarbonize hard-to-abate sectors − Transportation (60%), power and buildings (20%), 2 and industry (20%) • Producing 1.3 Mta and advancing technology to produce low-carbon hydrogen at scale • Low-carbon hydrogen from natural gas with CCS has cost and scale advantages versus alternatives 2020 2030 2040 • Developing Rotterdam hydrogen project to ~$1 trillion addressable market demonstrate fuel cell CCS technology ~30% projected growth per year Source: IAMC 1.5°C Scenario Explorer and Data, ExxonMobil analysis of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes. 18

REDUCING EMISSIONS CONSISTENT WITH GOALS OF PARIS Plans provide affordable and reliable energy while minimizing environmental impacts 1,2,3 EXXONMOBIL AND SOCIETY’S EMISSIONS Percent reduction versus 2016 1 Society’s emissions 0.9 Paris submissions (estimated 2016 Nationally Determined Contributions) 0% 0.8 ExxonMobil GHG emissions 0.7 -25% 0.6 0.5 -50% 0.4 0.3 -75% 0.2 0.1 Hypothetical Hypothetical 1.5°C pathway 2°C pathway Net -100% 0 zero 2016 2015 2030 2045 2060 2075 See Supplemental Information for footnotes. 19REDUCING EMISSIONS CONSISTENT WITH GOALS OF PARIS Plans provide affordable and reliable energy while minimizing environmental impacts 1,2,3 EXXONMOBIL AND SOCIETY’S EMISSIONS Percent reduction versus 2016 1 Society’s emissions 0.9 Paris submissions (estimated 2016 Nationally Determined Contributions) 0% 0.8 ExxonMobil GHG emissions 0.7 -25% 0.6 0.5 -50% 0.4 0.3 -75% 0.2 0.1 Hypothetical Hypothetical 1.5°C pathway 2°C pathway Net -100% 0 zero 2016 2015 2030 2045 2060 2075 See Supplemental Information for footnotes. 19

POSITIONED FOR A LOWER-CARBON FUTURE Leveraging capabilities and expertise to reduce emissions and deliver value Low Research, develop, Operated Announced reduction Carbon commercialize GHG emissions plans to 1 Solutions >$13 Billion -6% since 2016 2025 new business to advance lower-emission solutions: absolute emissions have absolute Upstream GHG commercial CCS CCS / hydrogen, biofuels, declined since start of the emissions to drop by ~30%, 2 3 opportunities and deploy cogeneration, and efficiency Paris Agreement methane & flaring 40-50% technologies Support the goals of Global Hydrogen Renewables in CCS leader produced operations (600MW) Paris 40% 1.3 Mta #2 All-time buyer Agreement engaging in climate-related of all CO captured, 2 developing technology to of wind / solar power policy, including carbon equivalent to planting produce low-carbon H with among Oil and Gas; top 5% 2 4 5 pricing ~2 billion trees CCS at scale across all corporates See Supplemental Information for footnotes. 20POSITIONED FOR A LOWER-CARBON FUTURE Leveraging capabilities and expertise to reduce emissions and deliver value Low Research, develop, Operated Announced reduction Carbon commercialize GHG emissions plans to 1 Solutions >$13 Billion -6% since 2016 2025 new business to advance lower-emission solutions: absolute emissions have absolute Upstream GHG commercial CCS CCS / hydrogen, biofuels, declined since start of the emissions to drop by ~30%, 2 3 opportunities and deploy cogeneration, and efficiency Paris Agreement methane & flaring 40-50% technologies Support the goals of Global Hydrogen Renewables in CCS leader produced operations (600MW) Paris 40% 1.3 Mta #2 All-time buyer Agreement engaging in climate-related of all CO captured, 2 developing technology to of wind / solar power policy, including carbon equivalent to planting produce low-carbon H with among Oil and Gas; top 5% 2 4 5 pricing ~2 billion trees CCS at scale across all corporates See Supplemental Information for footnotes. 20

OIL AND GAS INVESTMENT NEEDED TO MEET DEMAND New supply required to offset depletion GLOBAL OIL SUPPLY AND DEMAND GLOBAL ENERGY DEMAND IN IPCC LOWER 2°C SCENARIOS Mbd Quads 120 525 High demand Wind t IEA STEPS demand Solar t Bioenergy Average 350 80 demand based Other on IPCC Lower 2°C scenarios Coal New supply required Natural gas 175 40 Low demand 48% Oil Decline without investment: ~7% per year 0 - 0 IPCC 2040 2019 2040 IPCC 2040 Average average estimated demand • Oil and natural gas remain essential 1 • $12 trillion of investment needed by 2040 in 2°C Source: (left) IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios; (right) Excludes biofuels. IHS, IEA, ExxonMobil analysis of IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes and definitions. 21OIL AND GAS INVESTMENT NEEDED TO MEET DEMAND New supply required to offset depletion GLOBAL OIL SUPPLY AND DEMAND GLOBAL ENERGY DEMAND IN IPCC LOWER 2°C SCENARIOS Mbd Quads 120 525 High demand Wind t IEA STEPS demand Solar t Bioenergy Average 350 80 demand based Other on IPCC Lower 2°C scenarios Coal New supply required Natural gas 175 40 Low demand 48% Oil Decline without investment: ~7% per year 0 - 0 IPCC 2040 2019 2040 IPCC 2040 Average average estimated demand • Oil and natural gas remain essential 1 • $12 trillion of investment needed by 2040 in 2°C Source: (left) IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios; (right) Excludes biofuels. IHS, IEA, ExxonMobil analysis of IAMC 1.5°C Scenario Explorer and Data, average of IPCC Lower 2°C scenarios. See Supplemental Information for footnotes and definitions. 21

INDUSTRY-LEADING ASSETS AND INVESTMENT PORTFOLIO Responsibly meeting the continued demand for oil and gas Operational excellence Capital flexibility Cash Opex 1 <0.02 LTIR $6 billion ~$35 /bbl best-ever workforce safety and in structural efficiencies by year- to maintain dividend at 10-year reliability performance in 2020 average downstream and end 2023 versus 2019 2,3 chemical margins in 2025 Upstream Downstream Chemical ~90% 30% 60% growth in high-value of 2021-2025 investments have improvement in net cash margin 4 performance products by 2027 cost-of-supply ≤$35/bbl driven primarily by conversion from major projects 5 projects at advantaged sites See Supplemental Information for footnotes and definitions. 22INDUSTRY-LEADING ASSETS AND INVESTMENT PORTFOLIO Responsibly meeting the continued demand for oil and gas Operational excellence Capital flexibility Cash Opex 1 <0.02 LTIR $6 billion ~$35 /bbl best-ever workforce safety and in structural efficiencies by year- to maintain dividend at 10-year reliability performance in 2020 average downstream and end 2023 versus 2019 2,3 chemical margins in 2025 Upstream Downstream Chemical ~90% 30% 60% growth in high-value of 2021-2025 investments have improvement in net cash margin 4 performance products by 2027 cost-of-supply ≤$35/bbl driven primarily by conversion from major projects 5 projects at advantaged sites See Supplemental Information for footnotes and definitions. 22

UPSTREAMUPSTREAM

UPSTREAM STRATEGY RECONNECT 2020 update • Reduced 2020 cash Opex by 18% versus 2019 • Deferred 2020-25 investments of ~$50 billion; value deferred with delayed Strengthening portfolio implementation competitiveness 1 • ~90% of 2021-25 Upstream investments have cost-of-supply ≤$35/bbl 2 • Finalizing >$1 billion North Sea divestment; 10 assets in market • Three new Guyana discoveries; total resource ~9 Boeb Robust pipeline of future developments• Focused exploration on industry-leading basins in Guyana-Suriname and Brazil • Met 15% methane and 25% flare reduction goals Reducing emissions • Established plans to: consistent with goals of − Reduce methane intensity by 40-50% and flaring intensity by 35-45% by the Paris Agreement 3 2025 − Eliminate routine flaring in Upstream operations by 2030 See Supplemental Information for footnotes and definitions. 24UPSTREAM STRATEGY RECONNECT 2020 update • Reduced 2020 cash Opex by 18% versus 2019 • Deferred 2020-25 investments of ~$50 billion; value deferred with delayed Strengthening portfolio implementation competitiveness 1 • ~90% of 2021-25 Upstream investments have cost-of-supply ≤$35/bbl 2 • Finalizing >$1 billion North Sea divestment; 10 assets in market • Three new Guyana discoveries; total resource ~9 Boeb Robust pipeline of future developments• Focused exploration on industry-leading basins in Guyana-Suriname and Brazil • Met 15% methane and 25% flare reduction goals Reducing emissions • Established plans to: consistent with goals of − Reduce methane intensity by 40-50% and flaring intensity by 35-45% by the Paris Agreement 3 2025 − Eliminate routine flaring in Upstream operations by 2030 See Supplemental Information for footnotes and definitions. 24

INDUSTRY-LEADING INVESTMENTS Upstream capital program prioritizing low cost-of-supply opportunities 1 UPSTREAM INVESTMENTS Brent $/bbl required to generate the cost-of-supply plus 10% return 45 • Industry-leading investments focus on highest-return, lowest cost-of-supply opportunities $40/bbl Brent • Developing projects at less than $40/bbl cost-of- supply 30 • ~90% of Upstream investments generate >10% returns at ≤$35/bbl 15 2 • Average return of 32% at third-party price outlooks 0 2021–2025 Cumulative Capex See Supplemental Information for footnotes and definitions. 25INDUSTRY-LEADING INVESTMENTS Upstream capital program prioritizing low cost-of-supply opportunities 1 UPSTREAM INVESTMENTS Brent $/bbl required to generate the cost-of-supply plus 10% return 45 • Industry-leading investments focus on highest-return, lowest cost-of-supply opportunities $40/bbl Brent • Developing projects at less than $40/bbl cost-of- supply 30 • ~90% of Upstream investments generate >10% returns at ≤$35/bbl 15 2 • Average return of 32% at third-party price outlooks 0 2021–2025 Cumulative Capex See Supplemental Information for footnotes and definitions. 25

HIGH-RETURN INVESTMENTS GUYANA Industry’s largest oil-play discovered in the past decade GHG intensity Exploration Resource Production ~80% >45% lower ~9 Boeb >750 Kbd success rate with 18 than Upstream average in including three additional by 2026 1 2025; zero routine flaring discoveries discoveries in 2020 by 2030 Cash flow High return Highly resilient Community support ~$3.5 billion >20% >10% >2,000 2,3 3 of operating cash flow in rate of return return at <$35/bbl Guyanese supporting 2 2025 developments 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 26 See Supplemental Information for footnotes and definitions.HIGH-RETURN INVESTMENTS GUYANA Industry’s largest oil-play discovered in the past decade GHG intensity Exploration Resource Production ~80% >45% lower ~9 Boeb >750 Kbd success rate with 18 than Upstream average in including three additional by 2026 1 2025; zero routine flaring discoveries discoveries in 2020 by 2030 Cash flow High return Highly resilient Community support ~$3.5 billion >20% >10% >2,000 2,3 3 of operating cash flow in rate of return return at <$35/bbl Guyanese supporting 2 2025 developments 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 26 See Supplemental Information for footnotes and definitions.

HIGH-RETURN INVESTMENTS GUYANA Maintaining aggressive development schedule of low cost-of-supply resource DISCOVERED RESOURCE CAPACITY Boeb Kbd 9• Liza Phase 1 achieved nameplate capacity FPSO 6 1,000 • Liza Phase 2 on schedule for start-up in 2022 Future FPSO 5 − 2H21 arrival in Guyanese waters FPSOs 6 Yellowtail • Payara FID in 2020, start-up in 2024 − Begin topside installation in 1H22 500 Yellowtail, Payara FPSO 5 & 6 3 • Sixth FPSO producing by 2027 Liza Ph 2 Liza Ph 1, • Capturing capital efficiencies through “design one, Liza Ph 2, build many” approach Liza Ph 1 and Payara 0 0 2020 2022 2024 2025 2026 2027 See Supplemental Information for definitions. 27HIGH-RETURN INVESTMENTS GUYANA Maintaining aggressive development schedule of low cost-of-supply resource DISCOVERED RESOURCE CAPACITY Boeb Kbd 9• Liza Phase 1 achieved nameplate capacity FPSO 6 1,000 • Liza Phase 2 on schedule for start-up in 2022 Future FPSO 5 − 2H21 arrival in Guyanese waters FPSOs 6 Yellowtail • Payara FID in 2020, start-up in 2024 − Begin topside installation in 1H22 500 Yellowtail, Payara FPSO 5 & 6 3 • Sixth FPSO producing by 2027 Liza Ph 2 Liza Ph 1, • Capturing capital efficiencies through “design one, Liza Ph 2, build many” approach Liza Ph 1 and Payara 0 0 2020 2022 2024 2025 2026 2027 See Supplemental Information for definitions. 27

HIGH-RETURN INVESTMENTS GUYANA Exploration success increasing value of developments ~100 MILES Stabroek Payara/Liza Mako/Uaru Yellowtail/Redtail Longtail/Turbot Haimara • Size and quality of resource enables: − Highly capital-efficient development − Extended production plateaus through facilities integration − Unmatched flexibility and optionality potential NW SE • Significant additional resource potential Penetrated reservoirs Seismic signature Pac Paco or ra a − New discoveries beneath previously identified Sta Stab broek roek Koe Koeb bi i Pay Payar ara a resource W Whi hip ptai tail l Ua Uar ru u Kaieteur Li Liza za Dee Deep p R Re ed dt tai aill Li Liza za Y Ye ellllo ow wt tai aill − Anticipate 10 exploration and appraisal wells in Ma Mak ko o 2021 including Koebi and Whiptail S Sn no oe ek k T Tr riip pllet etai aill Canje Block 59 Hammer Hammerh he ead ad U Uar aru u- -2 2 Lo Lon ng gt tai aill Stabroek Y Ye ellllo ow wt tai aill- -2 2 T Tu ur rb bo ot t Largest operated position in Guyana-Suriname T Tiillapi apia a L Long ongtai tail l 2 2 & & 3 3 Basin • Total basin potential more than 2x discovered Hai Haimar mara a resource Block 52 Pl Plu uma ma G U Y A N A • Began testing play extensions in 2020-2021 ExxonMobil interests Discoveries 2021 wells − Quality reservoirs and hydrocarbons identified in S U R I N A M E first wells in Canje, Kaieteur, and Suriname See Supplemental Information for definitions. 28HIGH-RETURN INVESTMENTS GUYANA Exploration success increasing value of developments ~100 MILES Stabroek Payara/Liza Mako/Uaru Yellowtail/Redtail Longtail/Turbot Haimara • Size and quality of resource enables: − Highly capital-efficient development − Extended production plateaus through facilities integration − Unmatched flexibility and optionality potential NW SE • Significant additional resource potential Penetrated reservoirs Seismic signature Pac Paco or ra a − New discoveries beneath previously identified Sta Stab broek roek Koe Koeb bi i Pay Payar ara a resource W Whi hip ptai tail l Ua Uar ru u Kaieteur Li Liza za Dee Deep p R Re ed dt tai aill Li Liza za Y Ye ellllo ow wt tai aill − Anticipate 10 exploration and appraisal wells in Ma Mak ko o 2021 including Koebi and Whiptail S Sn no oe ek k T Tr riip pllet etai aill Canje Block 59 Hammer Hammerh he ead ad U Uar aru u- -2 2 Lo Lon ng gt tai aill Stabroek Y Ye ellllo ow wt tai aill- -2 2 T Tu ur rb bo ot t Largest operated position in Guyana-Suriname T Tiillapi apia a L Long ongtai tail l 2 2 & & 3 3 Basin • Total basin potential more than 2x discovered Hai Haimar mara a resource Block 52 Pl Plu uma ma G U Y A N A • Began testing play extensions in 2020-2021 ExxonMobil interests Discoveries 2021 wells − Quality reservoirs and hydrocarbons identified in S U R I N A M E first wells in Canje, Kaieteur, and Suriname See Supplemental Information for definitions. 28

HIGH-RETURN INVESTMENTS PERMIAN Demonstrated ability to leverage short-cycle flexibility Resource Production GHG intensity Unique technology brings upside 1 ~10 Boeb ~700 Koebd ~50% lower >40% NPV increase from cube with more than 70% liquids net by 2025 in 2025 versus 2016 for the 3 2 developments Unconventional portfolio Cash flow Free cash Highly resilient Industry-leading Recovery >$4 billion Positive >10% 5 for Poker Lake in the of operating cash flow in achieved 4Q20 with return at <$35/bbl 4 Delaware Basin 2025 performance and flexible 6 development 4 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 29 See Supplemental Information for footnotes and definitions.HIGH-RETURN INVESTMENTS PERMIAN Demonstrated ability to leverage short-cycle flexibility Resource Production GHG intensity Unique technology brings upside 1 ~10 Boeb ~700 Koebd ~50% lower >40% NPV increase from cube with more than 70% liquids net by 2025 in 2025 versus 2016 for the 3 2 developments Unconventional portfolio Cash flow Free cash Highly resilient Industry-leading Recovery >$4 billion Positive >10% 5 for Poker Lake in the of operating cash flow in achieved 4Q20 with return at <$35/bbl 4 Delaware Basin 2025 performance and flexible 6 development 4 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 29 See Supplemental Information for footnotes and definitions.

HIGH-RETURN INVESTMENTS PERMIAN Leveraging unique competitive advantages HYDROCARBON DENSITY MAP 1 • World-class resource base of ~10 Boeb − >70% higher-margin liquids Delaware • Development plans leverage unique set of Basin competitive advantages: Midland − Large contiguous acreage position Basin ExxonMobil − Subsurface understanding acreage − Drilling and completion capability EDDY MARTIN − Demonstrated success in large-scale project execution COUNTY COUNTY • Competitive advantages are key to achieving double- MIDLAND 40 55 COUNTY miles miles digit returns at <$35/bbl − Improved capital efficiency Poker − Lower operating cost Lake − Higher resource recovery 25 miles 31 miles See Supplemental Information for footnotes and definitions. 30HIGH-RETURN INVESTMENTS PERMIAN Leveraging unique competitive advantages HYDROCARBON DENSITY MAP 1 • World-class resource base of ~10 Boeb − >70% higher-margin liquids Delaware • Development plans leverage unique set of Basin competitive advantages: Midland − Large contiguous acreage position Basin ExxonMobil − Subsurface understanding acreage − Drilling and completion capability EDDY MARTIN − Demonstrated success in large-scale project execution COUNTY COUNTY • Competitive advantages are key to achieving double- MIDLAND 40 55 COUNTY miles miles digit returns at <$35/bbl − Improved capital efficiency Poker − Lower operating cost Lake − Higher resource recovery 25 miles 31 miles See Supplemental Information for footnotes and definitions. 30

HIGH-RETURN INVESTMENTS PERMIAN Unique Poker Lake development: >2.5 Boeb net resource, >65 thousand contiguous acres POKER LAKE UNIT • Largest contiguous development in the Permian Compression and pumps − Scale is key to lower cost and capital efficiency Separation and local storage Well pads • Multi-well pad corridor design provides: − Advantaged drilling and completion costs − More efficient utilization of surface facilities Central − Lower operating and maintenance cost processing facility • Leveraging cube development to deliver 40% higher 1 net present value versus alternatives − Cube performance in line with expectations • Started up major low-cost gathering and separation facility in 2020 − Central processing facility See Supplemental Information for footnotes and definitions. 31HIGH-RETURN INVESTMENTS PERMIAN Unique Poker Lake development: >2.5 Boeb net resource, >65 thousand contiguous acres POKER LAKE UNIT • Largest contiguous development in the Permian Compression and pumps − Scale is key to lower cost and capital efficiency Separation and local storage Well pads • Multi-well pad corridor design provides: − Advantaged drilling and completion costs − More efficient utilization of surface facilities Central − Lower operating and maintenance cost processing facility • Leveraging cube development to deliver 40% higher 1 net present value versus alternatives − Cube performance in line with expectations • Started up major low-cost gathering and separation facility in 2020 − Central processing facility See Supplemental Information for footnotes and definitions. 31

HIGH-RETURN INVESTMENTS PERMIAN Exceeding operating performance plans in the Delaware Basin 1 DAILY DRILLING LATERAL FEET FRAC STAGES PER DAY • Industry-leading drilling achievements 170% 240% >100% >50% − Fastest 2-mile Upper Wolfcamp (758 lat. ft/day) Improvement Improvement − Fastest Lower Wolfcamp (495 lat. ft/day) • Technology advancements and manufacturing methodology driving frac improvements 70% 70% 2 3 • Step-change improvement in drilling and LEASE OPERATING EXPENSES DRILLING AND COMPLETION COSTS completion 100% 100% 40% >35% − Optimizing overall value (cost versus duration) Improvement Improvement • 2020 cost improvements sustainable − ~2/3 efficiency and performance gains 0% − ~1/3 market pricing 0% 2018 2019 2020 2018 2019 2020 Data indexed to 2018. See Supplemental Information for footnotes. 32HIGH-RETURN INVESTMENTS PERMIAN Exceeding operating performance plans in the Delaware Basin 1 DAILY DRILLING LATERAL FEET FRAC STAGES PER DAY • Industry-leading drilling achievements 170% 240% >100% >50% − Fastest 2-mile Upper Wolfcamp (758 lat. ft/day) Improvement Improvement − Fastest Lower Wolfcamp (495 lat. ft/day) • Technology advancements and manufacturing methodology driving frac improvements 70% 70% 2 3 • Step-change improvement in drilling and LEASE OPERATING EXPENSES DRILLING AND COMPLETION COSTS completion 100% 100% 40% >35% − Optimizing overall value (cost versus duration) Improvement Improvement • 2020 cost improvements sustainable − ~2/3 efficiency and performance gains 0% − ~1/3 market pricing 0% 2018 2019 2020 2018 2019 2020 Data indexed to 2018. See Supplemental Information for footnotes. 32

HIGH-RETURN INVESTMENTS PERMIAN >15% increase in resource recovery versus 2018 Achieving industry-leading well performance in Poker Lake 1 DELAWARE AVERAGE WELL OIL PRODUCTION RATES (365 DAYS) DELAWARE AVERAGE WELL CUMULATIVE OIL PRODUCTION Bbl/d Kbbl 300 700 2020 2019 2018 0 0 Poker ExxonMobil 6 0 12 Lake Months Source: ExxonMobil analysis Source: Peer range - IHS Markit; ExxonMobil - ExxonMobil analysis See Supplemental Information for footnotes and definitions. 33HIGH-RETURN INVESTMENTS PERMIAN >15% increase in resource recovery versus 2018 Achieving industry-leading well performance in Poker Lake 1 DELAWARE AVERAGE WELL OIL PRODUCTION RATES (365 DAYS) DELAWARE AVERAGE WELL CUMULATIVE OIL PRODUCTION Bbl/d Kbbl 300 700 2020 2019 2018 0 0 Poker ExxonMobil 6 0 12 Lake Months Source: ExxonMobil analysis Source: Peer range - IHS Markit; ExxonMobil - ExxonMobil analysis See Supplemental Information for footnotes and definitions. 33

HIGH-RETURN INVESTMENTS PERMIAN Flexible development with options to reduce spend as market changes PRODUCTION Koebd net 800 • Pace of investment set by objective to: − Maintain positive free cash ~$60/bbl − Deliver industry-leading capital efficiency − Achieve double-digit returns at <$35/bbl Production range − Strengthen balance sheet ~$50/bbl • Prioritizing highest-quality core opportunities 400 • 2021 production outlook ~400 Koebd − 7-10 rigs, 5-7 frac crews • Longer-term outlook of ~700 Koebd by 2025 − Flexibility across state and federal acreage • Unique technology program brings significant upside 0 to current planning basis 2020 2021 2025 See Supplemental Information for definitions. 34HIGH-RETURN INVESTMENTS PERMIAN Flexible development with options to reduce spend as market changes PRODUCTION Koebd net 800 • Pace of investment set by objective to: − Maintain positive free cash ~$60/bbl − Deliver industry-leading capital efficiency − Achieve double-digit returns at <$35/bbl Production range − Strengthen balance sheet ~$50/bbl • Prioritizing highest-quality core opportunities 400 • 2021 production outlook ~400 Koebd − 7-10 rigs, 5-7 frac crews • Longer-term outlook of ~700 Koebd by 2025 − Flexibility across state and federal acreage • Unique technology program brings significant upside 0 to current planning basis 2020 2021 2025 See Supplemental Information for definitions. 34

HIGH-RETURN INVESTMENTS BRAZIL BACALHAU Expanding portfolio of low cost-of-supply deepwater developments GHG intensity Capacity Resource >65% lower 220 Kbd ~1 Boeb 1 than Upstream average in 2025 with start-up in 2024 for Phase 1 Cash flow Highly resilient High return ~$1 billion >10% >15% 2 3 2,3 of operating cash flow in 2025 return at <$35/bbl rate of return 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 35 See Supplemental Information for footnotes and definitions.HIGH-RETURN INVESTMENTS BRAZIL BACALHAU Expanding portfolio of low cost-of-supply deepwater developments GHG intensity Capacity Resource >65% lower 220 Kbd ~1 Boeb 1 than Upstream average in 2025 with start-up in 2024 for Phase 1 Cash flow Highly resilient High return ~$1 billion >10% >15% 2 3 2,3 of operating cash flow in 2025 return at <$35/bbl rate of return 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 35 See Supplemental Information for footnotes and definitions.

HIGH-POTENTIAL BRAZIL EXPLORATION Leading position in one of the most prolific offshore basins in the world 1 Cutthroat-1 • Second largest IOC acreage position − 2.6 million net acres S e r g i p e B a s i n − Operate more than 60% Mairare-1* B R A Z I L • Multiple prospects averaging >1 Boeb of Urissane-1* recoverable resource Naru-1* C a m p o s • Three wells drilled B a s i n Yba-1* ExxonMobil interests 2021 wells Opal-1 − Results confirm working hydrocarbon system in 2020 wells Tita-1 outer basins − Integrating results to guide future drilling Araucaria-1* • Plan to drill up to five wells in 2021; ~$200 million S a n t o s 2 B a s i n total cost *Petrobras operated See Supplemental Information for footnotes and definitions. 36HIGH-POTENTIAL BRAZIL EXPLORATION Leading position in one of the most prolific offshore basins in the world 1 Cutthroat-1 • Second largest IOC acreage position − 2.6 million net acres S e r g i p e B a s i n − Operate more than 60% Mairare-1* B R A Z I L • Multiple prospects averaging >1 Boeb of Urissane-1* recoverable resource Naru-1* C a m p o s • Three wells drilled B a s i n Yba-1* ExxonMobil interests 2021 wells Opal-1 − Results confirm working hydrocarbon system in 2020 wells Tita-1 outer basins − Integrating results to guide future drilling Araucaria-1* • Plan to drill up to five wells in 2021; ~$200 million S a n t o s 2 B a s i n total cost *Petrobras operated See Supplemental Information for footnotes and definitions. 36

RESILIENT LNG PORTFOLIO Diverse pipeline of low cost-of-supply developments Development status • Mozambique: Coral FLNG, 3.4 Mta, start-up in 2022 Growing sales GHG intensity • Mozambique: Rovuma, 15 Mta st 26 Mta in 2025 1 quartile − Capital efficient from scale of 85 TCF Area 4 resource 1 operated performance − Pursuing synergies with Area 1 ~10% net sales increase versus 2020 • Golden Pass: 16 Mta, start-up in 2024 − Capital-efficient import terminal conversion Cash flow Highly resilient − Atlantic Basin supply point providing logistics optimization and customer supply diversity ~$5 billion >10% • PNG: Papua, 5 Mta 3 of operating cash flow in return at <$5/Mbtu 2 − Capital efficient leveraging current facilities 2025; ~$4 billion in 2020 − Continuing development optimization 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 37RESILIENT LNG PORTFOLIO Diverse pipeline of low cost-of-supply developments Development status • Mozambique: Coral FLNG, 3.4 Mta, start-up in 2022 Growing sales GHG intensity • Mozambique: Rovuma, 15 Mta st 26 Mta in 2025 1 quartile − Capital efficient from scale of 85 TCF Area 4 resource 1 operated performance − Pursuing synergies with Area 1 ~10% net sales increase versus 2020 • Golden Pass: 16 Mta, start-up in 2024 − Capital-efficient import terminal conversion Cash flow Highly resilient − Atlantic Basin supply point providing logistics optimization and customer supply diversity ~$5 billion >10% • PNG: Papua, 5 Mta 3 of operating cash flow in return at <$5/Mbtu 2 − Capital efficient leveraging current facilities 2025; ~$4 billion in 2020 − Continuing development optimization 2 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 37

UPSTREAM VOLUMES OUTLOOK Focused on increasing value; flexible to adjust to market PRODUCTION • Strategy driven by improving portfolio competitiveness Koebd net 4,000 − Focusing on low cost-of-supply liquids and LNG investments 2 Volumes associated with − ~50% reduction of lower-value North American dry gas post 2020 start-ups 1 Returns >10% at <$40/bbl • 2021 outlook ~3.7 Moebd, in line with 2020 • 2025 outlook flat versus 2021 2,000 − Reduced 2021-2025 Capex by ~$40 billion − Permian Capex reduced by >40% • ~40% of 2025 volumes from low cost-of-supply investments starting up after 2020 − Guyana and Brazil investments unchanged 0 2021 2025 See Supplemental Information for footnotes and definitions. 38UPSTREAM VOLUMES OUTLOOK Focused on increasing value; flexible to adjust to market PRODUCTION • Strategy driven by improving portfolio competitiveness Koebd net 4,000 − Focusing on low cost-of-supply liquids and LNG investments 2 Volumes associated with − ~50% reduction of lower-value North American dry gas post 2020 start-ups 1 Returns >10% at <$40/bbl • 2021 outlook ~3.7 Moebd, in line with 2020 • 2025 outlook flat versus 2021 2,000 − Reduced 2021-2025 Capex by ~$40 billion − Permian Capex reduced by >40% • ~40% of 2025 volumes from low cost-of-supply investments starting up after 2020 − Guyana and Brazil investments unchanged 0 2021 2025 See Supplemental Information for footnotes and definitions. 38

UPSTREAM VOLUMES OUTLOOK Focused on increasing value; flexible to adjust to market PRODUCTION AND OPERATING CASH FLOW • Strategy driven by improving portfolio competitiveness Indexed to 2021, % − Focusing on low cost-of-supply liquids and LNG investments 2 − ~50% reduction of lower-value North American dry gas 2025 2021 100 • 2021 outlook ~3.7 Moebd, in line with 2020 • 2025 outlook flat versus 2021 − Reduced 2021-2025 Capex by ~$40 billion 50 − Permian Capex reduced by >40% • ~40% of 2025 volumes from low cost-of-supply investments starting up after 2020 − Guyana and Brazil investments unchanged 0 Production Operating cash flow 3 • 2025 operating cash flow up ~20% versus 2021 3 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 39 See Supplemental Information for footnotes and definitions.UPSTREAM VOLUMES OUTLOOK Focused on increasing value; flexible to adjust to market PRODUCTION AND OPERATING CASH FLOW • Strategy driven by improving portfolio competitiveness Indexed to 2021, % − Focusing on low cost-of-supply liquids and LNG investments 2 − ~50% reduction of lower-value North American dry gas 2025 2021 100 • 2021 outlook ~3.7 Moebd, in line with 2020 • 2025 outlook flat versus 2021 − Reduced 2021-2025 Capex by ~$40 billion 50 − Permian Capex reduced by >40% • ~40% of 2025 volumes from low cost-of-supply investments starting up after 2020 − Guyana and Brazil investments unchanged 0 Production Operating cash flow 3 • 2025 operating cash flow up ~20% versus 2021 3 Potential assuming $50/bbl Brent price adjusted for inflation from 2021. 39 See Supplemental Information for footnotes and definitions.

DOWNSTREAM & CHEMICALDOWNSTREAM & CHEMICAL

DOWNSTREAM STRATEGY RECONNECT 1 #1 in synthetic lubricants and basestocks; industry-leading integration SYNTHETIC LUBRICANTS VOLUMES 1.5x INDUSTRY Strategy Indexed to 2010, % 300 • Grow earnings from highly profitable Lubricants ExxonMobil • Improve Fuels competitiveness and resiliency − Deliver industry-leading manufacturing costs − Shift yield to more distillates, lubricants, and chemicals Industry 2020 results and plans • Lubricants delivers >$1 billion annual earnings • Fuels portfolio net cash margin improves 30% primarily 2 driven by conversion projects at advantaged sites • Structural efficiencies of ~$1.5 billion by year-end 2023 50 • Key growth markets contribute >$500 million annual 2010 2015 2020 2025 earnings potential by 2025 Source: Industry - Kline and Company (2019); ExxonMobil - ExxonMobil analysis. 41 See supplemental information for footnotes and definitions.DOWNSTREAM STRATEGY RECONNECT 1 #1 in synthetic lubricants and basestocks; industry-leading integration SYNTHETIC LUBRICANTS VOLUMES 1.5x INDUSTRY Strategy Indexed to 2010, % 300 • Grow earnings from highly profitable Lubricants ExxonMobil • Improve Fuels competitiveness and resiliency − Deliver industry-leading manufacturing costs − Shift yield to more distillates, lubricants, and chemicals Industry 2020 results and plans • Lubricants delivers >$1 billion annual earnings • Fuels portfolio net cash margin improves 30% primarily 2 driven by conversion projects at advantaged sites • Structural efficiencies of ~$1.5 billion by year-end 2023 50 • Key growth markets contribute >$500 million annual 2010 2015 2020 2025 earnings potential by 2025 Source: Industry - Kline and Company (2019); ExxonMobil - ExxonMobil analysis. 41 See supplemental information for footnotes and definitions.

CHEMICAL STRATEGY RECONNECT Meet increasing global demand for high-value products through advantaged investments 1 PERFORMANCE PRODUCTS DELIVERED GROWTH AT >4x GDP Strategy Indexed to 2010, % 350 ExxonMobil • Grow environmentally sustainable, high-value performance performance products to meet increasing demand products − Capacity additions through advantaged projects leveraging technology and scale 2020 results and plans Industry commodity chemicals 2 • Industry-leading earnings of $2 billion • Performance products growth of 5% in 2020; major projects to deliver 60% growth by 2027 Global GDP • Structural efficiencies supporting $1 billion cost reduction by year-end 2021 • Integrated optimization and advantaged feed flexibility 50 delivered ~$500 million earnings 2010 2015 2020 2025 See Supplemental Information for footnotes and definitions. 42CHEMICAL STRATEGY RECONNECT Meet increasing global demand for high-value products through advantaged investments 1 PERFORMANCE PRODUCTS DELIVERED GROWTH AT >4x GDP Strategy Indexed to 2010, % 350 ExxonMobil • Grow environmentally sustainable, high-value performance performance products to meet increasing demand products − Capacity additions through advantaged projects leveraging technology and scale 2020 results and plans Industry commodity chemicals 2 • Industry-leading earnings of $2 billion • Performance products growth of 5% in 2020; major projects to deliver 60% growth by 2027 Global GDP • Structural efficiencies supporting $1 billion cost reduction by year-end 2021 • Integrated optimization and advantaged feed flexibility 50 delivered ~$500 million earnings 2010 2015 2020 2025 See Supplemental Information for footnotes and definitions. 42

LEADING CHEMICAL BUSINESS Diversified and resilient portfolio delivers strong earnings growth An industry leader across the cycle #1 or #2 market position in >80% of Performance product development chemical product portfolio supports rapid sales growth 4 400% Polyethylene ExxonMobil Performance market position: #1 Total market position: #1 Fluids / plasticizer Market position: #1 Vistamaxx™ Propylene-based plastomer Market position: #1 Industry 2 200% Adhesions Market position: #1 IOC Synthetics Performance Market position: #1 polypropylene Performance TPV and butyl rubber polyethylene Market position: #1 0% 0 Aromatics 2010 2015 2020 2025 2010-2019 2020 Market position: #2 average 1 2 3 MARKET POSITION ANNUAL EARNINGS, Billion USD EXXONMOBIL SALES VOLUME, Indexed to 2010 See Supplemental Information for footnotes and definitions. 43LEADING CHEMICAL BUSINESS Diversified and resilient portfolio delivers strong earnings growth An industry leader across the cycle #1 or #2 market position in >80% of Performance product development chemical product portfolio supports rapid sales growth 4 400% Polyethylene ExxonMobil Performance market position: #1 Total market position: #1 Fluids / plasticizer Market position: #1 Vistamaxx™ Propylene-based plastomer Market position: #1 Industry 2 200% Adhesions Market position: #1 IOC Synthetics Performance Market position: #1 polypropylene Performance TPV and butyl rubber polyethylene Market position: #1 0% 0 Aromatics 2010 2015 2020 2025 2010-2019 2020 Market position: #2 average 1 2 3 MARKET POSITION ANNUAL EARNINGS, Billion USD EXXONMOBIL SALES VOLUME, Indexed to 2010 See Supplemental Information for footnotes and definitions. 43

INNOVATIVE PRODUCTS PROVIDE CUSTOMER BENEFITS High-value products provide customer choices for lower emissions or improved efficiencies HIGH-VALUE PRODUCTS MEET EVOLVING CUSTOMER NEEDS Representative examples 1 PRODUCT / SECTOR POTENTIAL BENEFITS Plastic packaging 54% lower lifecycle GHG emissions impact versus alternatives Flexible film applications Exceed™ XP enables up to 30% down gauging versus conventional plastics Advanced recycling of plastic waste To produce certified circular polymers with equivalent performance of virgin plastics Polypropylene automotive application Fuel efficiency improves 6-8% for a 10% reduction in vehicle weight 2 Synergy Diesel Efficient™ Improves average fuel economy by 2% versus diesel fuel without detergent additive Synthetic motor oil Can improve fuel economy up to 2% versus conventional mineral engine oils Wind turbine gear oil Mobil SHC™ Gear 320 WT oil offers long oil drain interval with 10-year warranty 2 Synergy Diesel Efficient™ assumes a 250 gallon tank and an average of 7 miles per gallon. See Supplemental Information for footnotes and definitions. 44INNOVATIVE PRODUCTS PROVIDE CUSTOMER BENEFITS High-value products provide customer choices for lower emissions or improved efficiencies HIGH-VALUE PRODUCTS MEET EVOLVING CUSTOMER NEEDS Representative examples 1 PRODUCT / SECTOR POTENTIAL BENEFITS Plastic packaging 54% lower lifecycle GHG emissions impact versus alternatives Flexible film applications Exceed™ XP enables up to 30% down gauging versus conventional plastics Advanced recycling of plastic waste To produce certified circular polymers with equivalent performance of virgin plastics Polypropylene automotive application Fuel efficiency improves 6-8% for a 10% reduction in vehicle weight 2 Synergy Diesel Efficient™ Improves average fuel economy by 2% versus diesel fuel without detergent additive Synthetic motor oil Can improve fuel economy up to 2% versus conventional mineral engine oils Wind turbine gear oil Mobil SHC™ Gear 320 WT oil offers long oil drain interval with 10-year warranty 2 Synergy Diesel Efficient™ assumes a 250 gallon tank and an average of 7 miles per gallon. See Supplemental Information for footnotes and definitions. 44

PRODUCT MIX DELIVERS INCREASED VALUE Proprietary technology enables product mix upgrade 1 DOWNSTREAM AND CHEMICAL PRODUCT MIX UPGRADE PLANS 2027 volume change, indexed to 2017 -50% 0% 50% • Grow Chemical performance product Performance products commodity ++ volume consistent with demand Chemical Commodity • Highgrade refinery product mix +$70/bbl − Reduce fuel oil and gasoline yield Lubricants +$45/bbl • Proprietary technology enables: − Fuel oil to lubricant upgrade Diesel / Jet +$14/bbl − New innovative chemical products Feedstock Refining $/bbl Gasoline +$9/bbl Fuel oil -$11/bbl Product spreads versus average 2 refining feedstock cost $/bbl See Supplemental Information for footnotes and definitions. 45PRODUCT MIX DELIVERS INCREASED VALUE Proprietary technology enables product mix upgrade 1 DOWNSTREAM AND CHEMICAL PRODUCT MIX UPGRADE PLANS 2027 volume change, indexed to 2017 -50% 0% 50% • Grow Chemical performance product Performance products commodity ++ volume consistent with demand Chemical Commodity • Highgrade refinery product mix +$70/bbl − Reduce fuel oil and gasoline yield Lubricants +$45/bbl • Proprietary technology enables: − Fuel oil to lubricant upgrade Diesel / Jet +$14/bbl − New innovative chemical products Feedstock Refining $/bbl Gasoline +$9/bbl Fuel oil -$11/bbl Product spreads versus average 2 refining feedstock cost $/bbl See Supplemental Information for footnotes and definitions. 45

FUTURE INVESTMENTS DELIVER ROBUST RETURNS Advantaged investments focus on margin improvement and high-value product growth FUTURE MAJOR DOWNSTREAM & CHEMICAL GROWTH PROJECTS EARNINGS FROM FUTURE MAJOR GROWTH PROJECTS 1 2 DELIVER ~30% RETURN DELIVER >$2 BILLION AT 10-YEAR LOW MARGINS Billion USD 5 Refining product upgrades Connect advantaged Upstream with Permian crude venture world-class U.S. Gulf Coast assets Beaumont light crude Process advantaged Permian crude Fawley hydrofiner Capture attractive local diesel market Singapore resid upgrade Upgrade bottoms to lubes and distillates 30% 1 return Chemical high-value performance product growth Corpus Christi complex Leverage North America gas advantage China complex Enables access to key growth market Baton Rouge polypropylene Meet growing auto / durable demand Sustain performance polyethylene and Baytown expansion Vistamaxx™ growth 0 10-year 10-year low margins average margins See Supplemental Information for footnotes and definitions. 46FUTURE INVESTMENTS DELIVER ROBUST RETURNS Advantaged investments focus on margin improvement and high-value product growth FUTURE MAJOR DOWNSTREAM & CHEMICAL GROWTH PROJECTS EARNINGS FROM FUTURE MAJOR GROWTH PROJECTS 1 2 DELIVER ~30% RETURN DELIVER >$2 BILLION AT 10-YEAR LOW MARGINS Billion USD 5 Refining product upgrades Connect advantaged Upstream with Permian crude venture world-class U.S. Gulf Coast assets Beaumont light crude Process advantaged Permian crude Fawley hydrofiner Capture attractive local diesel market Singapore resid upgrade Upgrade bottoms to lubes and distillates 30% 1 return Chemical high-value performance product growth Corpus Christi complex Leverage North America gas advantage China complex Enables access to key growth market Baton Rouge polypropylene Meet growing auto / durable demand Sustain performance polyethylene and Baytown expansion Vistamaxx™ growth 0 10-year 10-year low margins average margins See Supplemental Information for footnotes and definitions. 46

DELIVERING ON STRATEGIC PRIORITIES Earnings growth through integration, cost reductions, and project portfolio Leading 2020 Structural • World-class Downstream and Chemical businesses Chemical earnings efficiencies with leading market positions • Competitive cost structure supported by industry- ~$2 billion $2.5 billion leading integration platform and nearly double 10-year combined Downstream and 1 industry-average earnings Chemical by year-end 2023 • Earnings growth driven by innovative, high-value products to meet increasing customer demand 2020 Lubricants Major growth earnings projects • Attractive major projects resilient across market cycles 3 >$1 billion >30% return industry-leading synthetic resilient across the cycle 2 lubricants positon with significant upside See Supplemental Information for footnotes and definitions. 47DELIVERING ON STRATEGIC PRIORITIES Earnings growth through integration, cost reductions, and project portfolio Leading 2020 Structural • World-class Downstream and Chemical businesses Chemical earnings efficiencies with leading market positions • Competitive cost structure supported by industry- ~$2 billion $2.5 billion leading integration platform and nearly double 10-year combined Downstream and 1 industry-average earnings Chemical by year-end 2023 • Earnings growth driven by innovative, high-value products to meet increasing customer demand 2020 Lubricants Major growth earnings projects • Attractive major projects resilient across market cycles 3 >$1 billion >30% return industry-leading synthetic resilient across the cycle 2 lubricants positon with significant upside See Supplemental Information for footnotes and definitions. 47

FINANCIAL PLAN FINANCIAL PLAN

REAFFIRMING CAPITAL ALLOCATION PHILOSOPHY Maintaining flexibility to respond as markets evolve • Long-term capital allocation priorities remain − Invest in advantaged projects to drive cash flow − Maintain balance sheet strength − Provide reliable dividend • Flexibility to efficiently respond to market developments − Driving further structural cost reductions − Advancing flexible portfolio of high-return, cost-advantaged investments • Ability to preserve strong balance sheet and maintain dividend 49REAFFIRMING CAPITAL ALLOCATION PHILOSOPHY Maintaining flexibility to respond as markets evolve • Long-term capital allocation priorities remain − Invest in advantaged projects to drive cash flow − Maintain balance sheet strength − Provide reliable dividend • Flexibility to efficiently respond to market developments − Driving further structural cost reductions − Advancing flexible portfolio of high-return, cost-advantaged investments • Ability to preserve strong balance sheet and maintain dividend 49

DRIVING STRUCTURAL COST EFFICIENCIES Achieved ~$3 billion of structural reductions in 2020; $6 billion by 2023 CASH OPEX EXCLUDING ENERGY AND PRODUCTION TAXES Billion USD • Delivered on cost reduction objectives, outperforming revised plan 44 3 • Leveraged prior reorganizations to deliver structural reductions of ~$3 billion in 2020 41 39 39 38 3+ • Additional $3 billion of structural efficiencies through 2023 for a total of $6 billion versus 2019 34 34 2019 Structural Market / 2020 Structural Market / 2023 activity activity See Supplemental Information for definitions. 50DRIVING STRUCTURAL COST EFFICIENCIES Achieved ~$3 billion of structural reductions in 2020; $6 billion by 2023 CASH OPEX EXCLUDING ENERGY AND PRODUCTION TAXES Billion USD • Delivered on cost reduction objectives, outperforming revised plan 44 3 • Leveraged prior reorganizations to deliver structural reductions of ~$3 billion in 2020 41 39 39 38 3+ • Additional $3 billion of structural efficiencies through 2023 for a total of $6 billion versus 2019 34 34 2019 Structural Market / 2020 Structural Market / 2023 activity activity See Supplemental Information for definitions. 50

MAINTAINING INVESTMENT OPTIONALITY Demonstrated ability to adjust capital spending and preserve value CAPEX 2021–2025 Billion USD • 2021-2025 capital program optimized to current $20 - $25 market outlook Guidance: $16 - $19 20 Flexible • Investment strategy prioritizes highest-return opportunities • Robust economics across price scenarios 10 Less • Flexibility to adjust investments in response to flexible market conditions in any year 0 2021 2022 - 2025 average See Supplemental Information for definitions. 51MAINTAINING INVESTMENT OPTIONALITY Demonstrated ability to adjust capital spending and preserve value CAPEX 2021–2025 Billion USD • 2021-2025 capital program optimized to current $20 - $25 market outlook Guidance: $16 - $19 20 Flexible • Investment strategy prioritizes highest-return opportunities • Robust economics across price scenarios 10 Less • Flexibility to adjust investments in response to flexible market conditions in any year 0 2021 2022 - 2025 average See Supplemental Information for definitions. 51

CAPITAL ALLOCATION PRIORITIES Leverage portfolio flexibility to sustain the dividend 1,2,3 2021 ESTIMATED SOURCES AND USES OF CASH Billion USD • Prioritizes Guyana, Brazil, Permian, and Chemical By Brent price, with performance products 10yr low Downstream Guidance: & Chemical margins $16 - $19 $55/bbl $50/bbl• Capital flexibility to maintain dividend at ~$45/bbl and Flexible 10-year low Downstream and Chemical margins $45/bbl Less flexible • Debt reduced at Brent > ~$50/bbl and 10-year low Downstream and Chemical margins • Capital flexibility to maintain dividend at ~$35/bbl and 4 average Downstream and Chemical margins in 2025 Available cash Dividend Capex from operations See Supplemental Information for footnotes and definitions. 52CAPITAL ALLOCATION PRIORITIES Leverage portfolio flexibility to sustain the dividend 1,2,3 2021 ESTIMATED SOURCES AND USES OF CASH Billion USD • Prioritizes Guyana, Brazil, Permian, and Chemical By Brent price, with performance products 10yr low Downstream Guidance: & Chemical margins $16 - $19 $55/bbl $50/bbl• Capital flexibility to maintain dividend at ~$45/bbl and Flexible 10-year low Downstream and Chemical margins $45/bbl Less flexible • Debt reduced at Brent > ~$50/bbl and 10-year low Downstream and Chemical margins • Capital flexibility to maintain dividend at ~$35/bbl and 4 average Downstream and Chemical margins in 2025 Available cash Dividend Capex from operations See Supplemental Information for footnotes and definitions. 52

CASH FLOW GROWTH Investments drive cash flow generation through the cycle 1,2 ESTIMATED AVAILABLE CASH FROM OPERATIONS Billion USD • Cash flow growth driven by investment program Return to 10yr avg. and reduced cash operating expenses Downstream and 40 Chemical margins • 2021—2025 project start-ups drive ~40% of 2025 cash flow Cash flow from start- 30 ups 2021—2025 • High-return investments more than offset Base $50/bbl real Brent divestments and base decline 20 and 10yr low Base Downstream and $50/bbl real Brent Chemical margins and 10yr low Downstream and Chemical margins 10 0 2021 2025 Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 53CASH FLOW GROWTH Investments drive cash flow generation through the cycle 1,2 ESTIMATED AVAILABLE CASH FROM OPERATIONS Billion USD • Cash flow growth driven by investment program Return to 10yr avg. and reduced cash operating expenses Downstream and 40 Chemical margins • 2021—2025 project start-ups drive ~40% of 2025 cash flow Cash flow from start- 30 ups 2021—2025 • High-return investments more than offset Base $50/bbl real Brent divestments and base decline 20 and 10yr low Base Downstream and $50/bbl real Brent Chemical margins and 10yr low Downstream and Chemical margins 10 0 2021 2025 Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 53

CAPITAL ALLOCATION PRIORITIES Cumulative excess available cash generation of ~$30 billion through 2025 1,2,3 CUMULATIVE ESTIMATED SOURCES AND USES OF CASH (2021-2025) Billion USD • Investing in advantaged, low cost-of-supply Real Brent price projects drives strong, long-term free cash flow $55/bbl 200 $50/bbl • Portfolio covers dividend and capital program while Excess cash generating excess available cash at $50/bbl for debt reduction and increased distributions • Cumulative available cash increases by more than Less flexible 100 $15 billion at 10-year high Downstream and Chemical margins • Cumulative available cash increases by ~$3 billion for every $1/bbl increase in Brent price 0 Available cash Dividend Capex Excess available from operations cash Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 54CAPITAL ALLOCATION PRIORITIES Cumulative excess available cash generation of ~$30 billion through 2025 1,2,3 CUMULATIVE ESTIMATED SOURCES AND USES OF CASH (2021-2025) Billion USD • Investing in advantaged, low cost-of-supply Real Brent price projects drives strong, long-term free cash flow $55/bbl 200 $50/bbl • Portfolio covers dividend and capital program while Excess cash generating excess available cash at $50/bbl for debt reduction and increased distributions • Cumulative available cash increases by more than Less flexible 100 $15 billion at 10-year high Downstream and Chemical margins • Cumulative available cash increases by ~$3 billion for every $1/bbl increase in Brent price 0 Available cash Dividend Capex Excess available from operations cash Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 54

GROWING EARNINGS Cost reductions and advantaged investments enhance earnings power across a range of prices / margins 1,2 EARNINGS GROWTH $55/bbl real Brent Billion USD and 10yr high • Delivering structural cash Opex reductions across Downstream and Chemical margins the corporation • Investing in high-quality Upstream portfolio to 20 Portfolio improve profitability and offset decline improvements Structural Uplift to 10yr cash Opex avg. Downstream reductions • Highgrading Downstream product yields with and Chemical strategic investments margins $50/bbl real Brent 10 and 10yr low Downstream/ Chemical margins • Growing high-value Chemical performance products through advantaged projects 0 2021 2025 Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 55GROWING EARNINGS Cost reductions and advantaged investments enhance earnings power across a range of prices / margins 1,2 EARNINGS GROWTH $55/bbl real Brent Billion USD and 10yr high • Delivering structural cash Opex reductions across Downstream and Chemical margins the corporation • Investing in high-quality Upstream portfolio to 20 Portfolio improve profitability and offset decline improvements Structural Uplift to 10yr cash Opex avg. Downstream reductions • Highgrading Downstream product yields with and Chemical strategic investments margins $50/bbl real Brent 10 and 10yr low Downstream/ Chemical margins • Growing high-value Chemical performance products through advantaged projects 0 2021 2025 Brent price adjusted for inflation from 2021. See Supplemental Information for footnotes and definitions. 55

CLOSING CLOSING

GROWING LONG-TERM SHAREHOLDER VALUE Progressing actions to highgrade portfolio and improve earnings and cash flow • Committed to delivering sustainable shareholder value • Competitively advantaged assets and investments drive strong cash flow to sustain dividend, reduce debt, and invest in the future • Significant cash Opex savings and flexible Capex resilient to price cycles • Focused on industry-leading safety, reliability, and environmental performance; executing plans to deliver aggressive 2025 emission reductions • Strategy leverages experience and competitive advantages to deliver value while transitioning to a lower-carbon future, consistent with the goals of the Paris Agreement 57GROWING LONG-TERM SHAREHOLDER VALUE Progressing actions to highgrade portfolio and improve earnings and cash flow • Committed to delivering sustainable shareholder value • Competitively advantaged assets and investments drive strong cash flow to sustain dividend, reduce debt, and invest in the future • Significant cash Opex savings and flexible Capex resilient to price cycles • Focused on industry-leading safety, reliability, and environmental performance; executing plans to deliver aggressive 2025 emission reductions • Strategy leverages experience and competitive advantages to deliver value while transitioning to a lower-carbon future, consistent with the goals of the Paris Agreement 57

SUPPLEMENTSUPPLEMENT

SOCIETY’S GLOBAL EMISSIONS FROM ALL SOURCES Emissions need to reach net-zero by 2070 per the IPCC Lower 2°C Scenarios GLOBAL EMISSIONS BY SOURCE AND SECTOR 49 GT/yr CO e 2 • Human activities contribute to greenhouse gas All other (GHG) emissions Agriculture Landfills Forestry − Energy used to light and warm homes Land use Agriculture Forestry − Materials for infrastructure and consumer goods Buildings Land use − Food for health and nourishment Transport − Changes to land and forestry Coal Power generation • Oil and natural gas use contributes ~1/3 of global GHG emissions Oil & Natural gas Industry By sector By source Source: (left) IPCC Fifth Assessment Report Climate Change 2014: Mitigation of Climate Change, page 9; (right) ExxonMobil analysis of IPCC Fifth Assessment reports and Fourth Assessment reports. See Supplemental Information for definitions. 59SOCIETY’S GLOBAL EMISSIONS FROM ALL SOURCES Emissions need to reach net-zero by 2070 per the IPCC Lower 2°C Scenarios GLOBAL EMISSIONS BY SOURCE AND SECTOR 49 GT/yr CO e 2 • Human activities contribute to greenhouse gas All other (GHG) emissions Agriculture Landfills Forestry − Energy used to light and warm homes Land use Agriculture Forestry − Materials for infrastructure and consumer goods Buildings Land use − Food for health and nourishment Transport − Changes to land and forestry Coal Power generation • Oil and natural gas use contributes ~1/3 of global GHG emissions Oil & Natural gas Industry By sector By source Source: (left) IPCC Fifth Assessment Report Climate Change 2014: Mitigation of Climate Change, page 9; (right) ExxonMobil analysis of IPCC Fifth Assessment reports and Fourth Assessment reports. See Supplemental Information for definitions. 59

HIGH-RETURN INVESTMENTS PERMIAN Midland Basin 1 2 DAILY DRILLING LATERAL FEET FRAC STAGES PER DAY DRILLING AND COMPLETION COSTS >60% 60% Improvement 170% 170% 100% Improvement >30% Improvement 0% 70% 70% 2018 2019 2020 2018 2019 2020 2018 2019 2020 Data indexed to 2018. See Supplemental Information for footnotes and definitions. 60HIGH-RETURN INVESTMENTS PERMIAN Midland Basin 1 2 DAILY DRILLING LATERAL FEET FRAC STAGES PER DAY DRILLING AND COMPLETION COSTS >60% 60% Improvement 170% 170% 100% Improvement >30% Improvement 0% 70% 70% 2018 2019 2020 2018 2019 2020 2018 2019 2020 Data indexed to 2018. See Supplemental Information for footnotes and definitions. 60

HIGH-RETURN INVESTMENTS PERMIAN Midland Basin Continued year-on-year improvement; positive early results from cube development 1 MIDLAND AVERAGE WELL OIL PRODUCTION RATES (365 DAYS) MIDLAND AVERAGE WELL CUMULATIVE OIL PRODUCTION Bbl/d Kbbl 700 180 2020 2019 2018 27 well cube 0 0 Months 0 6 12 ExxonMobil Source: Peer range - IHS Markit; ExxonMobil - ExxonMobil analysis Source: ExxonMobil analysis See Supplemental Information for footnotes and definitions. 61HIGH-RETURN INVESTMENTS PERMIAN Midland Basin Continued year-on-year improvement; positive early results from cube development 1 MIDLAND AVERAGE WELL OIL PRODUCTION RATES (365 DAYS) MIDLAND AVERAGE WELL CUMULATIVE OIL PRODUCTION Bbl/d Kbbl 700 180 2020 2019 2018 27 well cube 0 0 Months 0 6 12 ExxonMobil Source: Peer range - IHS Markit; ExxonMobil - ExxonMobil analysis Source: ExxonMobil analysis See Supplemental Information for footnotes and definitions. 61

CORPUS CHRISTI CHEMICAL COMPLEX Achieving industry-leading cycle times at industry-low unit development costs CORPUS CHRISTI FURNACE MODULES DELIVERED IN 2020 • World’s first fully modularized chemical complex − 1.8 Mta steam cracker; largest under construction − World-scale polyethylene and ethylene glycol units • Project execution capturing market efficiencies − Delivering at <75% industry average cost − Ahead of schedule with 4Q21 start up activities 1 SCHEDULE PERFORMANCE Average project duration (U.S.) ExxonMobil • At full capacity delivers >$500 million per year in 2 Industry earnings on 10-year average chemical margins − Leverages integrated Permian feedstock advantage 1 COST PERFORMANCE Average complex $k/T (U.S.) ExxonMobil Industry 62 See Supplemental Information for footnotes.CORPUS CHRISTI CHEMICAL COMPLEX Achieving industry-leading cycle times at industry-low unit development costs CORPUS CHRISTI FURNACE MODULES DELIVERED IN 2020 • World’s first fully modularized chemical complex − 1.8 Mta steam cracker; largest under construction − World-scale polyethylene and ethylene glycol units • Project execution capturing market efficiencies − Delivering at <75% industry average cost − Ahead of schedule with 4Q21 start up activities 1 SCHEDULE PERFORMANCE Average project duration (U.S.) ExxonMobil • At full capacity delivers >$500 million per year in 2 Industry earnings on 10-year average chemical margins − Leverages integrated Permian feedstock advantage 1 COST PERFORMANCE Average complex $k/T (U.S.) ExxonMobil Industry 62 See Supplemental Information for footnotes.

CHEMICAL SUSTAINABILITY Developing technology to help address plastic waste and improve the efficient use of resources Founding member. Alliance 1 Received ISCC+ certification for Performance Polymers focused on developing safe, circular polymers resulting from Developing products that help protect scalable, and economically advanced recycling operations food, improve recyclability, and lower viable solutions to help end based on mass balance approach lifecycle GHG impacts vs. alternatives plastic waste in the environment Manufacturing Plastic Converters Brands Consumers Waste Waste-to-energy Raw materials Landfill Litter Vistamaxx™ Enables increased use of recycled Conventional material in end-use products recycling Transforming difficult-to-recycle waste into products Advanced recycling Baytown integrated site trial Completed initial phase of a plant trial to Formed joint venture with Agilyx test proprietary advanced recycling process to aggregate and pre-process plastic for producing certified circular polymers waste to enable increased recycling See Supplemental Information for footnotes and definitions. 63CHEMICAL SUSTAINABILITY Developing technology to help address plastic waste and improve the efficient use of resources Founding member. Alliance 1 Received ISCC+ certification for Performance Polymers focused on developing safe, circular polymers resulting from Developing products that help protect scalable, and economically advanced recycling operations food, improve recyclability, and lower viable solutions to help end based on mass balance approach lifecycle GHG impacts vs. alternatives plastic waste in the environment Manufacturing Plastic Converters Brands Consumers Waste Waste-to-energy Raw materials Landfill Litter Vistamaxx™ Enables increased use of recycled Conventional material in end-use products recycling Transforming difficult-to-recycle waste into products Advanced recycling Baytown integrated site trial Completed initial phase of a plant trial to Formed joint venture with Agilyx test proprietary advanced recycling process to aggregate and pre-process plastic for producing certified circular polymers waste to enable increased recycling See Supplemental Information for footnotes and definitions. 63

SUPPLEMENTAL INFORMATION IMPORTANT INFORMATION AND ASSUMPTIONS REGARDING CERTAIN FORWARD-LOOKING STATEMENTS. Forward-looking statements contained in this presentation regarding the potential for future earnings, cash flow, margins, ROCE, returns, rate of return, addressable markets, available cash from operations, operating cash flow, cash operating expenses, net cash margin, free cash, free cash flow, and resource potential are not forecasts of actual future results. These figures are provided to help quantify the potential future results and goals of currently-contemplated management plans and objectives including new project investments, plans to replace natural decline in Upstream production with low-cost volumes, plans to increase sales in our Downstream and Chemical segments and to shift our Downstream product mix toward higher-value products, continued highgrading of ExxonMobil’s portfolio through our ongoing asset management program, both announced and continuous initiatives to improve efficiencies and reduce costs, capital expenditures and cash management, and other efforts within management’s control to impact future results as discussed in this presentation. These figures are intended to quantify for illustrative purposes management’s view of the potentials for these efforts over the time periods shown, calculated on a basis consistent with our internal modelling assumptions for factors such as working capital, as well as factors management does not control, such as interest, differentials, and exchange rates. For all price point comparisons, unless otherwise indicated, we assume $50/bbl Brent crude prices. Unless otherwise specified, crude prices are Brent prices. Except where noted, natural gas prices used are consistent with management’s internal price assumptions for the relevant natural gas markets relative to the crude price for a given case. All crude and natural gas prices for future years are adjusted for inflation from 2021. Downstream and Chemical margins reflect annual historical averages for the 10-year period from 2010—2019 unless otherwise stated. These prices are not intended to reflect management’s forecasts for future prices or the prices we use for internal planning purposes. We have assumed that other factors such as laws and regulations, including tax and environmental laws, and fiscal regimes remain consistent with current conditions for the relevant periods. This presentation does not attempt to model potential COVID-19 outbreaks or recoveries beyond historical pricing. Unless otherwise indicated, asset sales and proceeds are consistent with our internal planning. For future periods, we have assumed Corporate & Financing expenses between $2.1 and $2.7 billion annually. To illustrate future financial capacity, we have used scenarios of Corporate & Financing expenses that reflect the estimated potential debt levels under those scenarios. Outlook for Corporate & Financing expenses for the first quarter 2021 is expected to be approximately $700 million. ExxonMobil-operated emissions, reductions and avoidance performance data are based on a combination of measured and estimated data using best available information. Calculations are based on industry standards and best practices, including guidance from the American Petroleum Institute (API) and IPIECA. The uncertainty associated with the emissions, reductions and avoidance performance data depends on variation in the processes and operations, the availability of sufficient data, the quality of those data and methodology used for measurement and estimation. Changes to the performance data may be reported as updated data and/or emission methodologies become available. ExxonMobil works with industry, including API and IPIECA, to improve emission factors and methodologies. Emissions, reductions and avoidance estimates from non- ExxonMobil operated facilities are included in the equity data and similarly may be updated as changes to the performance data are reported. The data includes XTO Energy performance beginning in 2011. See the Cautionary Statement at the front of this presentation for additional information regarding forward-looking statements. 64SUPPLEMENTAL INFORMATION IMPORTANT INFORMATION AND ASSUMPTIONS REGARDING CERTAIN FORWARD-LOOKING STATEMENTS. Forward-looking statements contained in this presentation regarding the potential for future earnings, cash flow, margins, ROCE, returns, rate of return, addressable markets, available cash from operations, operating cash flow, cash operating expenses, net cash margin, free cash, free cash flow, and resource potential are not forecasts of actual future results. These figures are provided to help quantify the potential future results and goals of currently-contemplated management plans and objectives including new project investments, plans to replace natural decline in Upstream production with low-cost volumes, plans to increase sales in our Downstream and Chemical segments and to shift our Downstream product mix toward higher-value products, continued highgrading of ExxonMobil’s portfolio through our ongoing asset management program, both announced and continuous initiatives to improve efficiencies and reduce costs, capital expenditures and cash management, and other efforts within management’s control to impact future results as discussed in this presentation. These figures are intended to quantify for illustrative purposes management’s view of the potentials for these efforts over the time periods shown, calculated on a basis consistent with our internal modelling assumptions for factors such as working capital, as well as factors management does not control, such as interest, differentials, and exchange rates. For all price point comparisons, unless otherwise indicated, we assume $50/bbl Brent crude prices. Unless otherwise specified, crude prices are Brent prices. Except where noted, natural gas prices used are consistent with management’s internal price assumptions for the relevant natural gas markets relative to the crude price for a given case. All crude and natural gas prices for future years are adjusted for inflation from 2021. Downstream and Chemical margins reflect annual historical averages for the 10-year period from 2010—2019 unless otherwise stated. These prices are not intended to reflect management’s forecasts for future prices or the prices we use for internal planning purposes. We have assumed that other factors such as laws and regulations, including tax and environmental laws, and fiscal regimes remain consistent with current conditions for the relevant periods. This presentation does not attempt to model potential COVID-19 outbreaks or recoveries beyond historical pricing. Unless otherwise indicated, asset sales and proceeds are consistent with our internal planning. For future periods, we have assumed Corporate & Financing expenses between $2.1 and $2.7 billion annually. To illustrate future financial capacity, we have used scenarios of Corporate & Financing expenses that reflect the estimated potential debt levels under those scenarios. Outlook for Corporate & Financing expenses for the first quarter 2021 is expected to be approximately $700 million. ExxonMobil-operated emissions, reductions and avoidance performance data are based on a combination of measured and estimated data using best available information. Calculations are based on industry standards and best practices, including guidance from the American Petroleum Institute (API) and IPIECA. The uncertainty associated with the emissions, reductions and avoidance performance data depends on variation in the processes and operations, the availability of sufficient data, the quality of those data and methodology used for measurement and estimation. Changes to the performance data may be reported as updated data and/or emission methodologies become available. ExxonMobil works with industry, including API and IPIECA, to improve emission factors and methodologies. Emissions, reductions and avoidance estimates from non- ExxonMobil operated facilities are included in the equity data and similarly may be updated as changes to the performance data are reported. The data includes XTO Energy performance beginning in 2011. See the Cautionary Statement at the front of this presentation for additional information regarding forward-looking statements. 64

SUPPLEMENTAL INFORMATION NON-GAAP AND OTHER MEASURES. With respect to historical periods, reconciliation information is provided in the Frequently Used Terms available on the Investor page of our website at www.exxonmobil.com under the heading News & Resources for certain terms used in this presentation including available cash from operations, operating cash flow, cash operating expense, net cash margin, free cash and free cash flow. For future periods, we are unable to provide a reconciliation of forward-looking non-GAAP or other measures to the most comparable GAAP financial measures because the information needed to reconcile these measures is dependent on future events, many of which are outside management’s control as described above. Additionally, estimating such GAAP measures and providing a meaningful reconciliation consistent with our accounting policies for future periods is extremely difficult and requires a level of precision that is unavailable for these future periods and cannot be accomplished without unreasonable effort. Forward-looking non-GAAP measures are estimated in a manner consistent with the relevant definitions and assumptions noted above. DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS. Available cash from operations. Available cash from operations provides an indication of cash flow available to fund shareholder distributions, capex, and debt reduction and is calculated as the sum of (1) net cash provided by operating activities and (2) net cash used in investing activities, both from the Consolidated statement of cash flows, and (3) capital and exploration expenditures. It includes estimated proceeds from asset sales net of forgone cash flows from divested assets. This measure is useful when evaluating total sources of cash available, including from equity companies, for uses such as capital and exploration expenditures and financing activities, including debt reduction and shareholder distributions. Cash operating expenses (cash Opex, structural efficiencies, or structural reductions). Cash operating expenses are a subset of total operating costs that are stewarded internally to support management’s oversight of spending over time. This measure is useful for investors to understand the Corporation’s efforts to optimize cash through disciplined expense management. For information concerning the calculation and reconciliation of cash operating expenses see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Flexible Capex. Flexible Capex includes those investments with minimal costs or value loss to defer expenditures, such as investments in short cycle businesses like unconventionals, projects that have not commenced or are early in construction and with limited penalty to pause. Less-flexible Capex. Less flexible Capex includes projects conducted for safety, environmental and regulatory reasons, projects already in execution with penalties or loss of value associated with pausing, and investments made in order to retain rights or options for potential future investment. Free cash. Free cash is operating cash flow less capital investment. This measure is useful when approximating contributions to cash available for financing activities, applied to the Upstream business. Free cash flow. Free cash flow is cash flow from operations and asset sales less additions to property, plant and equipment, and additional investments and advances, plus other investing activities, including collection of advances. This measure is useful when evaluating cash available for financing activities, including shareholder distributions, after investment in the business. For information concerning the calculation and reconciliation of free cash flow see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. 65SUPPLEMENTAL INFORMATION NON-GAAP AND OTHER MEASURES. With respect to historical periods, reconciliation information is provided in the Frequently Used Terms available on the Investor page of our website at www.exxonmobil.com under the heading News & Resources for certain terms used in this presentation including available cash from operations, operating cash flow, cash operating expense, net cash margin, free cash and free cash flow. For future periods, we are unable to provide a reconciliation of forward-looking non-GAAP or other measures to the most comparable GAAP financial measures because the information needed to reconcile these measures is dependent on future events, many of which are outside management’s control as described above. Additionally, estimating such GAAP measures and providing a meaningful reconciliation consistent with our accounting policies for future periods is extremely difficult and requires a level of precision that is unavailable for these future periods and cannot be accomplished without unreasonable effort. Forward-looking non-GAAP measures are estimated in a manner consistent with the relevant definitions and assumptions noted above. DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS. Available cash from operations. Available cash from operations provides an indication of cash flow available to fund shareholder distributions, capex, and debt reduction and is calculated as the sum of (1) net cash provided by operating activities and (2) net cash used in investing activities, both from the Consolidated statement of cash flows, and (3) capital and exploration expenditures. It includes estimated proceeds from asset sales net of forgone cash flows from divested assets. This measure is useful when evaluating total sources of cash available, including from equity companies, for uses such as capital and exploration expenditures and financing activities, including debt reduction and shareholder distributions. Cash operating expenses (cash Opex, structural efficiencies, or structural reductions). Cash operating expenses are a subset of total operating costs that are stewarded internally to support management’s oversight of spending over time. This measure is useful for investors to understand the Corporation’s efforts to optimize cash through disciplined expense management. For information concerning the calculation and reconciliation of cash operating expenses see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Flexible Capex. Flexible Capex includes those investments with minimal costs or value loss to defer expenditures, such as investments in short cycle businesses like unconventionals, projects that have not commenced or are early in construction and with limited penalty to pause. Less-flexible Capex. Less flexible Capex includes projects conducted for safety, environmental and regulatory reasons, projects already in execution with penalties or loss of value associated with pausing, and investments made in order to retain rights or options for potential future investment. Free cash. Free cash is operating cash flow less capital investment. This measure is useful when approximating contributions to cash available for financing activities, applied to the Upstream business. Free cash flow. Free cash flow is cash flow from operations and asset sales less additions to property, plant and equipment, and additional investments and advances, plus other investing activities, including collection of advances. This measure is useful when evaluating cash available for financing activities, including shareholder distributions, after investment in the business. For information concerning the calculation and reconciliation of free cash flow see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. 65

SUPPLEMENTAL INFORMATION DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS, CONTINUED Lower 2°C scenarios. The Intergovernmental Panel on Climate Change (IPCC) published a Special Report on “Global Warming of 1.5°C” and identified 74 scenarios as “Lower 2ºC,” which are pathways limiting peak warming to below 2ºC during the entire 21st century with greater than 66 percent likelihood. Net cash margin ($/bbl input). Net cash margin, following Solomon Associate’s definition, is defined as gross margin at a standard price set for feeds and products, less normalized operating costs on a unit basis, expressed as $/bbl of total input. Operating cash flow. Operating Cash Flow is earnings plus depreciation and depletion, including non-controlling interests and abandonment spend, plus asset sales proceeds. Where applicable, pro-rata equity company earnings are net of depreciation and depletion. This measure is useful when approximating contributions to cash available for investment and financing activities excluding working capital impacts, applied to the Upstream business. Operating costs (Opex). Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy, staffing, and maintenance costs. They exclude the cost of raw materials, taxes, and interest expense and are on a before-tax basis. While ExxonMobil’s management is responsible for all revenue and expense elements of net income, operating costs, as defined above, represent the expenses most directly under management’s control, and therefore are useful for investors and ExxonMobil management in evaluating management’s performance. For information concerning the calculation and reconciliation of operating costs see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Performance product. Refers to Chemical products that provide differentiated performance for multiple applications through enhanced properties versus commodity alternatives and bring significant additional value to customers and end-users. Project. The term “project” as used in this presentation can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. Resources, resource base, and recoverable resources. Along with similar terms, these refer to the total remaining estimated quantities of oil and natural gas that are expected to be ultimately recoverable. ExxonMobil refers to new discoveries and acquisitions of discovered resources as resource additions. The resource base includes quantities of oil and natural gas classified as proved reserves, as well as, quantities that are not yet classified as proved reserves, but that are expected to be ultimately recoverable. The term “resource base” or similar terms is not intended to correspond to SEC definitions such as “probable” or “possible” reserves. The term “in-place” refers to those quantities of oil and natural gas estimated to be contained in known accumulations and includes recoverable and unrecoverable amounts. 66SUPPLEMENTAL INFORMATION DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS, CONTINUED Lower 2°C scenarios. The Intergovernmental Panel on Climate Change (IPCC) published a Special Report on “Global Warming of 1.5°C” and identified 74 scenarios as “Lower 2ºC,” which are pathways limiting peak warming to below 2ºC during the entire 21st century with greater than 66 percent likelihood. Net cash margin ($/bbl input). Net cash margin, following Solomon Associate’s definition, is defined as gross margin at a standard price set for feeds and products, less normalized operating costs on a unit basis, expressed as $/bbl of total input. Operating cash flow. Operating Cash Flow is earnings plus depreciation and depletion, including non-controlling interests and abandonment spend, plus asset sales proceeds. Where applicable, pro-rata equity company earnings are net of depreciation and depletion. This measure is useful when approximating contributions to cash available for investment and financing activities excluding working capital impacts, applied to the Upstream business. Operating costs (Opex). Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy, staffing, and maintenance costs. They exclude the cost of raw materials, taxes, and interest expense and are on a before-tax basis. While ExxonMobil’s management is responsible for all revenue and expense elements of net income, operating costs, as defined above, represent the expenses most directly under management’s control, and therefore are useful for investors and ExxonMobil management in evaluating management’s performance. For information concerning the calculation and reconciliation of operating costs see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Performance product. Refers to Chemical products that provide differentiated performance for multiple applications through enhanced properties versus commodity alternatives and bring significant additional value to customers and end-users. Project. The term “project” as used in this presentation can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. Resources, resource base, and recoverable resources. Along with similar terms, these refer to the total remaining estimated quantities of oil and natural gas that are expected to be ultimately recoverable. ExxonMobil refers to new discoveries and acquisitions of discovered resources as resource additions. The resource base includes quantities of oil and natural gas classified as proved reserves, as well as, quantities that are not yet classified as proved reserves, but that are expected to be ultimately recoverable. The term “resource base” or similar terms is not intended to correspond to SEC definitions such as “probable” or “possible” reserves. The term “in-place” refers to those quantities of oil and natural gas estimated to be contained in known accumulations and includes recoverable and unrecoverable amounts. 66

SUPPLEMENTAL INFORMATION DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS, CONTINUED Return on average capital employed (ROCE). ROCE is a performance measure ratio. From the perspective of the business segments, ROCE is annual business segment earnings divided by average business segment capital employed (average of beginning and end-of-year amounts). These segment earnings include ExxonMobil’s share of segment earnings of equity companies, consistent with our capital employed definition, and exclude the cost of financing. The Corporation’s total ROCE is net income attributable to ExxonMobil, excluding the after-tax cost of financing, divided by total corporate average capital employed. The Corporation has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in our capital-intensive, long-term industry, both to evaluate management’s performance and to demonstrate to shareholders that capital has been used wisely over the long term. Additional measures, which are more cash-flow based, are used to make investment decisions. For information concerning the calculation and reconciliation of ROCE see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Returns, rate of return, IRR. Unless referring specifically to external data, references to returns, rate of return, IRR, and similar terms mean future discounted cash flow returns on future capital investments based on current company estimates. Investment returns exclude prior exploration and acquisition costs. Stated Policies Scenario (STEPS). STEPS is an IEA scenario in their World Energy Outlook 2020 based on today’s policy settings and an assumption that the COVID-19 pandemic is brought under control in 2021. 67SUPPLEMENTAL INFORMATION DEFINITIONS AND NON-GAAP FINANCIAL MEASURE RECONCILIATIONS, CONTINUED Return on average capital employed (ROCE). ROCE is a performance measure ratio. From the perspective of the business segments, ROCE is annual business segment earnings divided by average business segment capital employed (average of beginning and end-of-year amounts). These segment earnings include ExxonMobil’s share of segment earnings of equity companies, consistent with our capital employed definition, and exclude the cost of financing. The Corporation’s total ROCE is net income attributable to ExxonMobil, excluding the after-tax cost of financing, divided by total corporate average capital employed. The Corporation has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in our capital-intensive, long-term industry, both to evaluate management’s performance and to demonstrate to shareholders that capital has been used wisely over the long term. Additional measures, which are more cash-flow based, are used to make investment decisions. For information concerning the calculation and reconciliation of ROCE see the Frequently Used Terms available on the Investors page of our website at www.exxonmobil.com under the heading News & Resources. Returns, rate of return, IRR. Unless referring specifically to external data, references to returns, rate of return, IRR, and similar terms mean future discounted cash flow returns on future capital investments based on current company estimates. Investment returns exclude prior exploration and acquisition costs. Stated Policies Scenario (STEPS). STEPS is an IEA scenario in their World Energy Outlook 2020 based on today’s policy settings and an assumption that the COVID-19 pandemic is brought under control in 2021. 67

SUPPLEMENTAL INFORMATION OTHER INFORMATION. All references to production rates, project capacity, resource size, and acreage are on a gross basis, unless otherwise noted. This presentation includes a number of third party scenarios such as the 74 Lower 2°C scenarios, made available through the IPCC SR 1.5 scenario explorer data, and the IEA’s Stated Policies Scenario as well as the IEA’s Sustainable Development Scenario. These third party scenarios reflect the modeling assumptions and outputs of their respective authors, not ExxonMobil, and their use and inclusion herein is not an endorsement by ExxonMobil of their likelihood or probability. The analysis done by ExxonMobil on the IPCC Lower 2°C scenarios and the representation thereof aims to reflect the average or trends across a wide range of pathways. Where data was not or insufficiently available, further analysis was done to enable a more granular view on trends within these IPCC Lower 2°C scenarios. ExxonMobil has business relationships with thousands of customers, suppliers, governments, and others. For convenience and simplicity, words such as venture, joint venture, partnership, co-venturer, operated by others, and partner are used to indicate business and other relationships involving common activities and interests, and those words may not indicate precise legal relationships. Competitor data is based on publicly available information and, where estimated or derived, done so on a consistent basis with ExxonMobil data. Future competitor data, unless otherwise noted, is taken from publicly available statements or disclosures by that competitor and has not been independently verified by ExxonMobil or any third party. We note that certain competitors report financial information under accounting standards other than U.S. GAAP (i.e., IFRS). 68SUPPLEMENTAL INFORMATION OTHER INFORMATION. All references to production rates, project capacity, resource size, and acreage are on a gross basis, unless otherwise noted. This presentation includes a number of third party scenarios such as the 74 Lower 2°C scenarios, made available through the IPCC SR 1.5 scenario explorer data, and the IEA’s Stated Policies Scenario as well as the IEA’s Sustainable Development Scenario. These third party scenarios reflect the modeling assumptions and outputs of their respective authors, not ExxonMobil, and their use and inclusion herein is not an endorsement by ExxonMobil of their likelihood or probability. The analysis done by ExxonMobil on the IPCC Lower 2°C scenarios and the representation thereof aims to reflect the average or trends across a wide range of pathways. Where data was not or insufficiently available, further analysis was done to enable a more granular view on trends within these IPCC Lower 2°C scenarios. ExxonMobil has business relationships with thousands of customers, suppliers, governments, and others. For convenience and simplicity, words such as venture, joint venture, partnership, co-venturer, operated by others, and partner are used to indicate business and other relationships involving common activities and interests, and those words may not indicate precise legal relationships. Competitor data is based on publicly available information and, where estimated or derived, done so on a consistent basis with ExxonMobil data. Future competitor data, unless otherwise noted, is taken from publicly available statements or disclosures by that competitor and has not been independently verified by ExxonMobil or any third party. We note that certain competitors report financial information under accounting standards other than U.S. GAAP (i.e., IFRS). 68

SUPPLEMENTAL INFORMATION Slide 13 Slide 16 1) Total Addressable Market figures: ExxonMobil analysis of IPCC SR 1.5 scenario 1) National Petroleum Council report. Financial assumptions include 12% explorer data on Lower 2°C scenarios for CO2, H2, Biofuels, and Fuels. Volumes internal rate of return (after tax). and prices in 2040 in the Lower 2°C scenarios were used, where available, to 2) U.S. EV tax credit: ExxonMobil analysis based on EV tax credit calculate an estimate of the market revenue. For H2, the highest and lowest (www.fueleconomy.gov/feg/taxevb.shtml) and emission factors for outliers for market revenue in the Lower 2°C scenarios were excluded. For vehicles from www.EIA.gov and other sources. 2040 IPCC Lower 2°C Chemicals, ExxonMobil analysis of current market data from Statista 2020 Report carbon price details: ExxonMobil analysis of IPCC SR 1.5 scenario explorer on Chemical Industry Worldwide, and the IEA Sustainable Development Scenario data on lower 2°C scenarios. California Low Carbon Fuel Credit: data for petrochemical feedstock growth to 2040. (https://ww2.arb.ca.gov/resources/documents/lcfs-credit-clearance- 2) IEA CCUS in Clean Energy Transitions Report (2020). market). U.S. 45Q Tax credit: (https://www.irs.gov/pub/irs-drop/td- 3) Oil and gas percentage of energy mix – IPCC SR 1.5 scenario explorer data on 9944.pdf), p. 141. Lower 2°C scenarios; depletion – ExxonMobil analysis of IEA and IHS data. 3) ExxonMobil analysis based on IEA World Energy Outlook 2020. 4) IPCC Fifth Assessment report assessed increase in societal costs to achieve a 2°C outcome without CCS. Slide 14 1) $2 trillion addressable market and projected growth: ExxonMobil analysis of IPCC Slide 18 SR 1.5 scenario explorer data on Lower 2°C scenarios. For CO , volumes and 2 1) $1 trillion market and projected growth: ExxonMobil analysis of IPCC SR prices in 2020 and 2040 in the Lower 2°C scenarios were used, where available, 1.5 scenario explorer data on Lower 2°C scenarios. For H , volumes and 2 to calculate an estimate of the market revenue and corresponding annual growth. prices in 2020 and 2040 in the Lower 2°C scenarios were used, where 2) Global CCS Institute. Data updated as of April 2020 and based on cumulative available, to calculate an estimate of the market revenue and anthropogenic carbon dioxide capture volume. Anthropogenic CO , for the 2 corresponding annual growth. For H the highest and lowest outliers for 2 purposes of this calculation, means CO that without carbon capture and storage 2 market revenue in the Lower 2°C scenarios were excluded. would have been emitted to the atmosphere, including, but not limited to: 2) IEA (2020), Energy Technology Perspectives 2020, IEA, Paris reservoir CO from gas fields; CO emitted during production and CO emitted 2 2 2 https://www.iea.org/reports/energy-technology-perspectives-2020. during combustion. It does not include natural CO produced solely for enhanced 2 oil recovery. 3) ExxonMobil analysis. Ranking estimate of CO pipelines is based on pipeline 2 capacity. 4) ExxonMobil analysis. Ranking estimate of CO geologic storage is based on 2 anthropogenic CO ; storage for natural CO produced and anthropogenic CO 2 2 2 captured for enhanced oil recovery is excluded. 69SUPPLEMENTAL INFORMATION Slide 13 Slide 16 1) Total Addressable Market figures: ExxonMobil analysis of IPCC SR 1.5 scenario 1) National Petroleum Council report. Financial assumptions include 12% explorer data on Lower 2°C scenarios for CO2, H2, Biofuels, and Fuels. Volumes internal rate of return (after tax). and prices in 2040 in the Lower 2°C scenarios were used, where available, to 2) U.S. EV tax credit: ExxonMobil analysis based on EV tax credit calculate an estimate of the market revenue. For H2, the highest and lowest (www.fueleconomy.gov/feg/taxevb.shtml) and emission factors for outliers for market revenue in the Lower 2°C scenarios were excluded. For vehicles from www.EIA.gov and other sources. 2040 IPCC Lower 2°C Chemicals, ExxonMobil analysis of current market data from Statista 2020 Report carbon price details: ExxonMobil analysis of IPCC SR 1.5 scenario explorer on Chemical Industry Worldwide, and the IEA Sustainable Development Scenario data on lower 2°C scenarios. California Low Carbon Fuel Credit: data for petrochemical feedstock growth to 2040. (https://ww2.arb.ca.gov/resources/documents/lcfs-credit-clearance- 2) IEA CCUS in Clean Energy Transitions Report (2020). market). U.S. 45Q Tax credit: (https://www.irs.gov/pub/irs-drop/td- 3) Oil and gas percentage of energy mix – IPCC SR 1.5 scenario explorer data on 9944.pdf), p. 141. Lower 2°C scenarios; depletion – ExxonMobil analysis of IEA and IHS data. 3) ExxonMobil analysis based on IEA World Energy Outlook 2020. 4) IPCC Fifth Assessment report assessed increase in societal costs to achieve a 2°C outcome without CCS. Slide 14 1) $2 trillion addressable market and projected growth: ExxonMobil analysis of IPCC Slide 18 SR 1.5 scenario explorer data on Lower 2°C scenarios. For CO , volumes and 2 1) $1 trillion market and projected growth: ExxonMobil analysis of IPCC SR prices in 2020 and 2040 in the Lower 2°C scenarios were used, where available, 1.5 scenario explorer data on Lower 2°C scenarios. For H , volumes and 2 to calculate an estimate of the market revenue and corresponding annual growth. prices in 2020 and 2040 in the Lower 2°C scenarios were used, where 2) Global CCS Institute. Data updated as of April 2020 and based on cumulative available, to calculate an estimate of the market revenue and anthropogenic carbon dioxide capture volume. Anthropogenic CO , for the 2 corresponding annual growth. For H the highest and lowest outliers for 2 purposes of this calculation, means CO that without carbon capture and storage 2 market revenue in the Lower 2°C scenarios were excluded. would have been emitted to the atmosphere, including, but not limited to: 2) IEA (2020), Energy Technology Perspectives 2020, IEA, Paris reservoir CO from gas fields; CO emitted during production and CO emitted 2 2 2 https://www.iea.org/reports/energy-technology-perspectives-2020. during combustion. It does not include natural CO produced solely for enhanced 2 oil recovery. 3) ExxonMobil analysis. Ranking estimate of CO pipelines is based on pipeline 2 capacity. 4) ExxonMobil analysis. Ranking estimate of CO geologic storage is based on 2 anthropogenic CO ; storage for natural CO produced and anthropogenic CO 2 2 2 captured for enhanced oil recovery is excluded. 69

SUPPLEMENTAL INFORMATION Slide 19 4) Global CCS Institute. Data updated as of April 2020 and based on cumulative 1) Global CO emissions: Global Carbon Budget 2020; Friedlingstein et al (2020); anthropogenic carbon dioxide capture volume. Anthropogenic CO , for the 2 2 including energy-related and cement processing CO emissions. purposes of this calculation, means CO that without carbon capture and 2 2 2) Paris submissions: estimated based on 2016 Nationally Determined storage would have been emitted to the atmosphere, including, but not limited Contributions. to: reservoir CO from gas fields; CO emitted during production and CO 2 2 2 3) Emission reduction plans announced in December 2020 include a 15 to 20 emitted during combustion. It does not include natural CO produced solely 2 percent reduction in greenhouse gas intensity of upstream operations by 2025 for enhanced oil recovery. Tree statistic calculated with U.S. EPA GHG compared to 2016 levels. This will be supported by a 40 to 50 percent reduction equivalency calculator. in methane intensity and 35 to 45 percent reduction in flaring intensity. The 2025 5) All-time, based on total wind and solar power purchase agreements signed emissions reduction plans are expected to reduce absolute greenhouse gas from BloombergNEF download Feb 22, 2021. emissions of Upstream operations by an estimated 30 percent and absolute flaring and methane emissions by 40 to 50 percent. Plans cover Scope 1 and Slide 21 Scope 2 emissions for assets operated by the company by the end of 2025, consistent with approved corporate plans. 1) IEA World Energy Outlook 2020 Annex A.5, investment data. Slide 20 Slide 22 1) Represents investments since 2000 and currently identified future investment 1) Lost-time injuries and illness rate (incidents per 200,000 work hours). opportunities through 2025, consistent with past practice, results, and 2) 2025 Available cash from operations assumes Downstream and Chemical announced plans. margins at the average of the annual margins from 2010—2019. See 2) ExxonMobil GHG emissions, absolute (operated CO -equivalent Scope 1 & 2) 2 definitions on page 65. from 2016—2019. 3) Any decisions on future dividend levels is at the discretion of the Board of 3) Emission reduction plans announced in December 2020 include a 15 to 20 Directors. percent reduction in greenhouse gas intensity of upstream operations by 2025 4) Includes projects that bring on new volumes. Breakeven based on cost-of- compared to 2016 levels. This will be supported by a 40 to 50 percent reduction supply to generate a minimum 10 percent return on a money-forward basis. in methane intensity and 35 to 45 percent reduction in flaring intensity. The 2025 5) Projected improvement 2017—2027, including all disclosed major projects, emissions reduction plans are expected to reduce absolute greenhouse gas and executed and planned portfolio management. emissions of Upstream operations by an estimated 30 percent and absolute flaring and methane emissions by 40 to 50 percent. Plans cover Scope 1 and Scope 2 emissions for assets operated by the company by the end of 2025, consistent with approved corporate plans. 70SUPPLEMENTAL INFORMATION Slide 19 4) Global CCS Institute. Data updated as of April 2020 and based on cumulative 1) Global CO emissions: Global Carbon Budget 2020; Friedlingstein et al (2020); anthropogenic carbon dioxide capture volume. Anthropogenic CO , for the 2 2 including energy-related and cement processing CO emissions. purposes of this calculation, means CO that without carbon capture and 2 2 2) Paris submissions: estimated based on 2016 Nationally Determined storage would have been emitted to the atmosphere, including, but not limited Contributions. to: reservoir CO from gas fields; CO emitted during production and CO 2 2 2 3) Emission reduction plans announced in December 2020 include a 15 to 20 emitted during combustion. It does not include natural CO produced solely 2 percent reduction in greenhouse gas intensity of upstream operations by 2025 for enhanced oil recovery. Tree statistic calculated with U.S. EPA GHG compared to 2016 levels. This will be supported by a 40 to 50 percent reduction equivalency calculator. in methane intensity and 35 to 45 percent reduction in flaring intensity. The 2025 5) All-time, based on total wind and solar power purchase agreements signed emissions reduction plans are expected to reduce absolute greenhouse gas from BloombergNEF download Feb 22, 2021. emissions of Upstream operations by an estimated 30 percent and absolute flaring and methane emissions by 40 to 50 percent. Plans cover Scope 1 and Slide 21 Scope 2 emissions for assets operated by the company by the end of 2025, consistent with approved corporate plans. 1) IEA World Energy Outlook 2020 Annex A.5, investment data. Slide 20 Slide 22 1) Represents investments since 2000 and currently identified future investment 1) Lost-time injuries and illness rate (incidents per 200,000 work hours). opportunities through 2025, consistent with past practice, results, and 2) 2025 Available cash from operations assumes Downstream and Chemical announced plans. margins at the average of the annual margins from 2010—2019. See 2) ExxonMobil GHG emissions, absolute (operated CO -equivalent Scope 1 & 2) 2 definitions on page 65. from 2016—2019. 3) Any decisions on future dividend levels is at the discretion of the Board of 3) Emission reduction plans announced in December 2020 include a 15 to 20 Directors. percent reduction in greenhouse gas intensity of upstream operations by 2025 4) Includes projects that bring on new volumes. Breakeven based on cost-of- compared to 2016 levels. This will be supported by a 40 to 50 percent reduction supply to generate a minimum 10 percent return on a money-forward basis. in methane intensity and 35 to 45 percent reduction in flaring intensity. The 2025 5) Projected improvement 2017—2027, including all disclosed major projects, emissions reduction plans are expected to reduce absolute greenhouse gas and executed and planned portfolio management. emissions of Upstream operations by an estimated 30 percent and absolute flaring and methane emissions by 40 to 50 percent. Plans cover Scope 1 and Scope 2 emissions for assets operated by the company by the end of 2025, consistent with approved corporate plans. 70

SUPPLEMENTAL INFORMATION Slide 24 5) Money-forward basis. 1) Includes projects that bring on new volumes. Breakeven based on cost-of-supply 6) Corporate objective is to set pace of investment resulting in positive annual free to generate a minimum 10 percent return on a money-forward basis. cash, industry-leading capital efficiency, and achieving double-digit returns at 2) Consideration as of effective date excluding contingent consideration. <$35/bbl. See page 65 for definition of free cash. 3) Emission reduction plans announced in December 2020 include a 15 to 20 percent reduction in greenhouse gas intensity of Upstream operations compared Slide 30 to 2016 levels supported by a corporate-wide 40 to 50 percent reduction in 1) Net resource. Includes Midland, Delaware and minor conventional operations in methane intensity and 35 to 45 percent reduction in flaring intensity. Plans cover the Central Basin Platform. Scope 1 and Scope 2 emissions, and are expected to result in a 30 percent reduction in absolute Upstream greenhouse gas emissions from assets operated Slide 31 by the Company by the end of 2025. 1) ExxonMobil internal analysis at 8 percent discount rate at $50/bbl Brent price in 2021 dollars. Slide 25 1) Includes projects that bring on new volumes. Breakeven based on cost-of-supply Slide 32 to generate a minimum 10 percent return on a money-forward basis. 1) Spud to rig-release days. 2) At IHS Markit price forecast (December 2020). 2) Drilling and completion costs per lateral foot. 3) Field operations, well work and energy expense per oil-equivalent barrel; operated business only. Slide 26 1) Comparison of ExxonMobil estimates of greenhouse gas intensity (tonnes of Slide 33 CO e per 100 tonnes of production) for Guyana and average of Upstream assets, 2 1) Core New Mexico development; 2020 wells include those in production for 180 on an operated basis, in 2025 based on approved corporate plans. days. 2) On page. 3) Money-forward basis. Slide 35 1) Comparison of ExxonMobil estimates of greenhouse gas intensity (tonnes of Slide 29 CO -equivalent per 100 tonnes of production) for Brazil Bacalhau and average of 1) Net resource. Includes Midland, Delaware and minor conventional operations in 2 Upstream assets, on an equity basis, in 2025 based on approved corporate plans. the Central Basin Platform. 2) On page. 2) Comparison of greenhouse gas intensity (tonnes of CO -equivalent per 100 2 3) Money-forward basis excluding acquisition cost. tonnes of production) for ExxonMobil operated Unconventional assets for 2025 versus 2016. 2025 estimate is based on approved corporate plans. 3) ExxonMobil analysis at 8 percent discount rate at $50/bbl Brent price in 2021 Slide 36 dollars. 1) WoodMackenzie data as of January 2021 and ExxonMobil analysis. 4) On page. 2) Net cost. 71SUPPLEMENTAL INFORMATION Slide 24 5) Money-forward basis. 1) Includes projects that bring on new volumes. Breakeven based on cost-of-supply 6) Corporate objective is to set pace of investment resulting in positive annual free to generate a minimum 10 percent return on a money-forward basis. cash, industry-leading capital efficiency, and achieving double-digit returns at 2) Consideration as of effective date excluding contingent consideration. <$35/bbl. See page 65 for definition of free cash. 3) Emission reduction plans announced in December 2020 include a 15 to 20 percent reduction in greenhouse gas intensity of Upstream operations compared Slide 30 to 2016 levels supported by a corporate-wide 40 to 50 percent reduction in 1) Net resource. Includes Midland, Delaware and minor conventional operations in methane intensity and 35 to 45 percent reduction in flaring intensity. Plans cover the Central Basin Platform. Scope 1 and Scope 2 emissions, and are expected to result in a 30 percent reduction in absolute Upstream greenhouse gas emissions from assets operated Slide 31 by the Company by the end of 2025. 1) ExxonMobil internal analysis at 8 percent discount rate at $50/bbl Brent price in 2021 dollars. Slide 25 1) Includes projects that bring on new volumes. Breakeven based on cost-of-supply Slide 32 to generate a minimum 10 percent return on a money-forward basis. 1) Spud to rig-release days. 2) At IHS Markit price forecast (December 2020). 2) Drilling and completion costs per lateral foot. 3) Field operations, well work and energy expense per oil-equivalent barrel; operated business only. Slide 26 1) Comparison of ExxonMobil estimates of greenhouse gas intensity (tonnes of Slide 33 CO e per 100 tonnes of production) for Guyana and average of Upstream assets, 2 1) Core New Mexico development; 2020 wells include those in production for 180 on an operated basis, in 2025 based on approved corporate plans. days. 2) On page. 3) Money-forward basis. Slide 35 1) Comparison of ExxonMobil estimates of greenhouse gas intensity (tonnes of Slide 29 CO -equivalent per 100 tonnes of production) for Brazil Bacalhau and average of 1) Net resource. Includes Midland, Delaware and minor conventional operations in 2 Upstream assets, on an equity basis, in 2025 based on approved corporate plans. the Central Basin Platform. 2) On page. 2) Comparison of greenhouse gas intensity (tonnes of CO -equivalent per 100 2 3) Money-forward basis excluding acquisition cost. tonnes of production) for ExxonMobil operated Unconventional assets for 2025 versus 2016. 2025 estimate is based on approved corporate plans. 3) ExxonMobil analysis at 8 percent discount rate at $50/bbl Brent price in 2021 Slide 36 dollars. 1) WoodMackenzie data as of January 2021 and ExxonMobil analysis. 4) On page. 2) Net cost. 71

SUPPLEMENTAL INFORMATION Slide 42 Slide 37 1) GDP - ExxonMobil’s 2019 Outlook for Energy; commodity chemicals 1) Based on 2018 greenhouse gas intensity (tonnes of CO -equivalent per 100 2 demand - IHS Markit World Analysis for Polyethylene, Polypropylene, and tonnes of LNG produced) of the PNG liquefaction facility compared to 2018 Paraxylene. ExxonMobil performance product sales - ExxonMobil analysis. industry performance (2018 LNG liquefaction benchmarking study completed by ExxonMobil forecast post-2020. Phillip Townsend and Associates Inc.). 2) Industry-leading earnings - Chemicals Industry Benchmark Group 2) On page. comprised of 11 of the top 20 global ethylene producers where public 3) Money-forward, weighted-average basis. information for segment earnings estimate is disclosed, and ExxonMobil estimates for fourth quarter 2020 where public information was not Slides 38 and 39 available. Group includes ExxonMobil Chemical Company, Dow Inc., 1) Money-forward basis. Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch 2) 2025 non-associated gas production versus 2021. Shell Chemicals Segment, Chevron Phillips Chemical Company, INEOS 3) On page 39. Group Ltd, Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals Segment. Slide 41 Slide 43 1) Synthetic lubricants - Kline and Company (2019) and ExxonMobil analysis. 1) IHS Markit 2020 Capacity Ranking data and ExxonMobil estimates based on Basestocks - ExxonMobil assessment of publically available sources, internally available data. generated observations, and/or 3rd party consulting services. Industry-leading 2) Leading Chemical business - chemicals industry benchmark group integration - S&P Global Platts. comprised of 11 of the top 20 global ethylene producers where public 2) Projected improvement 2017—2027, including all disclosed major projects, and information for segment earnings estimate is disclosed. ExxonMobil executed and planned portfolio management. estimates for fourth quarter 2020 where public information was not available. Group includes ExxonMobil Chemical Company, Dow Inc., Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch Shell Chemicals Segment, Chevron Phillips Chemical Company, INEOS Group Ltd, Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals Segment. Industry bar in chart excludes ExxonMobil Chemical Company. 3) ExxonMobil forecast post-2020. 72SUPPLEMENTAL INFORMATION Slide 42 Slide 37 1) GDP - ExxonMobil’s 2019 Outlook for Energy; commodity chemicals 1) Based on 2018 greenhouse gas intensity (tonnes of CO -equivalent per 100 2 demand - IHS Markit World Analysis for Polyethylene, Polypropylene, and tonnes of LNG produced) of the PNG liquefaction facility compared to 2018 Paraxylene. ExxonMobil performance product sales - ExxonMobil analysis. industry performance (2018 LNG liquefaction benchmarking study completed by ExxonMobil forecast post-2020. Phillip Townsend and Associates Inc.). 2) Industry-leading earnings - Chemicals Industry Benchmark Group 2) On page. comprised of 11 of the top 20 global ethylene producers where public 3) Money-forward, weighted-average basis. information for segment earnings estimate is disclosed, and ExxonMobil estimates for fourth quarter 2020 where public information was not Slides 38 and 39 available. Group includes ExxonMobil Chemical Company, Dow Inc., 1) Money-forward basis. Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch 2) 2025 non-associated gas production versus 2021. Shell Chemicals Segment, Chevron Phillips Chemical Company, INEOS 3) On page 39. Group Ltd, Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals Segment. Slide 41 Slide 43 1) Synthetic lubricants - Kline and Company (2019) and ExxonMobil analysis. 1) IHS Markit 2020 Capacity Ranking data and ExxonMobil estimates based on Basestocks - ExxonMobil assessment of publically available sources, internally available data. generated observations, and/or 3rd party consulting services. Industry-leading 2) Leading Chemical business - chemicals industry benchmark group integration - S&P Global Platts. comprised of 11 of the top 20 global ethylene producers where public 2) Projected improvement 2017—2027, including all disclosed major projects, and information for segment earnings estimate is disclosed. ExxonMobil executed and planned portfolio management. estimates for fourth quarter 2020 where public information was not available. Group includes ExxonMobil Chemical Company, Dow Inc., Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch Shell Chemicals Segment, Chevron Phillips Chemical Company, INEOS Group Ltd, Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals Segment. Industry bar in chart excludes ExxonMobil Chemical Company. 3) ExxonMobil forecast post-2020. 72

SUPPLEMENTAL INFORMATION Slide 45 Slide 44 1) Product benefits: 1) Shows 2027 expected volume indexed to 2017. Product mix upgrade plans • Plastic packaging - per April 2018 report of Franklin Associates; US; Max include Downstream and Chemical announced/completed conversions, all Decomp.; Figure 4-1; Impacts as defined in Chapter 4.7: Global Warming disclosed major projects, and executed portfolio management. Potential (GWP) results, and indexed to the alternatives as a group (including 2) Product spreads based on 2010—2019 average versus refining feedstock cost. steel; aluminum; glass; paper-based packaging; fiber-based textiles; and wood). Source: https://plastics.americanchemistry.com/Reports-and- Slide 46 Publications/LCA-of-Plastic-Packaging-Compared-to-Substitutes.pdf; 1) Return based on 2021 money-forward, remaining Capex-weighted basis, for Flexible film applications - Based on performance of specific ExxonMobil listed growth projects in 2027 at full capacity across Downstream and Chemical Exceed™ XP grades versus conventional polyethylene in flexible packaging using 2010—2019 annual average margins. applications. 2) Collective annual earnings generated by listed Downstream and Chemical • Polypropylene Automotive Application - Source: DOE statement: projects in 2027 at full capacity based on 2010–2019 low and average annual https://www.energy.gov/eere/vehicles/lightweight-materials-cars-and- margins. trucks • Synergy Diesel Efficient™ - Synergy Diesel Efficient™ improves fuel economy by Slide 47 2 percent versus diesel fuel without detergent additive and assumes a 250 1) Chemical earnings - chemicals industry benchmark group comprised of 11 of the gallon tank and an average of 7 miles per gallon. Source: ExxonMobil.com top 20 global ethylene producers where public information for segment earnings https://www.exxon.com/en/synergy-diesel-efficient-passenger estimate is disclosed. Estimates for fourth quarter 2020 where public information • Synthetic motor oil - Source: ExxonMobil analysis TM was not available. Group includes ExxonMobil Chemical Company, Dow Inc., • Mobil SHC Gear 320WT - Source: Performance profile at Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch Shell https://www.mobil.com/en/lubricants/for- Chemicals Segment, Chevron Phillips Chemical Company, INEOS Group Ltd, businesses/industrial/lubricants/products/mobil-shc-gear-320-wt Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals 2) On page. Segment. Industry bar in chart excludes ExxonMobil Chemical Company. 2) Industry-leading synthetic lubricants - Kline and Company (2019) and ExxonMobil analysis. 3) Major project returns - return based on 2021 money-forward basis for listed growth projects in 2027 at full capacity across Downstream and Chemical using 2010—2019 annual average margins. 73SUPPLEMENTAL INFORMATION Slide 45 Slide 44 1) Product benefits: 1) Shows 2027 expected volume indexed to 2017. Product mix upgrade plans • Plastic packaging - per April 2018 report of Franklin Associates; US; Max include Downstream and Chemical announced/completed conversions, all Decomp.; Figure 4-1; Impacts as defined in Chapter 4.7: Global Warming disclosed major projects, and executed portfolio management. Potential (GWP) results, and indexed to the alternatives as a group (including 2) Product spreads based on 2010—2019 average versus refining feedstock cost. steel; aluminum; glass; paper-based packaging; fiber-based textiles; and wood). Source: https://plastics.americanchemistry.com/Reports-and- Slide 46 Publications/LCA-of-Plastic-Packaging-Compared-to-Substitutes.pdf; 1) Return based on 2021 money-forward, remaining Capex-weighted basis, for Flexible film applications - Based on performance of specific ExxonMobil listed growth projects in 2027 at full capacity across Downstream and Chemical Exceed™ XP grades versus conventional polyethylene in flexible packaging using 2010—2019 annual average margins. applications. 2) Collective annual earnings generated by listed Downstream and Chemical • Polypropylene Automotive Application - Source: DOE statement: projects in 2027 at full capacity based on 2010–2019 low and average annual https://www.energy.gov/eere/vehicles/lightweight-materials-cars-and- margins. trucks • Synergy Diesel Efficient™ - Synergy Diesel Efficient™ improves fuel economy by Slide 47 2 percent versus diesel fuel without detergent additive and assumes a 250 1) Chemical earnings - chemicals industry benchmark group comprised of 11 of the gallon tank and an average of 7 miles per gallon. Source: ExxonMobil.com top 20 global ethylene producers where public information for segment earnings https://www.exxon.com/en/synergy-diesel-efficient-passenger estimate is disclosed. Estimates for fourth quarter 2020 where public information • Synthetic motor oil - Source: ExxonMobil analysis TM was not available. Group includes ExxonMobil Chemical Company, Dow Inc., • Mobil SHC Gear 320WT - Source: Performance profile at Sinopec Chemicals Segment, LyondellBasell Industries N.V., Royal Dutch Shell https://www.mobil.com/en/lubricants/for- Chemicals Segment, Chevron Phillips Chemical Company, INEOS Group Ltd, businesses/industrial/lubricants/products/mobil-shc-gear-320-wt Braskem, SABIC, BASF Chemicals Segment, and Reliance Petrochemicals 2) On page. Segment. Industry bar in chart excludes ExxonMobil Chemical Company. 2) Industry-leading synthetic lubricants - Kline and Company (2019) and ExxonMobil analysis. 3) Major project returns - return based on 2021 money-forward basis for listed growth projects in 2027 at full capacity across Downstream and Chemical using 2010—2019 annual average margins. 73

SUPPLEMENTAL INFORMATION Slide 52 Slide 55 1) See definition of Available cash from operations on page 65. 1) 10-year high and low Downstream and Chemical margins refer to annual highs 2) 2021 Available cash from operations assumes Downstream and Chemical and lows from 2010—2019. 10-year average Downstream and Chemical margins margins at 10-year annual lows from 2010—2019. refer to the average of annual margins from 2010—2019. 3) Any decisions on future dividend levels is at the discretion of the Board of 2) Portfolio improvements include uplift from new projects in Downstream and Directors. This chart assumes dividends per share are held flat relative to 4Q20 Chemical, uplift, base decline and nominal price inflation from Upstream, mix, levels. yield and marketing impacts, and corporate and financial impacts. 4) 10-year average Downstream and Chemical margins refer to the average of annual margins from 2010—2019. Slide 60 1) Spud to rig-release days. Slide 53 2) Drilling and completion costs per lateral foot. 1) See definition of Available cash from operations on page 65. 2) 10-year low Downstream and Chemical margins refer to annual lows from Slide 61 2010—2019. 10-year average Downstream and Chemical margins refer to the 1) 2020 wells includes those in production for 180 days. average of annual margins from 2010—2019. Slide 62 1) Cost and schedule benchmarked against recent comparable announced U.S. Slide 54 cracker projects. Sources: Public announcements (industry) and ExxonMobil 1) See definition of Available cash from operations on page 65. estimates (ExxonMobil). 2) Any decisions on future dividend levels is at the discretion of the Board of 2) Chemical margins refer to the average of annual margins from 2010—2019. Directors. This chart assumes dividends per share are held flat relative to 4Q20 levels. Slide 63 3) Available cash from operations based on 10-year low Downstream and 1) Performance polymers - per April 2018 Franklin report. Chemical margins in 2021 and 10-year average Downstream and Chemical margins from 2022—2025. 10-year low Downstream and Chemical margins refer to annual lows from 2010—2019. 10-year average Downstream and Chemical margins refer to the average of annual margins from 2010—2019. 74SUPPLEMENTAL INFORMATION Slide 52 Slide 55 1) See definition of Available cash from operations on page 65. 1) 10-year high and low Downstream and Chemical margins refer to annual highs 2) 2021 Available cash from operations assumes Downstream and Chemical and lows from 2010—2019. 10-year average Downstream and Chemical margins margins at 10-year annual lows from 2010—2019. refer to the average of annual margins from 2010—2019. 3) Any decisions on future dividend levels is at the discretion of the Board of 2) Portfolio improvements include uplift from new projects in Downstream and Directors. This chart assumes dividends per share are held flat relative to 4Q20 Chemical, uplift, base decline and nominal price inflation from Upstream, mix, levels. yield and marketing impacts, and corporate and financial impacts. 4) 10-year average Downstream and Chemical margins refer to the average of annual margins from 2010—2019. Slide 60 1) Spud to rig-release days. Slide 53 2) Drilling and completion costs per lateral foot. 1) See definition of Available cash from operations on page 65. 2) 10-year low Downstream and Chemical margins refer to annual lows from Slide 61 2010—2019. 10-year average Downstream and Chemical margins refer to the 1) 2020 wells includes those in production for 180 days. average of annual margins from 2010—2019. Slide 62 1) Cost and schedule benchmarked against recent comparable announced U.S. Slide 54 cracker projects. Sources: Public announcements (industry) and ExxonMobil 1) See definition of Available cash from operations on page 65. estimates (ExxonMobil). 2) Any decisions on future dividend levels is at the discretion of the Board of 2) Chemical margins refer to the average of annual margins from 2010—2019. Directors. This chart assumes dividends per share are held flat relative to 4Q20 levels. Slide 63 3) Available cash from operations based on 10-year low Downstream and 1) Performance polymers - per April 2018 Franklin report. Chemical margins in 2021 and 10-year average Downstream and Chemical margins from 2022—2025. 10-year low Downstream and Chemical margins refer to annual lows from 2010—2019. 10-year average Downstream and Chemical margins refer to the average of annual margins from 2010—2019. 74

FREQUENTLY USED TERMS Listed below are definitions of several of ExxonMobil’s key business and financial performance measures and other terms. These definitions are provided to facilitate understanding of the terms and their calculation. In the case of financial measures that we believe constitute “non-GAAP financial measures” under Securities and Exchange Commission Regulation G, we provide a reconciliation to the most comparable Generally Accepted Accounting Principles (GAAP) measure and other information required by that rule. Total shareholder return (TSR) • Measures the change in value of an investment in stock over a specified period of time, assuming dividend reinvestment. We calculate shareholder return over a particular measurement period by: dividing (1) the sum of (a) the cumulative value of dividends received during the measurement period, assuming reinvestment, plus (b) the difference between the stock price at the end and at the beginning of the measurement period; by (2) the stock price at the beginning of the measurement period. For this purpose, we assume dividends are reinvested in stock at market prices at approximately the same time actual dividends are paid. Shareholder return is usually quoted on an annualized basis. Capital and exploration expenditures (Capex) • Represents the combined total of additions at cost to property, plant and equipment, and exploration expenses on a before-tax basis from the Consolidated statement of income. ExxonMobil’s Capex includes its share of similar costs for equity companies. Capex excludes assets acquired in nonmonetary exchanges, the value of ExxonMobil shares used to acquire assets, and depreciation on the cost of exploration support equipment and facilities recorded to property, plant and equipment when acquired. While ExxonMobil’s management is responsible for all investments and elements of net income, particular focus is placed on managing the controllable aspects of this group of expenditures. Returns, rate of return, IRR • Unless referring specifically to external data, references to returns, rate of return, IRR, and similar terms mean future discounted cash flow returns on future capital investments based on current company estimates. Investment returns exclude prior exploration and acquisition costs. Heavy oil and oil sands • Heavy oil includes heavy oil, extra heavy oil, and bitumen, as defined by the World Petroleum Congress in 1987 based on American Petroleum Institute (API) gravity and viscosity at reservoir conditions. Heavy oil has an API gravity between 10 and 22.3 degrees. The API gravity of extra heavy oil and bitumen is less than 10 degrees. Extra heavy oil has a viscosity less than 10,000 centipoise, whereas the viscosity of bitumen is greater than 10,000 centipoise. The term “oil sands” is used to indicate heavy oil (generally bitumen) that is recovered in a mining operation. Divestments • Divestments represent the unadjusted sale price specified in the applicable contract of sale as of the effective date for asset divestiture agreements which the corporation or one of its affiliates has executed since January 1, 2019. Actual final sale price and cash proceeds may differ in amount and timing from the divestment value depending on applicable contract terms. Leverage • Leverage is defined as “net debt/(net debt + market capitalization).” Project • The term “project” can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. Proved reserves • Proved reserve figures are determined in accordance with SEC definitions. Resources, resource base, and recoverable resources • Along with similar terms, refer to the total remaining estimated quantities of oil and natural gas that are expected to be ultimately recoverable. ExxonMobil refers to new discoveries and acquisitions of discovered resources as resource additions. The resource base includes quantities of oil and natural gas classified as proved reserves, as well as quantities that are not yet classified as proved reserves, but that are expected to be ultimately recoverable. The term “resource base” or similar terms are not intended to correspond to SEC definitions such as “probable” or “possible” reserves. The term “in-place” refers to those quantities of oil and natural gas estimated to be contained in known accumulations and includes recoverable and unrecoverable amounts. 1FREQUENTLY USED TERMS Listed below are definitions of several of ExxonMobil’s key business and financial performance measures and other terms. These definitions are provided to facilitate understanding of the terms and their calculation. In the case of financial measures that we believe constitute “non-GAAP financial measures” under Securities and Exchange Commission Regulation G, we provide a reconciliation to the most comparable Generally Accepted Accounting Principles (GAAP) measure and other information required by that rule. Total shareholder return (TSR) • Measures the change in value of an investment in stock over a specified period of time, assuming dividend reinvestment. We calculate shareholder return over a particular measurement period by: dividing (1) the sum of (a) the cumulative value of dividends received during the measurement period, assuming reinvestment, plus (b) the difference between the stock price at the end and at the beginning of the measurement period; by (2) the stock price at the beginning of the measurement period. For this purpose, we assume dividends are reinvested in stock at market prices at approximately the same time actual dividends are paid. Shareholder return is usually quoted on an annualized basis. Capital and exploration expenditures (Capex) • Represents the combined total of additions at cost to property, plant and equipment, and exploration expenses on a before-tax basis from the Consolidated statement of income. ExxonMobil’s Capex includes its share of similar costs for equity companies. Capex excludes assets acquired in nonmonetary exchanges, the value of ExxonMobil shares used to acquire assets, and depreciation on the cost of exploration support equipment and facilities recorded to property, plant and equipment when acquired. While ExxonMobil’s management is responsible for all investments and elements of net income, particular focus is placed on managing the controllable aspects of this group of expenditures. Returns, rate of return, IRR • Unless referring specifically to external data, references to returns, rate of return, IRR, and similar terms mean future discounted cash flow returns on future capital investments based on current company estimates. Investment returns exclude prior exploration and acquisition costs. Heavy oil and oil sands • Heavy oil includes heavy oil, extra heavy oil, and bitumen, as defined by the World Petroleum Congress in 1987 based on American Petroleum Institute (API) gravity and viscosity at reservoir conditions. Heavy oil has an API gravity between 10 and 22.3 degrees. The API gravity of extra heavy oil and bitumen is less than 10 degrees. Extra heavy oil has a viscosity less than 10,000 centipoise, whereas the viscosity of bitumen is greater than 10,000 centipoise. The term “oil sands” is used to indicate heavy oil (generally bitumen) that is recovered in a mining operation. Divestments • Divestments represent the unadjusted sale price specified in the applicable contract of sale as of the effective date for asset divestiture agreements which the corporation or one of its affiliates has executed since January 1, 2019. Actual final sale price and cash proceeds may differ in amount and timing from the divestment value depending on applicable contract terms. Leverage • Leverage is defined as “net debt/(net debt + market capitalization).” Project • The term “project” can refer to a variety of different activities and does not necessarily have the same meaning as in any government payment transparency reports. Proved reserves • Proved reserve figures are determined in accordance with SEC definitions. Resources, resource base, and recoverable resources • Along with similar terms, refer to the total remaining estimated quantities of oil and natural gas that are expected to be ultimately recoverable. ExxonMobil refers to new discoveries and acquisitions of discovered resources as resource additions. The resource base includes quantities of oil and natural gas classified as proved reserves, as well as quantities that are not yet classified as proved reserves, but that are expected to be ultimately recoverable. The term “resource base” or similar terms are not intended to correspond to SEC definitions such as “probable” or “possible” reserves. The term “in-place” refers to those quantities of oil and natural gas estimated to be contained in known accumulations and includes recoverable and unrecoverable amounts. 1

Frequently Used Terms, continued Volume effects • Entitlements – net interest are changes to ExxonMobil’s share of production volumes caused by non-operational changes to volume-determining factors. These factors consist of net interest changes specified in Production Sharing Contracts (PSCs) which typically occur when cumulative investment returns or production volumes achieve defined thresholds, changes in equity upon achieving pay-out in partner investment carry situations, equity redeterminations as specified in venture agreements, or as a result of the termination or expiry of a concession. Once a net interest change has occurred, it typically will not be reversed by subsequent events, such as lower crude oil prices. Volume effects • Entitlements – price, spend and other are changes to ExxonMobil’s share of production volumes resulting from temporary changes to non-operational volume- determining factors. These factors include changes in oil and gas prices or spending levels from one period to another. According to the terms of contractual arrangements or government royalty regimes, price or spending variability can increase or decrease royalty burdens and/or volumes attributable to ExxonMobil. For example, at higher prices, fewer barrels are required for ExxonMobil to recover its costs. These effects generally vary from period to period with field spending patterns or market prices for oil and natural gas. Such factors can also include other temporary changes in net interest as dictated by specific provisions in production agreements. Volume effects • Government Mandates are changes to ExxonMobil’s sustainable production levels due to temporary non-operational production limits imposed by governments, generally upon a sector, type, or method of production. Volume effects • Divestments are reductions in ExxonMobil’s production arising from commercial arrangements to fully or partially reduce equity in a field or asset in exchange for financial or other economic consideration. Volume effects • Growth and other factors comprise all other operational and non-operational factors not covered by the above definitions that may affect volumes attributable to ExxonMobil. Such factors include, but are not limited to, production enhancements from project and work program activities, acquisitions including additions from asset exchanges, downtime, market demand, natural field decline, and any fiscal or commercial terms that do not affect entitlements. 2Frequently Used Terms, continued Volume effects • Entitlements – net interest are changes to ExxonMobil’s share of production volumes caused by non-operational changes to volume-determining factors. These factors consist of net interest changes specified in Production Sharing Contracts (PSCs) which typically occur when cumulative investment returns or production volumes achieve defined thresholds, changes in equity upon achieving pay-out in partner investment carry situations, equity redeterminations as specified in venture agreements, or as a result of the termination or expiry of a concession. Once a net interest change has occurred, it typically will not be reversed by subsequent events, such as lower crude oil prices. Volume effects • Entitlements – price, spend and other are changes to ExxonMobil’s share of production volumes resulting from temporary changes to non-operational volume- determining factors. These factors include changes in oil and gas prices or spending levels from one period to another. According to the terms of contractual arrangements or government royalty regimes, price or spending variability can increase or decrease royalty burdens and/or volumes attributable to ExxonMobil. For example, at higher prices, fewer barrels are required for ExxonMobil to recover its costs. These effects generally vary from period to period with field spending patterns or market prices for oil and natural gas. Such factors can also include other temporary changes in net interest as dictated by specific provisions in production agreements. Volume effects • Government Mandates are changes to ExxonMobil’s sustainable production levels due to temporary non-operational production limits imposed by governments, generally upon a sector, type, or method of production. Volume effects • Divestments are reductions in ExxonMobil’s production arising from commercial arrangements to fully or partially reduce equity in a field or asset in exchange for financial or other economic consideration. Volume effects • Growth and other factors comprise all other operational and non-operational factors not covered by the above definitions that may affect volumes attributable to ExxonMobil. Such factors include, but are not limited to, production enhancements from project and work program activities, acquisitions including additions from asset exchanges, downtime, market demand, natural field decline, and any fiscal or commercial terms that do not affect entitlements. 2

Frequently Used Terms, continued CASH FLOW FROM OPERATIONS AND ASSET SALES 2020 2019 2018 (millions of dollars) Net cash provided by operating activities 14,668 29,716 36,014 Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments 999 3,692 4,123 Cash flow from operations and asset sales 15,667 33,408 40,137 Cash flow from operations and asset sales is the sum of the net cash provided by operating activities and proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments from the Consolidated statement of cash flows. This cash flow reflects the total sources of cash from both operating the Corporation’s assets and from the divesting of assets. The Corporation employs a long-standing and regular disciplined review process to ensure all assets are contributing to the Corporation’s strategic objectives. Assets are divested when they are no longer meeting these objectives or are worth considerably more to others. Because of the regular nature of this activity, we believe it is useful for investors to consider proceeds associated with asset sales together with cash provided by operating activities when evaluating cash available for investment in the business and financing activities, including shareholder distributions. 3Frequently Used Terms, continued CASH FLOW FROM OPERATIONS AND ASSET SALES 2020 2019 2018 (millions of dollars) Net cash provided by operating activities 14,668 29,716 36,014 Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments 999 3,692 4,123 Cash flow from operations and asset sales 15,667 33,408 40,137 Cash flow from operations and asset sales is the sum of the net cash provided by operating activities and proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments from the Consolidated statement of cash flows. This cash flow reflects the total sources of cash from both operating the Corporation’s assets and from the divesting of assets. The Corporation employs a long-standing and regular disciplined review process to ensure all assets are contributing to the Corporation’s strategic objectives. Assets are divested when they are no longer meeting these objectives or are worth considerably more to others. Because of the regular nature of this activity, we believe it is useful for investors to consider proceeds associated with asset sales together with cash provided by operating activities when evaluating cash available for investment in the business and financing activities, including shareholder distributions. 3

Frequently Used Terms, continued OPERATING COSTS AND CASH OPERATING EXPENSES 2020 2019 2018 (millions of dollars) Reconciliation of operating costs From ExxonMobil’s Consolidated statement of income Total costs and other deductions 210,385 244,882 259,259 Less: Crude oil and product purchases 94,007 143,801 156,172 Interest expense 1,158 830 766 Other taxes and duties 26,122 30,525 32,663 Subtotal 89,098 69,726 69,658 ExxonMobil’s share of equity company expenses 8,292 9,088 9,569 Total operating costs 97,390 78,814 79,227 Components of operating costs From ExxonMobil’s Consolidated statement of income Production and manufacturing expenses 30,431 36,826 36,682 Selling, general and administrative expenses 10,168 11,398 11,480 Depreciation and depletion (includes impairments) 46,009 18,998 18,745 Exploration expenses, including dry holes 1,285 1,269 1,466 Non-service pension and postretirement benefit expense 1,205 1,235 1,285 Subtotal 89,098 69,726 69,658 ExxonMobil’s share of equity company expenses 8,292 9,088 9,569 Total operating costs 97,390 78,814 79,227 Cash operating expenses (cash opex) Total operating costs 97,390 78,814 79,227 Less: Depreciation and depletion (includes impairments) 46,009 18,998 18,745 Non-service pension and postretirement benefit expense 1,205 1,235 1,285 Other adjustments (includes equity company depreciation and depletion) 3,561 3,575 2,897 Total cash operating expenses (cash opex) 46,615 55,006 56,300 Upstream cash operating expenses 19,294 23,483 23,594 Downstream cash operating expenses 16,035 18,924 19,707 Chemical cash operating expenses 9,667 11,331 11,457 Corporate and Financing cash operating expenses 1,619 1,268 1,542 Total cash operating expenses (cash opex) 46,615 55,006 56,300 Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy, staffing, and maintenance costs. They exclude the cost of raw materials, taxes, and interest expense and are on a before-tax basis. While ExxonMobil’s management is responsible for all revenue and expense elements of net income, operating costs, as defined above, represent the expenses most directly under management’s control, and therefore are useful for investors and ExxonMobil management in evaluating management’s performance. Cash operating expenses (cash opex) are a subset of total operating costs that are stewarded internally to support management’s oversight of spending over time. This measure is useful for investors to understand the Corporation’s efforts to optimize cash through disciplined expense management. 4Frequently Used Terms, continued OPERATING COSTS AND CASH OPERATING EXPENSES 2020 2019 2018 (millions of dollars) Reconciliation of operating costs From ExxonMobil’s Consolidated statement of income Total costs and other deductions 210,385 244,882 259,259 Less: Crude oil and product purchases 94,007 143,801 156,172 Interest expense 1,158 830 766 Other taxes and duties 26,122 30,525 32,663 Subtotal 89,098 69,726 69,658 ExxonMobil’s share of equity company expenses 8,292 9,088 9,569 Total operating costs 97,390 78,814 79,227 Components of operating costs From ExxonMobil’s Consolidated statement of income Production and manufacturing expenses 30,431 36,826 36,682 Selling, general and administrative expenses 10,168 11,398 11,480 Depreciation and depletion (includes impairments) 46,009 18,998 18,745 Exploration expenses, including dry holes 1,285 1,269 1,466 Non-service pension and postretirement benefit expense 1,205 1,235 1,285 Subtotal 89,098 69,726 69,658 ExxonMobil’s share of equity company expenses 8,292 9,088 9,569 Total operating costs 97,390 78,814 79,227 Cash operating expenses (cash opex) Total operating costs 97,390 78,814 79,227 Less: Depreciation and depletion (includes impairments) 46,009 18,998 18,745 Non-service pension and postretirement benefit expense 1,205 1,235 1,285 Other adjustments (includes equity company depreciation and depletion) 3,561 3,575 2,897 Total cash operating expenses (cash opex) 46,615 55,006 56,300 Upstream cash operating expenses 19,294 23,483 23,594 Downstream cash operating expenses 16,035 18,924 19,707 Chemical cash operating expenses 9,667 11,331 11,457 Corporate and Financing cash operating expenses 1,619 1,268 1,542 Total cash operating expenses (cash opex) 46,615 55,006 56,300 Operating costs are the costs during the period to produce, manufacture, and otherwise prepare the company’s products for sale – including energy, staffing, and maintenance costs. They exclude the cost of raw materials, taxes, and interest expense and are on a before-tax basis. While ExxonMobil’s management is responsible for all revenue and expense elements of net income, operating costs, as defined above, represent the expenses most directly under management’s control, and therefore are useful for investors and ExxonMobil management in evaluating management’s performance. Cash operating expenses (cash opex) are a subset of total operating costs that are stewarded internally to support management’s oversight of spending over time. This measure is useful for investors to understand the Corporation’s efforts to optimize cash through disciplined expense management. 4

Frequently Used Terms, continued FREE CASH FLOW 2020 2019 2018 (millions of dollars) Net cash provided by operating activities 14,668 29,716 36,014 Additions to property, plant and equipment (17,282) (24,361) (19,574) Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments 999 3,692 4,123 Additional investments and advances (4,857) (3,905) (1,981) Other investing activities including collection of advances 2,681 1,490 986 Free cash flow (3,791 6,632 19,568 ) Free cash flow is cash flow from operations and asset sales less additions to property, plant and equipment, and additional investments and advances, plus other investing activities, including collection of advances. This measure is useful when evaluating cash available for financing activities, including shareholder distributions, after investment in the business. DISTRIBUTIONS TO SHAREHOLDERS 2020 2019 2018 (millions of dollars) Dividends paid to ExxonMobil shareholders 14,865 14,652 13,798 Cost of shares acquired to reduce shares outstanding – – – Distributions to ExxonMobil shareholders 14,865 14,652 13,798 Memo: Gross cost of shares acquired to offset shares or units settled in shares issued under benefit plans and programs 405 594 626 The Corporation distributes cash to shareholders in the form of both dividends and share purchases. Shares are acquired to reduce shares outstanding and offset shares or units settled in shares issued in conjunction with company benefit plans and programs. For purposes of calculating distributions to shareholders, the Corporation only includes the cost of those shares acquired to reduce shares outstanding. CAPITAL EMPLOYED AT YEAR END 2020 2019 2018 (millions of dollars) Business uses: asset and liability perspective Total assets 332,750 362,597 346,196 Less liabilities and noncontrolling interests share of assets and liabilities Total current liabilities excluding notes and loans payable (35,905) (43,411) (39,880) Total long-term liabilities excluding long-term debt (65,075) (73,328) (69,992) Noncontrolling interests share of assets and liabilities (8,773) (8,839) (7,958) Add ExxonMobil share of debt-financed equity company net assets 4,140 3,906 3,914 Total capital employed 227,137 240,925 232,280 Total corporate sources: debt and equity perspective Notes and loans payable 20,458 20,578 17,258 Long-term debt 47,182 26,342 20,538 ExxonMobil share of equity 157,150 191,650 191,794 Less noncontrolling interests share of total debt (1,793) (1,551) (1,224) Add ExxonMobil share of equity company debt 4,140 3,906 3,914 Total capital employed 227,137 240,925 232,280 Capital employed is a measure of net investment. When viewed from the perspective of how the capital is used by the businesses, it includes ExxonMobil’s net share of property, plant and equipment, and other assets, less liabilities, excluding both short-term and long-term debt. When viewed from the perspective of the sources of capital employed in total for the Corporation, it includes ExxonMobil’s share of total debt and equity. Both of these views include ExxonMobil’s share of amounts applicable to equity companies, which the Corporation believes should be included to provide a more comprehensive measure of capital employed. 5Frequently Used Terms, continued FREE CASH FLOW 2020 2019 2018 (millions of dollars) Net cash provided by operating activities 14,668 29,716 36,014 Additions to property, plant and equipment (17,282) (24,361) (19,574) Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments 999 3,692 4,123 Additional investments and advances (4,857) (3,905) (1,981) Other investing activities including collection of advances 2,681 1,490 986 Free cash flow (3,791 6,632 19,568 ) Free cash flow is cash flow from operations and asset sales less additions to property, plant and equipment, and additional investments and advances, plus other investing activities, including collection of advances. This measure is useful when evaluating cash available for financing activities, including shareholder distributions, after investment in the business. DISTRIBUTIONS TO SHAREHOLDERS 2020 2019 2018 (millions of dollars) Dividends paid to ExxonMobil shareholders 14,865 14,652 13,798 Cost of shares acquired to reduce shares outstanding – – – Distributions to ExxonMobil shareholders 14,865 14,652 13,798 Memo: Gross cost of shares acquired to offset shares or units settled in shares issued under benefit plans and programs 405 594 626 The Corporation distributes cash to shareholders in the form of both dividends and share purchases. Shares are acquired to reduce shares outstanding and offset shares or units settled in shares issued in conjunction with company benefit plans and programs. For purposes of calculating distributions to shareholders, the Corporation only includes the cost of those shares acquired to reduce shares outstanding. CAPITAL EMPLOYED AT YEAR END 2020 2019 2018 (millions of dollars) Business uses: asset and liability perspective Total assets 332,750 362,597 346,196 Less liabilities and noncontrolling interests share of assets and liabilities Total current liabilities excluding notes and loans payable (35,905) (43,411) (39,880) Total long-term liabilities excluding long-term debt (65,075) (73,328) (69,992) Noncontrolling interests share of assets and liabilities (8,773) (8,839) (7,958) Add ExxonMobil share of debt-financed equity company net assets 4,140 3,906 3,914 Total capital employed 227,137 240,925 232,280 Total corporate sources: debt and equity perspective Notes and loans payable 20,458 20,578 17,258 Long-term debt 47,182 26,342 20,538 ExxonMobil share of equity 157,150 191,650 191,794 Less noncontrolling interests share of total debt (1,793) (1,551) (1,224) Add ExxonMobil share of equity company debt 4,140 3,906 3,914 Total capital employed 227,137 240,925 232,280 Capital employed is a measure of net investment. When viewed from the perspective of how the capital is used by the businesses, it includes ExxonMobil’s net share of property, plant and equipment, and other assets, less liabilities, excluding both short-term and long-term debt. When viewed from the perspective of the sources of capital employed in total for the Corporation, it includes ExxonMobil’s share of total debt and equity. Both of these views include ExxonMobil’s share of amounts applicable to equity companies, which the Corporation believes should be included to provide a more comprehensive measure of capital employed. 5

Frequently Used Terms, continued RETURN ON AVERAGE CAPITAL EMPLOYED (ROCE) 2020 2019 2018 (millions of dollars) Net income attributable to ExxonMobil (22,440) 14,340 20,840 Financing costs (after tax) Gross third-party debt (1,272) (1,075) (912) ExxonMobil share of equity companies (182) (207) (192) All other financing costs – net 666 141 498 Total financing costs (788) (1,141) (606) Earnings excluding financing costs (21,652) 15,481 21,446 Average capital employed 234,031 236,603 232,374 Return on average capital employed – corporate total (9.3%) 6.5% 9.2% ROCE is a performance measure ratio. From the perspective of the business segments, ROCE is annual business segment earnings divided by average business segment capital employed (average of beginning and end-of-year amounts). These segment earnings include ExxonMobil’s share of segment earnings of equity companies, consistent with our capital employed definition, and exclude the cost of financing. The Corporation’s total ROCE is net income attributable to ExxonMobil, excluding the after-tax cost of financing, divided by total corporate average capital employed. The Corporation has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in our capital-intensive, long-term industry, both to evaluate management’s performance and to demonstrate to shareholders that capital has been used wisely over the long term. Additional measures, which are more cash-flow based, are used to make investment decisions. See page 7 for segment information relevant to ROCE. 6Frequently Used Terms, continued RETURN ON AVERAGE CAPITAL EMPLOYED (ROCE) 2020 2019 2018 (millions of dollars) Net income attributable to ExxonMobil (22,440) 14,340 20,840 Financing costs (after tax) Gross third-party debt (1,272) (1,075) (912) ExxonMobil share of equity companies (182) (207) (192) All other financing costs – net 666 141 498 Total financing costs (788) (1,141) (606) Earnings excluding financing costs (21,652) 15,481 21,446 Average capital employed 234,031 236,603 232,374 Return on average capital employed – corporate total (9.3%) 6.5% 9.2% ROCE is a performance measure ratio. From the perspective of the business segments, ROCE is annual business segment earnings divided by average business segment capital employed (average of beginning and end-of-year amounts). These segment earnings include ExxonMobil’s share of segment earnings of equity companies, consistent with our capital employed definition, and exclude the cost of financing. The Corporation’s total ROCE is net income attributable to ExxonMobil, excluding the after-tax cost of financing, divided by total corporate average capital employed. The Corporation has consistently applied its ROCE definition for many years and views it as the best measure of historical capital productivity in our capital-intensive, long-term industry, both to evaluate management’s performance and to demonstrate to shareholders that capital has been used wisely over the long term. Additional measures, which are more cash-flow based, are used to make investment decisions. See page 7 for segment information relevant to ROCE. 6

Frequently Used Terms, continued 1 AVERAGE CAPITAL EMPLOYED BY BUSINESS 2020 2019 2018 (millions of dollars) Upstream United States 65,780 72,152 69,981 Non-U.S. 107,506 107,271 107,893 Total 173,286 179,423 177,874 Downstream United States 11,472 9,515 8,725 Non-U.S. 18,682 18,518 17,015 Total 30,154 28,033 25,740 Chemical United States 14,436 13,196 12,171 Non-U.S. 17,600 18,113 18,249 Total 32,036 31,309 30,420 Corporate and Financing (1,445) (2,162) (1,660) Corporate total 234,031 236,603 232,374 Average capital employed applicable to equity companies included above 42,232 40,322 38,150 1 Average capital employed is the average of beginning-of-year and end-of-year business segment capital employed, including Exxon Mobil’s share of amounts applicable to equity companies. RETURN ON AVERAGE CAPITAL EMPLOYED BY BUSINESS 2020 2019 2018 (percent) Upstream United States (29.5) 0.7 2.5 Non-U.S. (0.6) 13.0 11.4 Total (11.6) 8.0 7.9 Downstream United States (7.4) 18.0 33.9 Non-U.S. (1.2) 3.3 17.9 Total (3.6) 8.3 23.3 Chemical United States 8.8 1.6 13.5 Non-U.S. 3.9 2.1 9.4 Total 6.1 1.9 11.0 Corporate and Financing N.A. N.A. N.A. Corporate total (9.3) 6.5 9.2 7Frequently Used Terms, continued 1 AVERAGE CAPITAL EMPLOYED BY BUSINESS 2020 2019 2018 (millions of dollars) Upstream United States 65,780 72,152 69,981 Non-U.S. 107,506 107,271 107,893 Total 173,286 179,423 177,874 Downstream United States 11,472 9,515 8,725 Non-U.S. 18,682 18,518 17,015 Total 30,154 28,033 25,740 Chemical United States 14,436 13,196 12,171 Non-U.S. 17,600 18,113 18,249 Total 32,036 31,309 30,420 Corporate and Financing (1,445) (2,162) (1,660) Corporate total 234,031 236,603 232,374 Average capital employed applicable to equity companies included above 42,232 40,322 38,150 1 Average capital employed is the average of beginning-of-year and end-of-year business segment capital employed, including Exxon Mobil’s share of amounts applicable to equity companies. RETURN ON AVERAGE CAPITAL EMPLOYED BY BUSINESS 2020 2019 2018 (percent) Upstream United States (29.5) 0.7 2.5 Non-U.S. (0.6) 13.0 11.4 Total (11.6) 8.0 7.9 Downstream United States (7.4) 18.0 33.9 Non-U.S. (1.2) 3.3 17.9 Total (3.6) 8.3 23.3 Chemical United States 8.8 1.6 13.5 Non-U.S. 3.9 2.1 9.4 Total 6.1 1.9 11.0 Corporate and Financing N.A. N.A. N.A. Corporate total (9.3) 6.5 9.2 7

Frequently Used Terms, continued 1 FUNCTIONAL EARNINGS (millions of dollars) 2020 quarters Earnings (Loss) (U.S. GAAP) First Second Third Fourth 2020 2019 2018 Upstream United States (704) (1,197) (681) (16,803) (19,385) 536 1,739 Non-U.S. 1,240 (454) 298 (1,729) (645) 13,906 12,340 Total 536 (1,651) (383) (18,532) (20,030) 14,442 14,079 Downstream United States (101) (101) (136) (514) (852) 1,717 2,962 Non-U.S. (510) 1,077 (95) (697) (225) 606 3,048 Total (611) 976 (231) (1,211) (1,077) 2,323 6,010 Chemical United States 288 171 357 461 1,277 206 1,642 Non-U.S. (144) 296 304 230 686 386 1,709 Total 144 467 661 691 1,963 592 3,351 Corporate and Financing (679) (872) (727) (1,018) (3,296) (3,017) (2,600) Net income (loss) attributable to ExxonMobil (U.S. GAAP) (610) (1,080) (680) (20,070) (22,440 14,340 20,840 ) 1 Unless indicated, references to earnings and Upstream, Downstream, Chemical, and Corporate and Financing segment earnings are E xxonMobil’s share after excluding amounts attributable to noncontrolling interests. 8Frequently Used Terms, continued 1 FUNCTIONAL EARNINGS (millions of dollars) 2020 quarters Earnings (Loss) (U.S. GAAP) First Second Third Fourth 2020 2019 2018 Upstream United States (704) (1,197) (681) (16,803) (19,385) 536 1,739 Non-U.S. 1,240 (454) 298 (1,729) (645) 13,906 12,340 Total 536 (1,651) (383) (18,532) (20,030) 14,442 14,079 Downstream United States (101) (101) (136) (514) (852) 1,717 2,962 Non-U.S. (510) 1,077 (95) (697) (225) 606 3,048 Total (611) 976 (231) (1,211) (1,077) 2,323 6,010 Chemical United States 288 171 357 461 1,277 206 1,642 Non-U.S. (144) 296 304 230 686 386 1,709 Total 144 467 661 691 1,963 592 3,351 Corporate and Financing (679) (872) (727) (1,018) (3,296) (3,017) (2,600) Net income (loss) attributable to ExxonMobil (U.S. GAAP) (610) (1,080) (680) (20,070) (22,440 14,340 20,840 ) 1 Unless indicated, references to earnings and Upstream, Downstream, Chemical, and Corporate and Financing segment earnings are E xxonMobil’s share after excluding amounts attributable to noncontrolling interests. 8

Frequently Used Terms, continued TOTAL TAXES INCLUDING SALES-BASED TAXES 2020 2019 2018 (millions of dollars) Income taxes (5,632) 5,282 9,532 Total other taxes and duties 28,425 33,186 35,230 Total taxes 22,793 38,468 44,762 Sales-based taxes 16,281 20,679 21,750 Total taxes including sales-based taxes 39,074 59,147 66,512 Total taxes including sales-based taxes is a broader indicator of the total tax burden on the Corporation’s products and earnings, including certain sales and value-added taxes imposed on and concurrent with revenue-producing transactions with customers and collected on behalf of governmental authorities (“sales-based taxes”). It combines “Income taxes” and “Total other taxes and duties” with sales-based taxes, which are reported net in the income statement. We believe it is useful for the Corporation and its investors to understand the total tax burden imposed on the Corporation’s products and earnings. 1 PP&E ADDS/INVESTMENTS & ADVANCES 2020 2019 2018 (millions of dollars) Additions to property, plant and equipment 17,282 24,361 19,574 Additional investments and advances 4,857 3,905 1,981 ) Other investing activities including collection of advances (2,681 (1,490) (986) PP&E Adds/Investments & Advances 19,458 26,776 20,569 1 PP&E adds/investments & advances derived from the Consolidated statement of cash flows. 9Frequently Used Terms, continued TOTAL TAXES INCLUDING SALES-BASED TAXES 2020 2019 2018 (millions of dollars) Income taxes (5,632) 5,282 9,532 Total other taxes and duties 28,425 33,186 35,230 Total taxes 22,793 38,468 44,762 Sales-based taxes 16,281 20,679 21,750 Total taxes including sales-based taxes 39,074 59,147 66,512 Total taxes including sales-based taxes is a broader indicator of the total tax burden on the Corporation’s products and earnings, including certain sales and value-added taxes imposed on and concurrent with revenue-producing transactions with customers and collected on behalf of governmental authorities (“sales-based taxes”). It combines “Income taxes” and “Total other taxes and duties” with sales-based taxes, which are reported net in the income statement. We believe it is useful for the Corporation and its investors to understand the total tax burden imposed on the Corporation’s products and earnings. 1 PP&E ADDS/INVESTMENTS & ADVANCES 2020 2019 2018 (millions of dollars) Additions to property, plant and equipment 17,282 24,361 19,574 Additional investments and advances 4,857 3,905 1,981 ) Other investing activities including collection of advances (2,681 (1,490) (986) PP&E Adds/Investments & Advances 19,458 26,776 20,569 1 PP&E adds/investments & advances derived from the Consolidated statement of cash flows. 9