powering the future 2024 annual report our strategy chevron’s strategy is to leverage our strengths to safely deliver lower carbon energy to a growing world Our objective is to safely deliver higher returns, lower carbon and superior shareholder value in any business environment. We are leveraging our capabilities, assets and customer relationships as we aim to lead in lower carbon intensity oil, products and natural gas, as well as advance new products and solutions that reduce the carbon emissions of major industries. We aim to grow our oil and gas business, lower the carbon intensity of our operations and grow new businesses in renewable fuels, carbon capture and offsets, hydrogen, power generation for data centers, and emerging technologies. delivering results in the gulf We believe affordable, reliable and ever-cleaner energy is essential to enabling human progress. For more than 85 years, Chevron and our legacy companies have been developing the oil and gas resources of the Gulf of America. In fact, Chevron is one of the leading producers in the Gulf of America, where we operate some of the world’s lowest carbon intensity oil and gas assets. Our deepwater platforms – Anchor, Big Foot, Blind Faith, Petronius, Jack/St. Malo, and Tahiti – are marvels of engineering. Tahiti alone has produced more than 500 million barrels of oil-equivalent since it started production in 2009. In 2024, we achieved another groundbreaking milestone with first oil from Anchor, our newest platform in the gulf. This state-of-the-art facility marks the first delivery of deepwater high-pressure technology, capable of safely operating at up to 20,000 pounds per square inch, with reservoir depths some 34,000 feet below sea level. Our operated and nonoperated facilities in the Gulf of America are projected to reach a combined net production of 300,000 barrels of oil-equivalent per day in 2026, further solidifying Chevron’s legacy as a leader in energy innovation. 1 th92 ousand net barrels of oil-equivalent per day from our Gulf of America assets in 2024 gros17 s wells added to our gulf production in 2024 > milli2 on gross acres of leases, making Chevron one of the gulf’s largest leaseholders Anchor FPU Gulf of America Deepwater Design capacity of 75,000 gross barrels of oil per day and 28 million gross cubic feet of natural gas per day Chevron Corporation 2024 Annual Report 1 table of contents to our stockholders 4 leveraging our strengths 8 board of directors 10 director: one-on-one 12 corporate officers 14 chevron at a glance 16 chevron stock performance 18 financial and operating highlights 20 process safety, reliability and integrity 22 financials 24 history 107 glossary of energy and financial terms 108 stockholder and investor information 110 Tengiz Oil and Gas Processing Plant Kazakhstan Conventional Over 730,000 net boepd production on a 100% TCO basis in 2024 and 260,000 bpd potential increase with FGP-WPMP project now complete powering the future We believe in the power of human ingenuity to solve any challenge and overcome any obstacle. Our work developing affordable, reliable and ever‑cleaner energy has made human progress a reality for people around the world. As customers, industries and nations strive to achieve economic prosperity, energy security and environmental protection, our capabilities, assets and relationships have a vital role to play. This is a noble call to leadership we proudly embrace. We look to the future with optimism, confident in the potential of our people and the undeniable power of energy to advance even greater progress. Learn more at: chevron.co/powering to our stockholders Events of the past year affirmed the crucial role energy plays in powering the world economy. Growing demand for all types of energy – including oil and natural gas – occurred amid continued instability in the Middle East and Europe, highlighting the link between energy and geopolitics. As nations seek to strengthen their energy security and ensure the reliable supplies needed to drive economic productivity, Chevron remains focused on our belief that affordable, reliable, ever‑cleaner energy enables human progress. executing our strategy Our strategy remains consistent: leverage our strengths to safely deliver lower carbon energy to a growing world. This begins with a portfolio of world‑class assets, which positions us for profitable growth, unlocked through the capabilities of our people, technologies and strong customer relationships. Our strategy is underpinned by our long-standing financial priorities: • Grow the dividend consistently: In January 2025, we raised the per-share dividend 5% to $1.71 per quarter. 2024 marked the 37th consecutive year of higher annual per-share dividend payout. • Invest capital efficiently: We delivered growth with a disciplined capital investment of $16.4 billion. These investments allowed us to deliver record production in the Permian Basin, while bringing new projects on line in the United States, Kazakhstan and West Africa. • Maintain a strong balance sheet: We finished the year with a debt ratio of 13.9% and a net debt ratio of 10.4%, both well below our historical average. Our balance sheet provides the financial strength and flexibility to navigate volatility, consistently reward stockholders and opportunistically capture value. • Return excess cash to stockholders: In 2024, we returned a record $27.0 billion to stockholders, including $15.2 billion in share repurchases, extending our track record of repurchasing shares to 17 of the past 21 years. the energy landscape In 2024, global energy demand set record highs. Oil consumption reached an estimated 103 million barrels per day and natural gas demand reached an estimated 4.2 trillion cubic meters. In 2025, global energy demand is projected to once again set records, with oil and natural gas remaining essential. Global energy investment topped an estimated $3 trillion for the first time in 2024, with just over one‑third directed to traditional energy, including oil and gas. Continued investment across the energy system will be critical, with more than $3 trillion of annual investment expected through the end of this decade to meet projected growth in demand. Chevron Corporation 2024 Annual Report 4 delivering profitable growth Our upstream business achieved another record year of production, driven by the Permian and Denver-Julesburg (DJ) basins. We produced more than 3.3 million net barrels of oil‑equivalent (boe) per day in 2024, up 7% from 2023 – and the highest in our history. Permian Basin production averaged an all-time high of 921,000 net boe per day, a nearly 18% increase from 2023, accounting for more than half of our total U.S. production of nearly 1.6 million net boe per day. We expect Permian production to reach 1 million boe per day in 2025. Project milestones achieved in 2024 set Chevron on a trajectory to deliver profitable future growth. Technological and engineering innovation is enabling Chevron’s Gulf of America operations, where our Anchor project achieved first oil. This breakthrough was made possible by safely deploying technology that can handle pressures up to 20,000 pounds per square inch to unlock resources previously difficult to access. Photo of Mike Wirth the sixth-largest asset in the gulf of america by total oil‑equivalent output to date, tahiti recently surpassed 500 million gross barrels of oil-equivalent cumulative production In August, we achieved first water injection at our St. Malo field, making it Chevron’s first waterflood project in the deepwater Wilcox trend. The project is expected to add approximately 175 million barrels of oil-equivalent to the St. Malo field’s gross ultimate recovery. We also expanded waterflood operations at our Tahiti facility. The sixth-largest asset in the Gulf of America by total oil-equivalent output to date, Tahiti recently surpassed 500 million gross barrels of oil‑equivalent cumulative production. With incremental investment, Tahiti could continue producing beyond 2040. In Kazakhstan, Tengizchevroil (TCO), Chevron’s 50%-owned affiliate, completed the Wellhead Pressure Management Project (WPMP) designed to optimize the producing field. And in January 2025, TCO started oil production at the Future Growth Project (FGP), designed to add 260,000 barrels of oil per day to production and ramp up total output to 1 million barrels of oil-equivalent per day. Over the past year, we continued to expand our exploration portfolio by adding new positions in Australia, Angola, Brazil, Equatorial Guinea, Namibia and Uruguay. We marked the 70-year anniversary of our partnership with Angola by achieving first gas on the Sanha Lean Gas Connection project, which will provide secure supply to the Angola Liquefied Natural Gas facility. Our transaction with Hess Corporation received approval from Hess’ stockholders and clearance by the Federal Trade Commission. We remain confident ongoing arbitration proceedings will confirm Hess’ position. In 2024, we took action to optimize our portfolio, selling the Athabasca Oil Sands and Duvernay shale assets in Canada, North Slope assets in Alaska, and we withdrew from Myanmar. We also sold our assets in Congo in early 2025. In downstream, we completed a retrofit of our refinery in Pasadena, Texas, allowing Chevron to process more equity crude from the Permian Basin, supply more products to our customers in the U.S. Gulf Coast and realize synergies with our Pascagoula, Mississippi, refinery. advancing lower carbon solutions In 2024, we completed projects and operational changes designed to abate over 700,000 tonnes of carbon dioxide-equivalent annually from our operations. Chevron continues to advance lower carbon‑intensity fuel solutions, including the construction of an oilseed processing plant in Louisiana through our joint venture, Bunge Chevron Ag Renewables LLC and an expansion project at our Geismar, Louisiana, biorefinery. The Geismar expansion is expected to start up in 2025, increasing renewable diesel nameplate capacity from 7,000 to 22,000 barrels per day. We drilled onshore and offshore test wells at Bayou Bend on the U.S. Gulf Coast and expanded our carbon dioxide storage portfolio by adding 2.6 million acres offshore Western Australia. Our ACES Delta green hydrogen project in Utah is expected to begin commercial operation in 2025. This large-scale hydrogen project aims to convert water into hydrogen, using renewable energy and utilizing salt caverns for dispatchable energy storage for power generation. In January 2025, we announced a partnership to develop scalable power solutions for U.S. data centers to run on U.S. natural gas to Chevron Corporation 2024 Annual Report 6 in 2024, we completed projects and operational changes designed to abate over 700,000 tonnes of carbon dioxide‑equivalent annually from our operations provide affordable, reliable energy to support AI advancements. These projects are considering flexible designs to potentially incorporate CCUS, renewables or other lower carbon-intensity enhancements in the future. looking to the future At Chevron, we’re proud of the role we play as a global leader in energy. Our capabilities, assets and relationships are helping customers, industries and nations achieve their goals for economic prosperity, energy security and environmental protection. As energy needs grow and geopolitical volatility continues, oil and natural gas will remain vital to people and markets around the world. We look ahead with optimism and are grateful for the continued trust you place in us. Sincerely, Michael K. Wirth Chairman of the Board and Chief Executive Officer Chevron Corporation 2024 Annual Report 7 The Board of Directors visited Angola during Chevron’s 70th anniversary of operations in the country. Pictured here, Chairman Mike Wirth and Lead Director Dr. Wanda Austin (center, in blue) visit the Malongo Camp workforce in Cabinda, a province of Angola. leveraging our strengths to safely deliver lower carbon energy to a growing world we tap the power of our portfolio through our people and technology scaling solutions Chevron’s technology strategy focuses on integrating digital solutions and innovative technologies to enhance operational efficiency, safety and GHG management. We’re accelerating technology solutions to help safely deliver the lower carbon energy the growing world demands today, while helping build the energy system for tomorrow. power the core Technology is critical to safely delivering affordable, reliable and lower carbon energy today. As we continue to reduce the carbon intensity of our products, we’re applying advanced technologies to help the energy system stay resilient as it seeks to deliver lower carbon energy. build for tomorrow Technology is essential to efficiently scale new energy businesses we believe will be a part of the future energy system. Chevron’s leading experts, solution developers, energy innovators and problem solvers are searching for the next technology breakthroughs. watch for the future Multiple solutions are needed to meet growing energy demands in lower carbon ways. We seek out emerging technologies at the cutting edge of innovation. From ideas to pilot projects, we use our expertise, experience and partnerships to evaluate and scale solutions. we aim to scale affordable, innovative technology solutions to support a resilient, lower carbon energy system Learn more at: chevron.co/technology Chevron Corporation 2024 Annual Report 8 Gorgon Australia Liquefied natural gas 15.6 million-metric-ton- per‑year LNG facility with a carbon capture and underground storage facility and domestic gas plant Chevron Corporation 2024 Annual Report 9 board of directors The Board of Directors of Chevron directs the affairs of the corporation and is committed to sound principles of corporate governance. The Directors bring a proven track record of success across a broad range of experiences at the policymaking level. Michael K. (Mike) Wirth, 64 Chairman of the Board and Chief Executive Officer since February 2018. Prior to his current role, Wirth served as Vice Chairman of the Board in 2017 and Executive Vice President of Midstream & Development from 2016 to 2018. In that role, he was responsible for supply and trading, shipping, pipeline and power operating units; corporate strategy; business development; and corporate affairs. Wirth was Executive Vice President of Downstream & Chemicals from 2006 to 2015. He served as President of Global Supply and Trading from 2003 to 2006. Wirth serves on the board of directors of the American Petroleum Institute, Catalyst and the National Football Foundation, and is a member of the National Petroleum Council, the Business Roundtable, the World Economic Forum International Business Council, the American Heart Association CEO Roundtable, The Business Council, and the American Society of Corporate Executives. Wirth joined Chevron in 1982 as a design engineer. He earned a bachelor’s degree in chemical engineering from the University of Colorado. Wanda M. Austin, 70 Lead Director since 2022 and a Director since 2016. She holds an adjunct Research Professor appointment at the University of Southern California’s Viterbi School’s Department of Industrial and Systems Engineering. She is a retired President and Chief Executive Officer of The Aerospace Corporation, a leading architect for the United States’ national security space programs. She is also a Director of Amgen Inc. and Apple Inc.2,3 John B. Frank, 68 Director since 2017. He is Vice Chairman of Brookfield Oaktree Holdings, LLC (formerly Oaktree Capital Group, LLC), a global investment management company with expertise in credit strategies. He was previously the firm’s Principal Executive Officer. He is also a Director of Daily Journal Corporation and Brookfield Oaktree Holdings, LLC and its subsidiary, Oaktree Specialty Lending Corporation.1 Alice P. Gast, 66 Director since 2012. She was President of Imperial College London, a public research university specializing in science, engineering, medicine and business. Previously, she was President of Lehigh University in Pennsylvania. Prior to that, she was Vice President for Research, Associate Provost and Robert T. Haslam Chair in Chemical Engineering at the Massachusetts Institute of Technology.2,4 Enrique Hernandez, Jr., 69 Director since 2008. He is Executive Chairman of Inter-Con Security Systems Inc., a global provider of security and facility support services to governments, utilities and industrial customers. He is also a Director of The Macerich Company.3,4 Chevron Corporation 2024 Annual Report 10 Marillyn A. Hewson, 71 Director since 2021. She was Executive Chairman, Chairman, President and Chief Executive Officer of Lockheed Martin Corporation, a security and aerospace company. She is also a Director of Johnson & Johnson.1 Jon M. Huntsman Jr., 65 Director since 2020 and from 2014 to 2017 when he resigned to serve as the U.S. Ambassador to Russia. He is Vice Chairman and President, Strategic Growth, for Mastercard Incorporated. Previously, he served as Vice Chair of Policy at Ford Motor Company from 2021 to 2023, as U.S. Ambassador to China and was Governor of Utah for two consecutive terms. He is also a Director of Ford Motor Company.3,4 Charles W. Moorman, 73 Director since 2012. He is a retired Chairman of the Board, Chief Executive Officer and President of Norfolk Southern Corporation, a freight and transportation company. He served as a Senior Advisor to Amtrak from 2018 to 2023, having previously served as Amtrak’s President and Chief Executive Officer. He is also a Director of Oracle Corporation.2,3 Dambisa F. Moyo, 56 Director since 2016. She is Co-Principal of Versaca Investments, a family office focused on growth investing globally. She sits as a member of the House of Lords in Britain, as Baroness Moyo of Knightsbridge. Previously, she served as Chief Executive Officer of Mildstorm LLC, focusing on the global economy and international affairs. Prior to that, she worked at Goldman Sachs in various roles and at the World Bank in Washington, D.C.1 Debra Reed-Klages, 68 Director since 2018. She is a retired Chairman, Chief Executive Officer and President of Sempra, an energy services holding company. Previously, she was Executive Vice President of Sempra and President and Chief Executive Officer of San Diego Gas & Electric and Southern California Gas Co. She is also a Director of Caterpillar Inc. and Lockheed Martin Corporation.1 D. James Umpleby III, 67 Director since 2018. He is Chairman and Chief Executive Officer of Caterpillar Inc., a leading manufacturer of construction and mining equipment, diesel and natural gas engines, industrial gas turbines and diesel-electric locomotives. Previously, he was Group President of Caterpillar’s Energy and Transportation business segment.2,4 Cynthia J. Warner, 66 Director since 2022. She was President and Chief Executive Officer of Renewable Energy Group, Inc. (REG) and a member of REG’s board of directors. Previously, she was Executive Vice President, Operations for Andeavor. She is also a Director of Sempra and Bloom Energy, and a member of the National Petroleum Council.4 1 Audit: Debra Reed-Klages, Chair 2 Board Nominating and Governance: Wanda M. Austin, Chair 3 Management Compensation: Charles W. Moorman, Chair 4 Public Policy and Sustainability: Enrique Hernandez, Jr., Chair committees of the board Chevron Corporation 2024 Annual Report 11 director: one-on-one director cynthia (c.j.) warner talks about her work on the board of directors’ public policy and sustainability committeePhoto: Wanda Austin visiting RBU fac C.J. Warner has served as a Chevron Director since 2022. With more than 45 years of experience in the traditional and renewable energy sectors, Warner has an extensive background in refining and its health, safety, security, environmental and operational issues. She led the groundbreaking cooperative effort with the U.S. Environmental Protection Agency to shape a framework for air quality improvements, which the entire U.S. refining industry eventually adopted. Warner was President and Chief Executive Officer of Renewable Energy Group, Inc. (REG) and a member of REG’s board of directors, positions she held when Chevron acquired REG. She is a Director of Sempra and Bloom Energy, a Trustee for Vanderbilt University and a member of both the Vanderbilt School of Engineering Academy of Distinguished Alumni and the National Petroleum Council. Chevron Corporation 2024 Annual Report 12 how does the public policy and sustainability committee assist the board in addressing stockholder concerns, particularly regarding sustainability and climate-related matters? The Committee assists the Board of Directors with overseeing alignment of Chevron’s policies and practices with stockholder interests, including the long-term strength and resilience of our portfolio and infrastructure in light of sustainability- related matters. The Committee, together with the Board Nominating and Governance Committee, oversees Chevron’s stockholder engagement program. This involves receiving updates on Chevron’s engagement plans and briefings on feedback from stockholders, and discussing how Chevron is addressing their concerns, including those related to sustainability and climate‑related matters. A robust stockholder engagement program is essential to our company’s corporate governance. Our program involves regular communication with stockholders throughout the year to understand their expectations regarding governance, community impact and environmental performance. Chevron held over 90 one-on-one meetings on these topics in 2024 with stockholders representing more than 40% of Chevron’s outstanding common stock. what steps does the committee take to address stakeholder concerns related to environmental and social issues? The Public Policy and Sustainability Committee identifies, monitors and evaluates environmental, social, political, human rights and public policy aspects of Chevron’s business and the communities in which Chevron operates. We place a priority on the safety and health of the company’s workforce and the protection of communities, the environment, and assets. The Committee reviews and evaluates stockholder proposals, including those that relate to environmental and social issues. We analyze the potential merits, alignment with stockholder expectations and interests, and alignment with Chevron’s values and, together with the Board Nominating and Governance Committee, provide informed counsel to the Board of Directors on how to recommend that a stockholder vote on these proposals. We also oversee the development and implementation of Chevron’s sustainability-related initiatives. This includes monitoring progress and execution of strategic plans and how these activities align with long-term stockholder interests. The Committee reviews Chevron’s voluntary sustainability and climate-related reports. We stay apprised of legal and regulatory trends and requirements, as well as industry standards and best practices, to inform our oversight of management’s performance in maintaining compliance with relevant environmental and social regulations. how does the board stay informed about changes in environmental regulations? which projects or achievements would you emphasize in this area? Your Board has the diverse skills, experience and expertise necessary to effectively oversee the company’s strategic and business planning process and the effectiveness of its legal compliance program. Given the dynamic nature of this area, we emphasize continuous learning and prioritize board educational opportunities in our regular agenda. We have access to Chevron’s internal subject matter experts and regularly receive briefings on company environmental performance and other environmental matters, including proposed regulations. Additionally, we meet with outside experts to hear their perspectives. One aspect to highlight is the company’s efforts to reduce the carbon intensity of its operations by managing methane emissions, flaring and energy consumption. Chevron’s ambition is to remain top-quartile in methane emissions performance and to meet that aim with a simple goal – keep methane in the pipe. Since 2022, the company has committed to design, where possible, new upstream facilities without routine methane emissions. And we continue to trial technologies to better detect and measure methane emissions. In 2024, Chevron continued to deploy advanced methane detection technologies, including ground sensors, airborne sensors and satellites, to monitor and inform opportunities to reduce emissions. Chevron’s monitoring and detection program provides insights to improve how its facilities are designed, operated and maintained to help remove, reduce or prevent methane emissions as part of normal operations. From 2016 to 2024, Chevron’s upstream methane intensity was reduced by more than 60%. The Board believes the continued global demand for oil and gas should be met by responsible producers. As Chevron pursues its objective to safely deliver higher returns, lower carbon and superior shareholder value in any business environment, protecting people, assets, communities and the environment is a priority. Chevron Corporation 2024 Annual Report 13 corporate officers Paul R. Antebi, 53 Vice President and General Tax Counsel since 2021. Responsible for directing Chevron’s worldwide tax activities. Previously, the company’s Deputy General Tax Counsel. Joined the company in 1998. Marissa Badenhorst, 49 Vice President, Health, Safety and Environment (HSE) since 2022. Responsible for leading the company’s HSE management, including audit and assurance and emergency response. Previously, General Manager of Enterprise Process Safety. Prior to that, Technical Manager, Chevron Australia. Joined the company in 2000. Eimear P. Bonner, 51 Vice President and Chief Financial Officer since 2024. Responsible for audit, controller, investor relations, tax and treasury activities worldwide. Previously President Chevron Technical Center and Chief Technology Officer. Joined the company in 1998. Mary A. Francis, 60 Corporate Secretary and Chief Governance Officer since 2015. Responsible for providing advice and counsel to the Board of Directors and senior management on corporate governance matters, managing the company’s corporate governance function, and serving on the Law Function Executive Committee. Previously, Chief Corporate Counsel. Joined the company in 2002. Michelle R. Green, 53 Vice President and Chief Human Resources Officer since 2025. Responsible for the global HR organization, including all aspects of people management and advancing the company’s efforts to attract world-class talent and support its workforce. Previously Vice President for Human Resources, Oil, Products & Gas. Joined the company in 1998. Jeff B. Gustavson, 52 Vice President, Lower Carbon Energies since 2021. Responsible for lower carbon solutions that have the potential to scale, including commercialization opportunities in lower carbon power, hydrogen, carbon capture, and support of ongoing growth in biofuels. Previously, Vice President, Mid‑Continent Business Unit; and President, Chevron Canada Limited. Joined the company in 1999. Alana K. Knowles, 60 Vice President and Controller since 2023. Responsible for corporatewide accounting, financial reporting and analysis, internal controls, accounting policy, and finance technology solutions. Previously, Vice President, Finance, Downstream & Chemicals and Midstream; and Assistant Treasurer, Operating Company Financing. Joined the company in 1988. Molly T. Laegeler, 47 Vice President, Strategy & Sustainability since 2023. Responsible for guiding development of the company’s key strategies, including capital allocation and sustainability efforts. Previously, Vice President of Chevron North America Exploration & Production Company’s San Joaquin Valley Business Unit. Joined the company in 2005. Chevron Corporation 2024 Annual Report 14 Laura J. Lane, 58 Vice President and Chief Corporate Affairs Officer since 2025. Responsible for overseeing government and public affairs, social investment and performance, and the company’s worldwide efforts to protect and enhance its reputation. Previously, Chief Corporate Affairs Officer for UPS and Managing Director and Head of International Government Affairs for Citigroup. Joined the company in 2025. Navin K. Mahajan, 58 Vice President and Treasurer since 2019. Responsible for Chevron’s banking, financing, cash management, insurance, pension investments, and credits and receivables activities. Previously, Vice President of Finance for Downstream & Chemicals, Assistant Treasurer of Operating Company Financing, and Chief Compliance Officer. Joined the company in 1996. Frank W. Mount, 55 Vice President, Corporate Business Development since 2023. Responsible for identifying and developing new, large-scale business opportunities worldwide, including mergers and acquisitions. Previously, President of M&A and Origination; and General Manager of Investor Relations. Joined the company in 1993. Mark A. Nelson, 61 Vice Chairman since 2023. Responsible for the oil, products, and gas value chains, advancing a more integrated approach to capital allocation, asset class excellence and value chain optimization. Previously, Executive Vice President, Strategic Business Solutions. Joined the company in 1985. R. Hewitt Pate, 62 Vice President and General Counsel since 2009. Responsible for directing the company’s worldwide legal affairs. Previously, Chair, Competition Practice, Hunton & Williams LLP, Washington, D.C., and Assistant Attorney General, Antitrust Division, U.S. Department of Justice. Joined the company in 2009. executive committee Michael K. Wirth Eimear P. Bonner Jeff B. Gustavson Mark A. Nelson R. Hewitt Pate retiring officers A. Nigel Hearne retired February 2025. Executive Vice President, Senior Advisor. Previously Executive Vice President, Oil, Products & Gas. Joined the company in 1989. Rhonda J. Morris retiring April 2025. Vice President and Chief Human Resources Officer. Previously, Vice President, Human Resources, Downstream & Chemicals. Joined the company in 1991. Colin E. Parfitt retiring April 2025. Vice President, Midstream. Previously, President, Supply and Trading. Joined the company in 1995. Albert J. Williams retiring April 2025. Vice President, Corporate Affairs. Previously, Managing Director of Chevron Australia. Joined the company in 1991. Chevron Corporation 2024 Annual Report 15 chevron at a glance Chevron is one of the world’s leading integrated energy companies. We believe affordable, reliable and ever‑cleaner energy is essential to enabling human progress. Chevron produces crude oil and natural gas; manufactures transportation fuels, lubricants, petrochemicals and additives; and develops technologies that enhance our business and the industry. We aim to grow our oil and gas business, lower the carbon intensity of our operations, and grow new businesses in renewable fuels, hydrogen, carbon capture and offsets, power generation for data centers, and emerging technologies. Our success is driven by a dedicated, diverse and highly skilled global workforce united by The Chevron Way, our enduring statement of culture, and our focus on delivering industry-leading results and superior stockholder value. We focus on strong performance in health, safety and the environment. The protection of people, assets, communities and the environment is a priority. 3.3 million barrels net oil-equivalent daily production1 9.8 billion barrels net oil-equivalent proved reserves2,3 $256.9 billion total assets2 $193.4 billion sales and otheroperating revenues1 Chevron Corporation 2024 Annual Report 16 1 Year ended December 31, 2024 2 At December 31, 2024 3 For definition of “reserves,” see glossary of energy and financial terms, page 109 Our Culture Global Operational Excellence Working hard to provide energy that helps improve the lives of people around the world Chevron Corporation 2024 Annual Report 17 chevron stock performance Indexed dividend growth Basis 2009 = 100 Ch art sh owi ng the 6. 3% C VX c oumpo und annual growth rate Chevron S&P 500 Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR). Dividends include both cash and scrip share distributions for European peers. Total stockholder returns* (As of 12/31/2024) 1-year Char t sh ow ing th e 5 8.1% stockh older return over 1 year compared to Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) 5-year Cha rt s ho wi ng the 12.2% stoc kholder return over 5 years compared to Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) 10-year Cha rt s ho wi ng the 9.6 % stockholder return over 10 years compared to Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) Chevron Chevron Corporation 2024 Annual Report 18 * Annualized total stockholder return (TSR) as of 12/31/2024. Includes stock price appreciation and reinvested dividends when paid. For TSR comparison purposes, ADR/ ADS prices and dividends are used for non-U.S.-based companies. Dividends include both cash and scrip share distributions. 2024 marked the 37th consecutive year chevron increased the annual per-share dividend payout Five-year cumulative total returns (Calendar years ended December 31) Char t sh owin g t he Five -yea r cu mula tive tot al r etur ns c ompa red to P eer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) Chevron S&P 500 Peer group: BP p.l.c. (ADS), ExxonMobil, Shell p.l.c. (ADS), TotalEnergies SE (ADR) Performance graph The stock performance graph above shows how an initial investment of $100 in Chevron stock would have compared with an equal investment in the S&P 500 Index or the competitor peer group. The comparison covers a five-year period beginning December 31, 2019, and ending December 31, 2024, and the peer group is weighted by market capitalization as of the beginning of each year. It includes the reinvestment of all dividends that an investor would be entitled to receive and is adjusted for stock splits. The interim measurement points show the value of $100 invested on December 31, 2019, as of the end of each year between 2020 and 2024. Chevron Corporation 2024 Annual Report 19 financial and operating highlights financial highlights1 2024 2023 2022 Net income attributable to Chevron Corporation $ 17,661 $ 21,369 $ 35,465 Sales and other operating revenues $ 193,414 $ 196,913 $ 235,717 Cash flow from operating activities $ 31,492 $ 35,609 $ 49,602 Capital expenditures (CAPEX) $ 16,448 $ 15,829 $ 11,974 Affiliate capital expenditures (affiliate CAPEX) $ 2,449 $ 3,534 $ 3,366 Total assets at year-end $ 256,938 $ 261,632 $ 257,709 Total debt and finance lease obligations at year-end $ 24,541 $ 20,836 $ 23,339 Chevron Corporation stockholders’ equity at year-end $ 152,318 $ 160,957 $ 159,282 Common shares outstanding at year-end (thousands)2 1,754,844 1,851,480 1,901,048 Per-share data Net income attributable to Chevron Corporation – diluted $ 9.72 $ 11.36 $ 18.28 Cash dividends $ 6.52 $ 6.04 $ 5.68 Chevron Corporation stockholders’ equity $ 86.80 $ 86.93 $ 83.79 Total debt to total debt-plus-equity ratio3 13.9% 11.5% 12.8% Net debt ratio3 10.4% 7.3% 3.3% Return on stockholders’ equity3 11.3% 13.3% 23.8% Return on average capital employed3 10.1% 11.9% 20.3% 1 Millions of dollars, except per-share amounts 2 Net of Chevron Benefit Plan Trust shares, see page 58 for more information 3 See pages 42–43 for additional information Chevron Corporation 2024 Annual Report 20 Cash returned to stockholders (Billions of dollars) Ch art sh owi ng t he d ebt rati o an d net debt ratio over the past five years Cash returned to stockholders – Total amount of cash returned to stockholders in the form of dividends and share repurchases. Return on average capital employed (Percent) Cha rt sh owi ng t he R etur n on cap ital employed over the past five years Return on Average Capital Employed – Net income attributable to Chevron (adjusted for after-tax interest expense and noncontrolling interest) divided by average capital employed. Chevron Corporation 2024 Annual Report 21 operating highlights1 2024 2023 2022 Net production of crude oil, condensate and synthetic oil (Thousands of barrels per day) 1,560 1,497 1,440 Net production of natural gas liquids (Thousands of barrels per day) 415 333 279 Net production of natural gas (Millions of cubic feet per day) 8,178 7,744 7,677 Net oil-equivalent production (Thousands of oil-equivalent barrels per day) 3,338 3,120 2,999 Net proved reserves of crude oil, condensate and synthetic oil2 (Millions of barrels) 3,916 4,777 4,997 Net proved reserves of natural gas liquids2 (Millions of barrels) 1,159 1,229 1,088 Net proved reserves of natural gas2 (Billions of cubic feet) 28,375 30,381 30,864 Net proved oil-equivalent reserves2 (Millions of barrels) 9,804 11,069 11,229 Refinery crude oil input (Thousands of barrels per day) 1,563 1,598 1,576 Sales of refined products (Thousands of barrels per day) 2,781 2,732 2,614 Number of employees at year-end3 39,742 40,212 38,258 1 Includes equity in affiliates, except number of employees 2 At year-end 3 Excludes service station employees (5,556 in 2024) process safety, reliability and integrity our approach: by maintaining rigorous standards and practices, we can protect the integrity of our operations, safeguard our employees and the environment, and ensure the consistent delivery of energy to our markets striving for consistent execution across our value chain Conduct of Operations (COO) seeks to instill disciplined behavior and actions so that activities are conducted in a predetermined manner, provide the intended barrier to high-consequence process safety incidents, promote strong operational excellence performance and build resilience into our value chain. COO is the backbone of our business. It’s our process safety culture to maintain the highest standards of safety and reliability at every step in our value chain. At its core, COO seeks to encourage consistent, disciplined actions for reliable performance. COO encompasses five key elements that strive to achieve clarity, consistency and repeatability in operating practices, reducing execution variability, and improving safe, reliable and consistent operational performance. Learn more about how we protect people and the environment at: chevron.co/process Chevron Corporation 2024 Annual Report 22 1 structured operations Conduct of Operations defines standards and requirements to structure operational activities. The goal is to deliberately influence task performance and reduce outcome variability to enhance safety, reliability and consistency in operations. 2 operating procedures Requirements for providing operations personnel with current and accurate Operating Procedures to safely start up, operate and shut down process and/or equipment in an incident- free manner. 3 operator routine duties Requirements for the periodic surveillance of equipment to verify fitness for service and correct defects to maintain safe and reliable operations. 4 managing process boundaries Requirements to ensure that alarms achieve their goal of alerting Operations personnel to abnormal situations requiring their response to maintain safety and reliable operations. 5 managing communications Requirements for verbal and written practices to ensure Operations personnel communicate significant changes across shifts and rotations to ensure the continuity of safe and reliable operations. Chevron Corporation 2024 Annual Report 23 Management’s Discussion and Analysis of Financial Condition and Results of Operations Notes to the Consolidated Financial Statements Key Financial Results ................................................................................ 25 Note 1 Summary of Significant Accounting Policies........................... 59 Earnings by Major Operating Area ........................................................... 25 Note 2 Changes in Accumulated Other Comprehensive Losses ....... 62 Business Environment and Outlook ......................................................... 25 Note 3 Information Relating to the Consolidated Statement of Cash Flows ............................................................................... 63 Noteworthy Developments ....................................................................... 32 Note 4 New Accounting Standards ..................................................... 64 Results of Operations ............................................................................... 33 Note 5 Lease Commitments ................................................................ 64 Consolidated Statement of Income ........................................................... 35 Note 6 Summarized Financial Data – Chevron U.S.A. Inc ................. 66 Selected Operating Data ............................................................................37 Note 7 Summarized Financial Data – Tengizchevroil LLP ................. 66 Liquidity and Capital Resources ............................................................... 38 Note 8 Restructuring and Reorganization Costs ................................ 66 Financial Ratios and Metrics ..................................................................... 42 Note 9 Fair Value Measurements ........................................................ 67 Financial and Derivative Instrument Market Risk ..................................... 43 Note 10 Financial and Derivative Instruments ...................................... 68 Transactions With Related Parties............................................................ 44 Note 11 Assets Held for Sale ................................................................. 69 Litigation and Other Contingencies .......................................................... 44 Note 12 Equity ........................................................................................ 69 Environmental Matters .............................................................................. 45 Note 13 Earnings Per Share ...................................................................70 Critical Accounting Estimates and Assumptions ...................................... 46 Note 14 Operating Segments and Geographic Data .............................70 New Accounting Standards ....................................................................... 49 Note 15 Investments and Advances ...................................................... 73 Quarterly Results ...................................................................................... 50 Note 16 Litigation ....................................................................................75 Note 17 Taxes ........................................................................................ 77 Consolidated Financial Statements Note 18 Properties, Plant and Equipment ............................................. 80 Reports of Management .............................................................................51 Note 19 Short-Term Debt ....................................................................... 80 Note 20 Long-Term Debt ........................................................................ Report of Independent Registered Public Accounting Firm 81 (PCAOB ID: 238) ....................................................................................... 52 Note 21 Accounting for Suspended Exploratory Wells .........................81 Consolidated Statement of Income ........................................................... 54 Note 22 Stock Options and Other Share-Based Compensation ......... 82 Consolidated Statement of Comprehensive Income ............................... 55 Note 23 Employee Benefit Plans ........................................................... 84 Consolidated Balance Sheet ..................................................................... 56 Note 24 Other Contingencies and Commitments ................................. 89 Consolidated Statement of Cash Flows .................................................... 57 Note 25 Asset Retirement Obligations .................................................. 90 Note 26 Revenue .................................................................................... Consolidated Statement of Equity ............................................................ 91 58 Note 27 Other Financial Information ......................................................91 Note 28 Financial Instruments – Credit Losses .................................... 92 Note 29 Acquisition of PDC Energy, Inc ................................................ 93 Note 30 Agreement to Acquire Hess Corporation ................................ 93 Supplemental Information on Oil and Gas Producing Activities ............. 94 CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995 This Annual Report of Chevron Corporation contains forward-looking statements relating to Chevron’s operations, assets, and strategy that are based on management’s current expectations, estimates and projections about the petroleum, chemicals and other energy-related industries. Words or phrases such as “anticipates,” “expects,” “intends,” “plans,” “targets,” “advances,” “commits,” “drives,” “aims,” “forecasts,” “projects,” “believes,” “approaches,” “seeks,” “schedules,” “estimates,” “positions,” “pursues,” “progress,” “design,” “enable,” “may,” “can,” “could,” “should,” “will,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on track,” “trajectory,” “goals,” “objectives,” “strategies,” “opportunities,” “poised,” “potential,” “ambitions,” “future,” “aspires” and similar expressions, and variations or negatives of these words, are intended to identify such forward-looking statements, but not all forward-looking statements include such words. These statements are not guarantees of future performance and are subject to numerous risks, uncertainties and other factors, many of which are beyond the company’s control and are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed or forecasted in such forward-looking statements. The reader should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Chevron undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise. Among the important factors that could cause actual results to differ materially from those in the forward-looking statements are: changing crude oil and natural gas prices and demand for the company’s products, and production curtailments due to market conditions; crude oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries and other producing countries; technological advancements; changes to government policies in the countries in which the company operates; public health crises, such as pandemics and epidemics, and any related government policies and actions; disruptions in the company’s global supply chain, including supply chain constraints and escalation of the cost of goods and services; changing economic, regulatory and political environments in the various countries in which the company operates; general domestic and international economic, market and political conditions, including the military conflict between Russia and Ukraine, the conflict in the Middle East and the global response to these hostilities; changing refining, marketing and chemicals margins; the company’s ability to realize anticipated cost savings and efficiencies associated with enterprise structural cost reduction initiatives; actions of competitors or regulators; timing of exploration expenses; changes in projected future cash flows; timing of crude oil liftings; uncertainties about the estimated quantities of crude oil, natural gas liquids and natural gas reserves; the competitiveness of alternate-energy sources or product substitutes; pace and scale of the development of large carbon capture and offset markets; the results of operations and financial condition of the company’s suppliers, vendors, partners and equity affiliates; the inability or failure of the company’s joint-venture partners to fund their share of operations and development activities; the potential failure to achieve expected net production from existing and future crude oil and natural gas development projects; potential delays in the development, construction or start-up of planned projects; the potential disruption or interruption of the company’s operations due to war, accidents, political events, civil unrest, severe weather, cyber threats, terrorist acts, or other natural or human causes beyond the company’s control; the potential liability for remedial actions or assessments under existing or future environmental regulations and litigation; significant operational, investment or product changes undertaken or required by existing or future environmental statutes and regulations, including international agreements and national or regional legislation and regulatory measures related to greenhouse gas emissions and climate change; the potential liability resulting from pending or future litigation; the risk that regulatory approvals and clearances related to the Hess Corporation (Hess) transaction are not obtained or are not obtained in a timely manner or are obtained subject to conditions that are not anticipated by the company and Hess; potential delays in consummating the Hess transaction, including as a result of the ongoing arbitration proceedings regarding preemptive rights in the Stabroek Block joint operating agreement; risks that such ongoing arbitration is not satisfactorily resolved and the potential transaction fails to be consummated; uncertainties as to whether the potential transaction, if consummated, will achieve its anticipated economic benefits, including as a result of risks associated with third party contracts containing material consent, anti-assignment, transfer or other provisions that may be related to the potential transaction that are not waived or otherwise satisfactorily resolved; the company’s ability to integrate Hess’ operations in a successful manner and in the expected time period; the possibility that any of the anticipated benefits and projected synergies of the potential transaction will not be realized or will not be realized within the expected time period; the company’s future acquisitions or dispositions of assets or shares or the delay or failure of such transactions to close based on required closing conditions; the potential for gains and losses from asset dispositions or impairments; government mandated sales, divestitures, recapitalizations, taxes and tax audits, tariffs, sanctions, changes in fiscal terms or restrictions on scope of company operations; foreign currency movements compared with the U.S. dollar; higher inflation and related impacts; material reductions in corporate liquidity and access to debt markets; changes to the company’s capital allocation strategies; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; the company’s ability to identify and mitigate the risks and hazards inherent in operating in the global energy industry; and the factors set forth under the heading “Risk Factors” on pages 20 through 27 in the Annual Report on Form 10-K, and as updated in the future. Other unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements. Chevron Corporation 2024 Annual Report 24 Key Financial Results Millions of dollars, except per-share amounts 2024 2023 2022 Net Income (Loss) Attributable to Chevron Corporation $ 17,661 $ 21,369 $ 35,465 Per Share Amounts: Net Income (Loss) Attributable to Chevron Corporation – Basic $ 9.76 $ 11.41 $ 18.36 – Diluted $ 9.72 $ 11.36 $ 18.28 Dividends $ 6.52 $ 6.04 $ 5.68 Sales and Other Operating Revenues $ 193,414 $ 196,913 $ 235,717 Return on: Capital Employed 10.1 % 11.9 % 20.3 % Stockholders’ Equity 11.3 % 13.3 % 23.8 % Earnings by Major Operating Area Millions of dollars 2024 2023 2022 Upstream United States $ 7,602 $ 4,148 $ 12,621 International 11,000 13,290 17,663 Total Upstream 18,602 17,438 30,284 Downstream United States 531 3,904 5,394 International 1,196 2,233 2,761 Total Downstream 1,727 6,137 8,155 All Other (2,668) (2,206) (2,974) Net Income (Loss) Attributable to Chevron Corporation1,2 $ 17,661 $ 21,369 $ 35,465 1 Includes foreign currency effects: $ 520 $ (224) $ 669 2 Income net of tax, also referred to as “earnings” in the discussions that follow. Refer to the Results of Operations section for a discussion of financial results by major operating area for the three years ended December 31, 2024. Throughout the document, certain totals and percentages may not sum to their component parts due to rounding. Business Environment and Outlook Chevron Corporation is a global energy company with direct and indirect subsidiaries and affiliates that conduct substantial business activities in the following countries: Angola, Argentina, Australia, Bangladesh, Brazil, Canada, China, Egypt, Equatorial Guinea, Israel, Kazakhstan, Mexico, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait, the Philippines, Singapore, South Korea, Thailand, the United Kingdom, the United States and Venezuela. The company’s objective is to safely deliver higher returns, lower carbon and superior shareholder value in any business environment. Earnings of the company depend mostly on the profitability of its upstream business segment. The most significant factor affecting the results of operations for the upstream segment is the price of crude oil, which is determined in global markets outside of the company’s control. In the company’s downstream business, crude oil is the largest cost component of refined products. Periods of sustained lower commodity prices could result in the impairment or write-off of specific assets in future periods and cause the company to adjust operating expenses, including employee reductions, and capital expenditures, along with other measures intended to improve financial performance. Some governments, companies, communities and other stakeholders are supporting efforts to address climate change. International initiatives and national, regional and state legislation and regulations that aim to directly or indirectly reduce GHG emissions are in various stages of design, adoption and implementation. These policies and programs, some of which support the global net zero emissions ambitions of the Paris Agreement, can change the amount of energy consumed, the rate of energy-demand growth, the energy mix and the relative economics of one fuel versus another. Implementation of jurisdiction-specific policies and programs can be dependent on, and can affect the pace of, technological advancements; the granting of necessary permits by governing authorities; the availability and acceptability of cost-effective, verifiable carbon credits; the availability of suppliers that can meet our sustainability-related standards; evolving regulatory or other requirements affecting ESG standards or disclosures and evolving standards and regulations for tracking, reporting, marketing and advertising relating to emissions and emission reductions and removals. Some of these policies and programs include renewable and low carbon fuel standards, such as the Renewable Fuel Standard program in the U.S. and California’s Low Carbon Fuel Standard; programs that price GHG emissions, including Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 25 California’s Cap-and-Trade Program; performance standards, including methane-specific regulations such as the United States Environmental Protection Agency (U.S. EPA) Standards of Performance for New, Reconstructed, and Modified Sources and Emissions Guidelines for Existing Sources; and measures that provide various incentives for lower carbon activities, including carbon capture and storage and the production of hydrogen and sustainable aviation fuel, such as the U.S. Inflation Reduction Act. Requirements for these and other similar policies and programs are complex, ever changing, program specific and encompass: (1) the blending of renewable fuels into transportation fuels; (2) the purchasing, selling, utilizing and retiring of allowances and carbon credits; and (3) other emissions reduction measures including efficiency improvements and capturing GHG emissions. These compliance policies and programs have had and may continue to have negative impacts on the company now and in the future including, but not limited to, the displacement of hydrocarbon and other products and/or the impairment of assets. These policies have also enabled opportunities for Chevron in its lower carbon business lines. For example, Renewable Energy Group, Inc. (REG) produces most of Chevron’s renewable fuels offering and generates a substantial amount of the company’s carbon credit generation activities. Although we expect the company’s costs to comply with these policies and programs to continue to increase, these costs currently do not have a material impact on the company’s financial condition or results of operations. Significant uncertainty remains as to the pace and extent to which the transition to a lower carbon future will progress, which is dependent, in part, on further advancements and changes in policy, technology, and customer and consumer preferences. The level of expenditure required to comply with new or potential climate change-related laws and regulations and the amount of additional investments needed in new or existing technology or facilities, such as carbon capture and storage, is difficult to predict with certainty and is expected to vary depending on the actual laws and regulations enacted, available technology options, customer and consumer preferences, the company’s activities and market conditions. As discussed below, in 2021, the company announced planned capital spend of approximately $10 billion through 2028 in lower carbon investments. Although the future is uncertain, many published outlooks conclude that fossil fuels will remain a significant part of an energy system that increasingly incorporates lower carbon sources of supply for many years to come. Chevron supports the Paris Agreement’s global approach to governments addressing climate change and continues to take actions to help lower the carbon intensity of its operations while continuing to meet the demand for energy. Chevron believes that broad, market-based mechanisms are the most efficient approach to addressing GHG emission reductions. Chevron integrates climate change-related issues and the regulatory and other responses to these issues into its strategy and planning, capital investment reviews and risk management tools and processes, where it believes they are applicable. They are also factored into the company’s long-range supply, demand and energy price forecasts. These forecasts reflect estimates of long-range effects from climate change-related policy actions, such as electric vehicle and renewable fuel penetration, energy efficiency standards and demand response to oil and natural gas prices. The company will continue to develop oil and gas resources to meet customers’ and consumers’ demand for energy. At the same time, Chevron believes that the future of energy is lower carbon. The company will continue to maintain flexibility in its portfolio to be responsive to changes in policy, technology, and customer and consumer preferences. Chevron aims to grow its oil and gas business, lower the carbon intensity of its operations and grow new businesses in renewable fuels, carbon capture and offsets, hydrogen, power generation for data centers, and emerging technologies. To grow its new businesses, Chevron plans to target sectors of the economy where emissions are harder to abate or that cannot be easily electrified, while leveraging the company’s capabilities, assets, partnerships and customer relationships. The company’s oil and gas business may increase or decrease depending upon market, economic, legislative and regulatory forces, among other factors. In 2021, Chevron announced aspirations and targets that align with its strategy, as noted below. Chevron uses emissions intensity targets, which enable the company to assess, quantify and transparently communicate its own carbon performance in a standardized way. Chevron regularly evaluates its aspirations, targets and goals and expects to change or eliminate some of its aspirations, targets and goals for various reasons, including market conditions; its strategy or portfolio; and financial, operational, policy, reputational, legal and other factors. The company’s ability to achieve any aspiration, target or goal is subject to numerous risks and contingencies, many of which are outside of Chevron’s control. Examples of such risks and contingencies include: (1) sufficient and substantial advances in technology, including the continuing progress of commercially viable technologies and low- or non-carbon- based energy sources; (2) laws, governmental regulation, policies, and other enabling actions, including those regarding subsidies, tax and other incentives as well as the granting of necessary permits by governing authorities; (3) the availability and acceptability of cost-effective, verifiable carbon credits; (4) the availability of suppliers that can meet our Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 26 sustainability-related standards; (5) evolving regulatory requirements, including changes to IPCC’s Global Warming Potentials and the U.S. EPA Greenhouse Gas Reporting Program, affecting ESG standards or disclosures; (6) evolving standards for tracking and reporting on emissions and emission reductions and removals; (7) customers’ and consumers’ preferences and use of the company’s products or substitute products; (8) actions taken by the company’s competitors in response to legislation and regulations; and (9) successful negotiations for carbon capture and storage and nature-based solutions with customers, suppliers, partners and governments. Please refer to “Risk Factors” in Part I, Item 1A, on pages 23 through 27 of the company’s Annual Report on Form 10-K for further discussion of GHG regulation and climate change and the associated risks to Chevron’s business, including the risks impacting Chevron’s strategy, aspirations, targets and disclosures related to environmental, social, and governance matters. 2050 Net Zero Upstream Aspiration Chevron aspires to achieve net zero for upstream production Scope 1 and 2 GHG emissions on an equity basis by 2050. The company believes accomplishing this aspiration depends on, among other things, sufficient and substantial advances in technology, including the continuing progress of commercially viable technologies and low- or non-carbon-based energy sources; enabling policies and other actions by governing authorities, including those regarding subsidies, tax and other incentives as well as the granting of necessary permits; successful negotiations for carbon capture and storage and nature-based solutions with customers, suppliers, partners and governments; market conditions; and the availability and acceptability of cost-effective, verifiable carbon credits. 2028 Upstream Production GHG Intensity Targets These metrics include Scope 1 (direct emissions) and Scope 2 (indirect emissions associated with imported electricity and steam) and are net of emissions from exported electricity and steam. The 2028 GHG emissions intensity targets on an equity ownership basis include: • Oil production GHG intensity of 24 kilograms (kg) carbon dioxide equivalent per barrel of oil-equivalent (CO2e/ boe), • Gas production GHG intensity of 24 kg CO2e/boe, • Methane intensity of 2 kg CO2e/boe, and • Flaring GHG intensity of 3 kg CO2e/boe. The company also targets zero routine flaring by 2030 as outlined in the World Bank’s “Zero Routine Flaring by 2030” initiative. 2028 Portfolio Carbon Intensity Target The company also introduced a portfolio carbon intensity (PCI) metric, which is a measure of the carbon intensity across the full value chain of Chevron’s entire business. This metric encompasses the company’s upstream and downstream business and includes Scope 1 (direct emissions), Scope 2 (indirect emissions from imported electricity and steam), and certain Scope 3 (primarily emissions from use of sold products) emissions. The company’s PCI target is 71 grams (g) carbon dioxide equivalent (CO2e) per megajoule (MJ) by 2028. Planned Lower-Carbon Capital Spend through 2028 In 2021, the company guided to capital spend of approximately $10 billion through 2028 to advance its lower carbon ambitions, which includes approximately $2 billion to lower the carbon intensity of its oil and gas operations, and approximately $8 billion for lower carbon investments including in renewable fuels, hydrogen and carbon capture and offsets. Beyond 2028, the company anticipates capital spending will be necessary to progress the company’s 2050 upstream production Scope 1 and 2 net zero aspiration and building of its lower carbon business lines. Since 2021, the company has spent $7.7 billion in lower carbon investments, including $2.9 billion associated with the acquisition of REG in 2022. Income Taxes The effective tax rate for the company can change substantially during periods of significant earnings volatility. This is due to the mix effects that are impacted by both the absolute level of earnings or losses and whether they arise in higher or lower tax rate jurisdictions. As a result, a decline or increase in the effective income tax rate in one period may not be indicative of expected results in future periods. Additional information related to the company’s effective income tax rate is included in Note 17 Taxes to the Consolidated Financial Statements. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 27 Management’s Discussion and Analysis of Financial Condition and Results of Operations In December 2021, the Organization for Economic Co-operation and Development (OECD) issued model rules for a new 15 percent global minimum tax (Pillar Two), and various jurisdictions in which the company operates enacted or are in the process of enacting Pillar Two legislation. Certain aspects of the tax under the Pillar Two framework became effective in 2024 in some jurisdictions and will be effective in 2025 (or later) in others. Pillar Two did not have a material impact on the company’s results of operations in 2024. Although we do not currently expect that Pillar Two will have a material impact on our future results of operations, we are continuing to evaluate the impact of pending legislative adoption by individual countries. Supply Chain and Inflation Impacts The company is actively managing its contracting, procurement and supply chain activities to effectively manage costs and facilitate supply chain resiliency and continuity in support of the company’s operational goals. Third party costs for capital and operating expenses can be subject to external factors beyond the company’s control including, but not limited to: severe weather or civil unrest, delays in construction, global and local supply chain distribution issues, inflation, tariffs or other taxes imposed on goods or services, and market-based prices charged by the industry’s material and service providers. Chevron utilizes contracts with various pricing mechanisms, which may result in a lag before the company’s costs reflect changes in market trends. Trends in the costs of goods and services vary by spend category. The labor market remains tight, and suppliers are passing along wage rate increases for labor intensive operations. Chevron has applied inflation mitigation strategies in an effort to temper these cost increases, including fixed price and index-based contracts. Lead times for key capital equipment remain long and availability of offshore and specialized equipment is under pressure, with some experiencing upward pricing movements. In the United States, cost pressures for materials and standard onshore drilling and completion equipment continue to ease. Chevron has addressed equipment cost increases and long lead times by partnering with suppliers on demand planning, volume commitments, standardization and scope optimization. In February 2025, the U.S. announced the imposition of tariffs on imports from several U.S. trade partners and could announce additional tariffs in future periods. There is significant uncertainty as to the duration of these and any further tariffs, and the impacts these tariffs and any corresponding retaliatory tariffs will have on the company and its suppliers. The financial impacts of the tariffs are currently not expected to be material; however, the ultimate impact on the company’s results of operations and financial condition remains uncertain. Refer to the Cautionary Statement Relevant to Forward-Looking Information on page 24 and to Item 1A. Risk Factors on page 20 of the company’s Annual Report on Form 10-K for a discussion of some of the inherent risks that could materially impact the company’s results of operations or financial condition. Acquisition and Disposition of Assets The company continually evaluates opportunities to dispose of assets that are not expected to provide sufficient long-term value and to acquire assets or operations complementary to its asset base to help augment the company’s financial performance and value growth. The company is targeting $10-15 billion of asset sales over the five-year period ending in 2028. From 2024 through January 2025, the company has generated approximately $8 billion of asset sales proceeds. Asset dispositions and restructurings may result in significant gains or losses in future periods. In addition, some assets are divested along with their related liabilities, such as decommissioning obligations. In certain instances, such transferred obligations have returned and may continue to return to the company and result in losses that could be significant. For example, in fourth quarter 2023, the company recognized charges for decommissioning obligations from certain previously divested assets in the Gulf of America. In 2024, the company spent $235 million related to these obligations and anticipates spending an additional $200-300 million annually through 2033. To the extent the current owners of the company’s previously divested assets default on their decommissioning obligations, regulators may require that Chevron assume such obligations. The company could have additional significant obligations revert, primarily in the United States. The company is not currently aware of any such obligations that are reasonably possible to be material. Refer to Note 24. Other Contingencies and Commitments for additional information. In December 2024, the company sold its 20 percent non-operated interest in the Athabasca Oil Sands Project and 70 percent operated interest in the Duvernay shale in Alberta, Canada, to Canadian Natural Resources Limited for $6.5 billion before taxes, and expects to make tax payments totaling $1.5 billion in first quarter 2025. In 2024, these assets produced 86 thousand barrels of oil-equivalent per day and generated over $2.2 billion of sales and approximately $590 million of operational net income. As part of the sale, the buyer assumed decommissioning obligations for the transferred assets. In October 2023, the company announced that it had entered into a definitive merger agreement with Hess Corporation. Refer to Note 30. Agreement to Acquire Hess Corporation for additional information. Chevron Corporation 2024 Annual Report 28 Other Impacts The company closely monitors developments in the financial and credit markets, the level of worldwide economic activity, and the implications for the company of movements in prices for crude oil, natural gas and natural gas liquids (NGLs). Management takes these developments into account in the conduct of daily operations and for business planning. In fourth quarter 2024, the company announced plans to achieve $2-3 billion in structural cost reductions by the end of 2026. These cost savings will largely come from optimizing the portfolio, leveraging technology to enhance productivity, and changing how and where work is performed, including expanded use of global capability centers. In relation to these efforts, the company recognized a restructuring charge of $715 million after tax in fourth quarter 2024, with associated cash outflows anticipated over the next two years. The company continues to evaluate incremental cost reduction opportunities and could incur additional restructuring and reorganization charges in future periods. This will have an impact on the company’s pension and Other Post-Employment Benefit (OPEB) plans; however, the impact is not yet estimable and any impacts will be recognized in future periods. Earnings trends for the company’s major business areas are described as follows: Upstream Earnings for the upstream segment are closely aligned with industry prices for crude oil, natural gas and NGLs. These prices are subject to external factors over which the company has no control, including product demand connected with global economic conditions, industry production and inventory levels, technology advancements, production quotas or other actions imposed by OPEC+ countries, actions of regulators, weather-related damage and disruptions, competing fuel prices, natural and human causes beyond the company’s control, and regional supply interruptions or fears thereof that may be caused by military conflicts, civil unrest or political uncertainty. Any of these factors could also inhibit the company’s production capacity in an affected region. The company closely monitors developments in the countries in which it operates and holds investments and seeks to manage risks in operating its facilities and businesses. The longer-term trend in earnings for the upstream segment is also a function of other factors, including the company’s ability to efficiently find, acquire and produce crude oil, natural gas and NGLs, changes in fiscal terms of contracts, the pace of energy transition, and changes in tax, environmental and other applicable laws and regulations. In April 2024, Tengizchevroil LLP (TCO) achieved start-up of the Wellhead Pressure Management Project (WPMP) and at year-end 2024, all four pressure boost facility compressors are online and all metering stations have been converted to low pressure. In January 2025, TCO started oil production at its Future Growth Project, which is expected to contribute to higher free cash flow. Chevron has interests in Venezuelan assets operated by independent affiliates. Chevron has been conducting limited activities in Venezuela consistent with the authorization provided pursuant to licenses issued by the United States government. In fourth quarter 2022, Chevron received General License 41 from the United States government, enabling the company to resume activity in Venezuela subject to certain limitations, and the company continues such activities under this General License. The financial results for Chevron’s business in Venezuela are being recorded as non-equity investments since 2020, where income is only recognized when cash is received and production and reserves are not included in the company’s results. Crude oil liftings in Venezuela started in first quarter 2023, which have positively impacted the company’s results. The company’s independent affiliates have continued to maintain safe and reliable operations; however, future impact on results of operations and financial condition remain uncertain. Chevron maintains an equity interest in the Caspian Pipeline Consortium (CPC) which provides a primary export route for Tengiz field production in Kazakhstan. An adverse event or incident affecting CPC operations, which CPC has experienced from time to time, could have a negative impact on the Tengiz field and the company’s results of operations and financial position. The financial impacts of such risks, including presently imposed sanctions and the February 2025 drone attack on the CPC pumping station, remain uncertain. Other governments (including Russia) have imposed and may impose additional sanctions and other trade laws, restrictions and regulations that could lead to disruption in our ability to produce, transport and/or export crude in the region around Russia. Chevron holds a 39.7 percent interest in the Leviathan field and a 25 percent interest in the Tamar field in Israel. Despite the ongoing conflict between Israel and various regional adversaries, the company continues to maintain safe and reliable operations while meeting its contractual commitments. The company continues to monitor the ongoing conflict in the region and any future impacts on the company’s results of operations and financial condition remain uncertain. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 29 0.00 5.00 10.00 15.00 20.00 0 30 60 90 120 150 4Q 3Q 2Q 1Q 4Q 3Q 2Q 1Q 4Q 3Q 2Q 1Q 2022 2023 2024 Oil $/bbl HH $/mcf WTI Crude Oil, Brent Crude Oil and Henry Hub Natural Gas Spot Prices - Quarterly Average Brent WTI Henry Hub Chevron operates and holds interests in the Bibiyana, Jalalabad and Moulavi Bazar fields in Bangladesh. Recent political unrest in the country has not impacted the company’s operations to date; however, the future impacts, if any, on the company’s results of operations and financial condition remain uncertain. Commodity Prices The following chart shows the trend in benchmark prices for Brent crude oil, West Texas Intermediate (WTI) crude oil and U.S. Henry Hub natural gas. The Brent price averaged $81 per barrel for the full-year 2024, compared to $83 in 2023. As of mid-February 2025, the Brent price was $75 per barrel. The WTI price averaged $76 per barrel for the full-year 2024, compared to $78 in 2023. As of mid-February 2025, the WTI price was $71 per barrel. The majority of the company’s equity crude production is priced based on the Brent benchmark. The U.S. Henry Hub natural gas price averaged $2.25 per thousand cubic feet (MCF) for the full-year 2024, compared to $2.56 in 2023. As of mid- February 2025, the Henry Hub price was $4.42 per MCF. See page 37 for the company’s U.S. and international average realizations for each of the past three years. Management’s Discussion and Analysis of Financial Condition and Results of Operations Crude prices in 2024 were influenced by geopolitical conflict and OPEC+ supply restraint, which was offset by factors such as non-OPEC supply growth and slowing demand growth. In contrast to price movements in the global market for crude oil, prices for natural gas are also impacted by regional supply and demand and infrastructure conditions in local markets. In the United States, lower Henry Hub prices were driven by high storage levels, strong production, and delayed starts to liquefied natural gas (LNG) export projects. Outside the United States, prices for natural gas also depend on a wide range of supply, demand and regulatory circumstances. The company’s long-term contract prices for LNG are typically linked to crude oil prices. Most of the equity LNG offtake from the operated Australian LNG projects is committed under binding long-term contracts, with some sold in the Asian spot LNG market. Production The company’s worldwide net oil-equivalent production in 2024 was 3.3 million barrels per day, 7 percent higher than in 2023 primarily due to the full-year of legacy PDC Energy, Inc. (PDC) production and growth in the Permian Basin. About 20 percent of the company’s net oil-equivalent production in 2024 occurred in OPEC+ member countries of Equatorial Guinea, Kazakhstan, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait and the Republic of Congo. The company estimates its net oil-equivalent production in 2025 to increase six to eight percent over 2024, assuming a Brent crude oil price of $70 per barrel and excluding expected asset sales. This estimate is subject to many factors and uncertainties, including quotas or other actions that may be imposed by OPEC+; price effects on entitlement volumes; changes in fiscal terms or restrictions on the scope of company operations; delays in construction; reservoir performance; greater-than-expected declines in production from mature fields; start-up or ramp-up of projects; acquisition and divestment of assets; fluctuations in demand for crude oil and natural gas in various markets; weather conditions that may shut in production; civil unrest; changing geopolitics; delays in completion of maintenance turnarounds; storage constraints or economic conditions that could lead to shut-in production; or other disruptions to operations. The outlook for future Chevron Corporation 2024 Annual Report 30 production levels is also affected by the size and number of economic investment opportunities and the time lag between initial exploration and the beginning of production. Net crude oil production Thousands of barrels per day 1,560 22 23 24 0 500 1,000 1,500 2,000 Affiliates Europe Australia Asia Africa Other Americas United States Net natural gas liquids production Thousands of barrels per day 415 22 23 24 0 200 400 600 800 Affiliates Europe Australia Asia Africa Other Americas United States Net natural gas production Millions of cubic feet per day 8,178 22 23 24 0 3,000 6,000 9,000 12,000 Affiliates Europe Australia Asia Africa Other Americas United States Net proved reserves by geographic area Billions of BOE* 9.8 22 23 24 0.0 5.0 10.0 15.0 Affiliates Europe Australia Asia Africa Other Americas United States *barrels of oil-equivalent Net proved reserves by product Billions of BOE* 9.8 22 23 24 0.0 5.0 10.0 15.0 Natural gas Natural gas liquids Crude oil *barrels of oil-equivalent Proved Reserves Net proved reserves for consolidated companies and affiliated companies totaled 9.8 billion barrels of oil- equivalent at year-end 2024, a decrease from year-end 2023. The reserve replacement ratio in 2024 was negative 4 percent. The 5 and 10 year reserve replacement ratios were 72 percent and 88 percent, respectively. Refer to Table V for a tabulation of the company’s proved net oil and gas reserves by geographic area, at the beginning of 2022 and each year-end from 2022 through 2024, and an accompanying discussion of major changes to proved reserves by geographic area for the three-year period ending December 31, 2024. Refer to the “Results of Operations” section on pages 33 for additional discussion of the company’s upstream business. Downstream Earnings for the downstream segment are closely tied to margins on the refining, manufacturing and marketing of products that include gasoline, diesel, jet fuel, lubricants, fuel oil, fuel and lubricant additives, petrochemicals and renewable fuels. Industry margins are sometimes volatile and can be affected by the global and regional supply-and- demand balance for refined products and petrochemicals, and by changes in the price of crude oil, other refinery and petrochemical feedstocks, and natural gas. Industry margins can also be influenced by inventory levels, geopolitical events, costs of materials and services, refinery or chemical plant capacity utilization, maintenance programs, and disruptions at refineries or chemical plants resulting from unplanned outages due to severe weather, fires or other operational events. Other factors affecting profitability for downstream operations include the reliability and efficiency of the company’s refining, marketing and petrochemical assets, the effectiveness of its crude oil and product supply functions, and the volatility of tanker-charter rates for the company’s shipping operations, which are driven by the industry’s demand for crude oil and product tankers. Other factors beyond the company’s control include the general level of inflation and energy costs to operate the company’s refining, marketing and petrochemical assets, and changes in tax, environmental, and other applicable laws and regulations. The company’s most significant marketing areas are the West Coast and Gulf Coast of the United States and Asia Pacific. Chevron operates or has significant ownership interests in refineries in each of these areas. The company is also one of the largest renewable fuels producers in the United States. Refer to the “Results of Operations” section on page 34 for additional discussion of the company’s downstream operations. All Other consists of worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies. Management’s Discussion and Analysis of Financial Condition and Results of Operations Chevron Corporation 2024 Annual Report 31 Noteworthy Developments Key noteworthy developments and other events during 2024 and early 2025 included the following: Angola Added frontier exploration acreage positions in the deepwater lower Congo Basin. Angola Achieved first gas on the Sanha Lean Gas Connection project, securing incremental natural gas supply to the Angola Liquefied Natural Gas facility. Australia Announced asset exchange of North West Shelf Assets for Wheatstone Assets and Julimar/Brunello fields. Australia Received two offshore greenhouse gas assessment permits, covering an area of approximately 10,700 km2, to assess future carbon dioxide storage. Brazil Secured 15 exploration blocks in the South Santos and Pelotas Basins. Canada Sold the company’s interest in the Athabasca Oil Sands Project and Duvernay shale for $6.5 billion. Equatorial Guinea Signed agreements to acquire two exploration blocks offshore Bioko Island. Israel Reached final investment decision to add midstream infrastructure that is expected to increase production capacity at the Tamar gas field in Israel to 1.6 billion cubic feet per day. Kazakhstan Completed the Wellhead Pressure Management Project and, in January 2025, started production at the Future Growth Project, which is expected to ramp up total output to around one million barrels of oil equivalent per day at the company’s 50 percent-owned affiliate, Tengizchevroil LLP in Kazakhstan. Myanmar Withdrew from Chevron’s nonoperated working interests effective April 1, 2024. Namibia Signed agreements to acquire 80 percent working interest in Petroleum Exploration License 82 in the Walvis Basin. Nigeria Extended the Meji field offshore Nigeria with a near-field discovery and renewed the Agbami deep-water concession through 2044. Republic of Congo Sold the company’s 31.5 percent nonoperated working interest in the offshore Haute Mer permit area and its 15.75 percent interest in the Republic of Congo portion of Lianzi in January 2025. United States Reached final investment decision to build an oilseed processing plant in Louisiana through the company’s joint venture Bunge Chevron Ag Renewables LLC. United States Drilled onshore and offshore stratigraphic wells to delineate carbon dioxide storage potential through the company’s joint venture Bayou Bend CCS LLC. United States Launched a $500 million Future Energy Fund III focused on venture investments in technology-based solutions that have the potential to enable affordable, reliable and lower carbon energy. United States Progressed the company’s pending merger with Hess Corporation by securing Hess stockholder approval and clearing Federal Trade Commission antitrust review. United States Started production at the industry-first 20,000 pounds per square inch deepwater Anchor project, began water injection to boost production from the St. Malo and Tahiti fields, and in January 2025 started production from the Whale semi-submersible platform in the Gulf of America. United States Upgraded the Pasadena Refinery, which is expected to increase product flexibility and expand the processing capacity of lighter crude oil to 125,000 barrels per day. United States Completed projects and operational changes designed to abate over 700,000 tonnes of carbon dioxide- equivalent from the company’s operations. United States Announced plans to jointly develop scalable power solutions using natural gas-fired turbines with flexibility to integrate carbon capture and storage to support growing energy demand from U.S. data centers. Uruguay Entered an agreement to assume a 60 percent operated interest in Uruguay’s AREA OFF-1 offshore exploration block. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 32 Common Stock Dividends The 2024 annual dividend was $6.52 per share, making 2024 the 37th consecutive year that the company increased its annual per share dividend payout. In January 2025, the company’s Board of Directors increased its quarterly dividend by $0.08 per share, approximately five percent, to $1.71 per share payable in March 2025. Common Stock Repurchase Program The company repurchased $15.2 billion of its common stock in 2024 under its stock repurchase program. For more information on the common stock repurchase program, see Liquidity and Capital Resources. Results of Operations The following section presents the results of operations and variances on an after-tax basis for the company’s business segments – Upstream and Downstream – as well as for “All Other.” Earnings are also presented for the U.S. and international geographic areas of the Upstream and Downstream business segments. Refer to Note 14 Operating Segments and Geographic Data for a discussion of the company’s “reportable segments.” This section should also be read in conjunction with the discussion in Business Environment and Outlook. Refer to the Selected Operating Data for a three- year comparison of production volumes, refined product sales volumes and refinery inputs. A discussion of variances between 2023 and 2022 can be found in the “Results of Operations” section on pages 41 through 43 of the company’s 2023 Annual Report on Form 10-K filed with the SEC on February 26, 2024. Worldwide Upstream earnings Billions of Dollars $18.6 22 23 24 0.0 10.0 20.0 30.0 40.0 United States International Worldwide Downstream earnings Billions of dollars $1.7 22 23 24 0.0 10.0 20.0 United States International U.S. refined product sales Thousands of barrels per day 1,286 22 23 24 0 500 1,000 1,500 2,000 Other Fuel oil Diesel/Gas oil Jet fuel Gasoline International refined product sales* Thousands of barrels per day 1,495 22 23 24 0 500 1,000 1,500 2,000 Other Fuel oil Diesel/Gas oil Jet fuel Gasoline *includes equity share in affiliates U.S. Upstream Unit * 2024 2023 2022 Earnings $MM $ 7,602 $ 4,148 $ 12,621 Net Oil-Equivalent Production MBOED 1,599 1,349 1,181 Liquids Production MBD 1,152 997 888 Natural Gas Production MMCFD 2,684 2,112 1,758 Liquids Realization $/BBL $ 56.24 $ 59.19 $ 76.71 Natural Gas Realization $/MCF $ 1.04 $ 1.67 $ 5.55 * MBD — thousands of barrels per day; MMCFD — millions of cubic feet per day; BBL — Barrel; MCF — thousands of cubic feet; MBOED — thousands of barrels of oil- equivalent per day. U.S. upstream earnings increased by $3.5 billion primarily due to higher sales volumes of $2.2 billion, including from legacy PDC assets, and the absence of charges from decommissioning obligations for previously divested assets in the Gulf of America of $1.9 billion, partly offset by lower realizations of $790 million. Net oil-equivalent production was up 250,000 barrels per day, or 19 percent, primarily due to full-year of legacy PDC production and growth in the Permian Basin. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 33 International Upstream Unit2 2024 2023 2022 Earnings1 $MM $ 11,000 $ 13,290 $ 17,663 Net Oil-Equivalent Production MBOED 1,739 1,771 1,818 Liquids Production MBD 823 833 831 Natural Gas Production MMCFD 5,494 5,632 5,919 Liquids Realization $/BBL $ 71.38 $ 71.70 $ 90.71 Natural Gas Realization $/MCF $ 7.32 $ 7.69 $ 9.75 1 Includes foreign currency effects: $ 395 $ 376 $ 816 2 MBD — thousands of barrels per day; MMCFD — millions of cubic feet per day; BBL — Barrel; MCF — thousands of cubic feet; MBOED — thousands of barrels of oil- equivalent per day. International upstream earnings decreased by $2.3 billion primarily due to lower realizations of $770 million, higher operating expenses of $580 million, lower sales volumes of $570 million and absence of favorable one-time tax benefit in Nigeria of $560 million. Foreign currency effects had a favorable impact on earnings of $19 million between periods. Net oil-equivalent production was down 32,000 barrels per day, or 2 percent. The decrease was primarily due to downtime at TCO and Nigeria, and withdrawal from Myanmar, partly offset by entitlement effects. U.S. Downstream Unit * 2024 2023 2022 Earnings $MM $ 531 $ 3,904 $ 5,394 Refinery Crude Unit Inputs MBD 917 962 924 Refined Product Sales MBD 1,286 1,287 1,228 * MBD — thousands of barrels per day. U.S. downstream earnings decreased by $3.4 billion primarily due to lower margins on refined product sales of $2.6 billion and higher operating expenses of $810 million. Refinery crude unit inputs were down 45,000 barrels per day, or 5 percent, primarily due to the upgrade of the Pasadena, Texas refinery that was completed during the fourth quarter 2024 and downtime at the Pascagoula, Mississippi refinery. Refined product sales were down 1,000 barrels per day. International Downstream Unit 2 2024 2023 2022 Earnings 1 $MM $ 1,196 $ 2,233 $ 2,761 Refinery Crude Unit Inputs MBD 646 636 652 Refined Product Sales MBD 1,495 1,445 1,386 1 Includes foreign currency effects: $ 126 $ (12) $ 235 2 MBD — thousands of barrels per day. International downstream earnings decreased by $1.0 billion primarily due to lower margins on refined product sales of $880 million and impairments of $190 million. Foreign currency effects had a favorable impact on earnings of $138 million between periods. Refinery crude unit inputs were up 10,000 barrels per day, or 2 percent. Refined product sales were up 50,000 barrels per day, or 3 percent, primarily due to increased trading volumes. All Other Unit 2024 2023 2022 Net charges* $MM $ (2,668) $ (2,206) $ (2,974) *Includes foreign currency effects: $ (1) $ (588) $ (382) All Other consists of worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology companies. Net charges increased by $462 million primarily due to higher employee benefit costs, severance charges, lower interest income and higher interest expense, partially offset by a favorable swing of $587 million in foreign currency effects. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 34 Consolidated Statement of Income Comparative amounts for certain income statement categories are shown below. A discussion of variances between 2023 and 2022 can be found in the “Consolidated Statement of Income” section on pages 43 and 44 of the company’s 2023 Annual Report on Form 10-K. Millions of dollars 2024 2023 2022 Sales and other operating revenues $ 193,414 $ 196,913 $ 235,717 Sales and other operating revenues decreased in 2024 mainly due to lower commodity prices, partially offset by higher crude oil, natural gas and refined product sales volumes. Millions of dollars 2024 2023 2022 Income (loss) from equity affiliates $ 4,596 $ 5,131 $ 8,585 Income from equity affiliates decreased in 2024 mainly due to lower downstream-related earnings from GS Caltex in South Korea and lower upstream-related earnings from Tengizchevroil in Kazakhstan, partially offset by an absence of certain U.S. upstream equity affiliate impairments and higher downstream-related earnings from Chevron Phillips Chemical Company LLC (CPChem). Refer to Note 15 Investments and Advances for a discussion of Chevron’s investments in affiliated companies. Millions of dollars 2024 2023 2022 Other income (loss) $ 4,782 $ (1,095) $ 1,950 Other income increased in 2024 mainly due to the absence of charges related to decommissioning obligations from previously divested oil and gas production assets in the Gulf of America, before tax gains on asset sales in Canada, a favorable swing in foreign currency effects and higher dividend income. Millions of dollars 2024 2023 2022 Purchased crude oil and products $ 119,206 $ 119,196 $ 145,416 Crude oil and product purchases remained fairly flat in 2024 as lower crude and refined product prices were partially offset by higher crude oil and refined product volumes. Millions of dollars 2024 2023 2022 Operating, selling, general and administrative expenses $ 32,298 $ 29,028 $ 29,026 Operating, selling, general and administrative expenses increased compared to last year mainly due to higher employee- related expenses as a result of higher severance and employee benefit costs and higher downstream-related shutdown expenses. Millions of dollars 2024 2023 2022 Exploration expense $ 995 $ 914 $ 974 Exploration expenses in 2024 were higher primarily due to higher geological and geophysical engineering costs. Millions of dollars 2024 2023 2022 Depreciation, depletion and amortization $ 17,282 $ 17,326 $ 16,319 Depreciation, depletion and amortization expenses decreased slightly in 2024 primarily due to lower impairment charges partially offset by higher production and higher rates. Millions of dollars 2024 2023 2022 Taxes other than on income $ 4,716 $ 4,220 $ 4,032 Taxes other than on income increased in 2024 primarily due to higher excise and property taxes. Millions of dollars 2024 2023 2022 Interest and debt expense $ 594 $ 469 $ 516 Interest and debt expenses increased in 2024 mainly due to higher debt balances. Millions of dollars 2024 2023 2022 Other components of net periodic benefit costs $ 195 $ 212 $ 295 Other components of net periodic benefit costs decreased in 2024 primarily due to lower pension settlement costs. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 35 Millions of dollars 2024 2023 2022 Income tax expense (benefit) $ 9,757 $ 8,173 $ 14,066 The increase in income tax expense in 2024 of $1.6 billion was primarily due to the tax impacts of the asset sales in Canada, partially offset by the decrease in total income before tax for the company of $2.1 billion. The decrease in income before taxes for the company was primarily the result of lower downstream margins, lower upstream realizations, higher operating expenses, in part due to severance charges, partially offset by the absence of charges from decommissioning obligations for previously divested assets, higher sales volumes and favorable foreign exchange impacts. U.S. income before tax decreased from $8.6 billion in 2023 to $8.1 billion in 2024. This $0.5 billion decrease in income was primarily driven by lower downstream margins, higher operating expenses, in part due to severance charges, and lower upstream realizations, partially offset by the absence of charges related to decommissioning obligations for previously divested assets and higher sales volumes. The increase of $0.1 billion in U.S. income tax expense between year-over-year periods, from $1.8 billion in 2023 to $1.9 billion in 2024, was primarily driven by current period unfavorable tax items. International income before tax decreased from $21.0 billion in 2023 to $19.5 billion in 2024. This $1.6 billion decrease in income was primarily driven by lower downstream margins, lower upstream realizations, higher operating expenses and lower sales volumes, partially offset by favorable foreign exchange impacts. The increase of $1.5 billion in international income tax expense between year-over-year periods, from $6.4 billion in 2023 to $7.9 billion in 2024, was primarily driven by the tax impacts of the asset sales in Canada, partially offset by the decrease in income before tax. Refer also to the discussion of the effective income tax rate in Note 17 Taxes. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 36 Selected Operating Data1,2 Unit 2024 2023 2022 U.S. Upstream Net Crude Oil and Natural Gas Liquids (NGLs) Production MBD 1,152 997 888 Net Natural Gas Production3 MMCFD 2,684 2,112 1,758 Net Oil-Equivalent Production MBOED 1,599 1,349 1,181 Sales of Natural Gas4 MMCFD 5,172 4,637 4,354 Sales of Natural Gas Liquids MBD 490 354 276 Revenues from Net Production Crude $/BBL $ 73.47 $ 75.04 $ 92.41 NGLs $/BBL $ 19.88 $ 20.04 $ 33.80 Liquids (weighted average of Crude and NGLs) $/BBL $ 56.24 $ 59.19 $ 76.71 Natural Gas $/MCF $ 1.04 $ 1.67 $ 5.55 International Upstream Net Crude Oil and NGLs Production5 MBD 823 833 831 Net Natural Gas Production3 MMCFD 5,494 5,632 5,919 Net Oil-Equivalent Production5 MBOED 1,739 1,771 1,818 Sales of Natural Gas MMCFD 5,678 6,025 5,786 Sales of Natural Gas Liquids MBD 132 94 107 Revenues from Liftings Crude $/BBL $ 73.72 $ 74.29 $ 93.73 NGLs $/BBL $ 26.49 $ 24.01 $ 37.56 Liquids (weighted average of Crude and NGLs) $/BBL $ 71.38 $ 71.70 $ 90.71 Natural Gas $/MCF $ 7.32 $ 7.69 $ 9.75 Worldwide Upstream Net Oil-Equivalent Production5 United States MBOED 1,599 1,349 1,181 International MBOED 1,739 1,771 1,818 Total MBOED 3,338 3,120 2,999 U.S. Downstream Gasoline Sales6 MBD 667 642 639 Other Refined Product Sales MBD 619 645 589 Total Refined Product Sales MBD 1,286 1,287 1,228 Sales of Natural Gas4 MMCFD 28 32 24 Sales of Natural Gas Liquids MBD 21 22 27 Refinery Crude Unit Inputs8 MBD 917 962 924 International Downstream Gasoline Sales6 MBD 382 353 336 Other Refined Product Sales MBD 1,113 1,092 1,050 Total Refined Product Sales7 MBD 1,495 1,445 1,386 Sales of Natural Gas4 MMCFD — 1 3 Sales of Natural Gas Liquids MBD 136 153 127 Refinery Crude Unit Inputs8 MBD 646 636 652 1 Includes company share of equity affiliates. 2 MBD – thousands of barrels per day; MMCFD – millions of cubic feet per day; MBOED – thousands of barrels of oil-equivalents per day; Bbl – barrel; MCF – thousands of cubic feet. Oil-equivalent gas (OEG) conversion ratio is 6,000 cubic feet of natural gas = 1 barrel of crude oil; MBOED - thousands of barrels of oil-equivalent per day. 3 Includes natural gas consumed in operations: United States MMCFD 60 64 53 International MMCFD 549 532 517 4 Downstream sales of Natural Gas separately identified from Upstream. 5 Includes net production of synthetic oil: Canada MBD 46 51 45 6 Includes branded and unbranded gasoline. 7 Includes sales of affiliates: MBD 386 389 389 8 Includes crude oil and other inputs. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 37 Liquidity and Capital Resources Sources and Uses of Cash The strength of the company’s balance sheet enables it to fund any timing differences throughout the year between cash inflows and outflows. Cash, Cash Equivalents and Marketable Securities Total balances were $6.8 billion and $8.2 billion at December 31, 2024 and 2023, respectively. The company holds its cash with a diverse group of major financial institutions and has processes and safeguards in place designed to manage its cash balances and mitigate the risk of loss. Cash provided by operating activities in 2024 was $31.5 billion, compared to $35.6 billion in 2023, primarily due to lower earnings and higher payments related to asset retirement obligations. Cash provided by operating activities was net of contributions to employee pension plans of approximately $844 million in 2024 and $1.1 billion in 2023. Capital expenditures totaled $16.4 billion in 2024 compared to $15.8 billion in 2023. Proceeds and deposits related to asset sales and return of investments totaled $7.7 billion in 2024 compared to $669 million in 2023 primarily related to proceeds from asset sales in Canada. Cash flow from financing activities includes proceeds from shares issued for stock options of $330 million in 2024, compared with $261 million in 2023. Restricted cash of $1.5 billion and $1.1 billion at December 31, 2024 and 2023, respectively, was held in cash and short- term marketable securities and recorded as “Deferred charges and other assets” and “Prepaid expenses and other current assets” on the Consolidated Balance Sheet. These amounts are generally associated with upstream decommissioning activities, tax payments and funds held in escrow for tax-deferred exchanges. The increase of restricted cash in 2024 is mainly due to increase in funds for tax-deferred exchanges. Dividends Dividends paid to common stockholders were $11.8 billion in 2024 and $11.3 billion in 2023. Debt and Finance Lease Liabilities Total debt and finance lease liabilities were $24.5 billion at December 31, 2024, up from $20.8 billion at year-end 2023 as the company issued commercial paper and tax-exempt bonds and retired public bonds. The $3.7 billion increase in total debt and finance lease liabilities during 2024 was primarily due to the issuance of commercial paper. The company’s debt and finance lease liabilities due within one year, consisting primarily of the current portion of long-term debt and redeemable long-term obligations, totaled $12.7 billion at December 31, 2024, compared with $5.1 billion at year-end 2023. Of these amounts, $8.3 billion and $4.5 billion were reclassified to long-term debt at the end of 2024 and 2023, respectively, since settlement of these obligations was not expected to require the use of working capital within one year, as the company had the intent and the ability, as evidenced by committed credit facilities, to continue refinancing them. The company has access to a commercial paper program as a financing source for working capital or other short-term needs. The company had $5.4 billion of commercial paper outstanding as of December 31, 2024, and there was no commercial paper outstanding at December 31, 2023. The company has an automatic shelf registration statement that expires in November 2027 for an unspecified amount of nonconvertible debt securities issued by Chevron Corporation or Chevron U.S.A. Inc. (CUSA). Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 38 The major debt rating agencies routinely evaluate the company’s debt, and the company’s cost of borrowing can increase or decrease depending on these debt ratings. The company has outstanding public bonds issued by Chevron Corporation, CUSA, Noble Energy, Inc. (Noble), and Texaco Capital Inc. Most of these securities are the obligations of, or guaranteed by, Chevron Corporation and are rated AA- by Standard and Poor’s Corporation and Aa2 by Moody’s Investors Service. The company’s U.S. commercial paper is rated A-1+ by Standard and Poor’s and P-1 by Moody’s. All of these ratings denote high-quality, investment-grade securities. The company’s future debt level is dependent primarily on results of operations, cash that may be generated from asset dispositions, the capital program, acquisitions, investments, lending commitments to affiliates and cash returned to shareholders. Based on its high-quality debt ratings, the company believes that it has substantial borrowing capacity to meet unanticipated cash requirements. During extended periods of low prices for crude oil and natural gas and narrow margins for refined products and commodity chemicals, the company has the ability to modify its capital spending plans and discontinue or curtail the stock repurchase program. This provides the flexibility to continue paying the common stock dividend and remain committed to retaining the company’s high-quality debt ratings. Committed Credit Facilities Information related to committed credit facilities is included in Note 19 Short-Term Debt. Summarized Financial Information for Guarantee of Securities of Subsidiaries CUSA issued bonds that are fully and unconditionally guaranteed on an unsecured basis by Chevron Corporation (together, the “Obligor Group”). The tables below contain summary financial information for Chevron Corporation, as Guarantor, excluding its consolidated subsidiaries, and CUSA, as the issuer, excluding its consolidated subsidiaries. The summary financial information of the Obligor Group is presented on a combined basis, and transactions between the combined entities have been eliminated. Financial information for non-guarantor entities has been excluded. In the year ended December 31, 2024, the Obligor Group recognized an increase in “Net income (loss)” and reduction in “Current liability - related party” and “Total net equity (deficit)” following the resolution of outstanding balances with subsidiaries outside of the Obligor Group. 2024 2023 (Millions of dollars) (unaudited) Sales and other operating revenues $ 96,035 $ 100,405 Sales and other operating revenues - related party 43,562 44,553 Total costs and other deductions 102,116 102,773 Total costs and other deductions - related party 35,454 35,781 Net income (loss) $ 73,119 $ 12,190 At December 31, 22 23 24 0.0 10.0 20.0 30.0 40.0 22 23 24 0.0 3.0 6.0 9.0 12.0 18.0 22 23 24 0.0 3.0 6.0 9.0 12.0 18.0 22 23 24 0.0 10.0 20.0 30.0 22 23 24 0.0 10.0 20.0 Chevron Corporation 2024 Annual Report 39 At December 31, 2024 2023 (Millions of dollars) (unaudited) Current assets $ 16,918 $ 19,006 Current assets - related party 2,626 18,375 Other assets 57,921 54,558 Current liabilities 30,563 20,512 Current liabilities - related party 22,997 132,474 Other liabilities 23,719 28,849 Total net equity (deficit) $ 186 $ (89,896) Common Stock Repurchase Program On January 25, 2023, the Board of Directors authorized the repurchase of the company’s shares of common stock in an aggregate amount of $75 billion (the “2023 Program”). The 2023 Program took effect on April 1, 2023, and does not have a fixed expiration date. During 2024, the company purchased a total of 100.4 million shares for $15.2 billion and paid an additional $145 million in excise taxes related to 2023 buybacks. As of December 31, 2024, the company had purchased a total of 170.9 million shares for $26.4 billion excluding excise taxes, resulting in $48.6 billion remaining under the 2023 Program. Repurchases of shares of the company’s common stock may be made from time to time in the open market, by block purchases, in privately negotiated transactions or in such other manner as determined by the company. The timing of the repurchases and the actual amount repurchased will depend on a variety of factors, including the market price of the company’s shares, general market and economic conditions, and other factors. The stock repurchase program does not obligate the company to acquire any particular amount of common stock and may be suspended or discontinued at any time. Capital Expenditures Capital expenditures (Capex) primarily includes additions to fixed asset or investment accounts for the company’s consolidated subsidiaries and is disclosed in the Consolidated Statement of Cash Flows. Capex by business segment for 2024, 2023 and 2022 is as follows: Year ended December 31 Capex 2024 2023 2022 Millions of dollars U.S. Int’l. Total U.S. Int’l. Total U.S. Int’l. Total Upstream $ 9,481 $ 4,850 $ 14,331 $ 9,842 $ 3,836 $ 13,678 $ 6,847 $ 2,718 $ 9,565 Downstream 1,443 251 1,694 1,536 237 1,773 1,699 375 2,074 All Other 406 17 423 351 27 378 310 25 335 Capex $ 11,330 $ 5,118 $ 16,448 $ 11,729 $ 4,100 $ 15,829 $ 8,856 $ 3,118 $ 11,974 Capex for 2024 was $16.4 billion, 4 percent higher than 2023 due to higher investments in the upstream. The company estimates that 2025 Capex will range from $14.5 to $15.5 billion. Upstream Capex is projected at $13 billion, with two-thirds in the United States. This includes $4.5 to $5 billion for Permian Basin development, with the remaining split between the DJ Basin and the Gulf of America. In international Upstream, about $1 billion is allocated to Australia. Downstream Capex is estimated at $1.2 billion, with two-thirds in the United States. About $1.5 billion of total Capex, which is included within upstream and downstream budgets, is dedicated to lowering the carbon intensity of our operations and growing new energies businesses. Corporate and other Capex is projected to be about $0.7 billion. Affiliate Capital Expenditures Equity affiliate capital expenditures (Affiliate Capex) primarily includes additions to fixed asset and investment accounts in the equity affiliate companies’ financial statements and does not require cash outlays by the company. Affiliate Capex by business segment for 2024, 2023 and 2022 is as follows: Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 40 Year ended December 31 Affiliate Capex 2024 2023 2022 Millions of dollars U.S. Int’l. Total U.S. Int’l. Total U.S. Int’l. Total Upstream $ — $ 1,451 $ 1,451 $ — $ 2,310 $ 2,310 $ — $ 2,406 $ 2,406 Downstream 802 196 998 983 241 1,224 768 192 960 All Other — — — — — — — — — Affiliate Capex $ 802 $ 1,647 $ 2,449 $ 983 $ 2,551 $ 3,534 $ 768 $ 2,598 $ 3,366 Affiliate Capex for 2024 was $2.4 billion, 31 percent lower than 2023 mainly due to lower spend at Tengizchevroil’s Wellhead Pressure Management Project (WPMP) and Future Growth Project (FGP). Affiliate Capex is expected to range between $1.7 to $2.0 billion in 2025. Less than half of Affiliate Capex is for Tengizchevroil, while the remaining spend primarily supports CPChem’s two major integrated polymer projects. The company monitors market conditions and can adjust future capital outlays should conditions change. Noncontrolling Interests The company had noncontrolling interests of $839 million at December 31, 2024, and $972 million at December 31, 2023. Distributions to noncontrolling interests net of contributions totaled $195 million and $40 million in 2024 and 2023, respectively. Pension Obligations Information related to pension plan contributions is included in Note 23 Employee Benefit Plans, under the heading “Cash Contributions and Benefit Payments.” Contractual Obligations Information related to the company’s significant contractual obligations is included in Note 19 Short-Term Debt, in Note 20 Long-Term Debt and in Note 5 Lease Commitments. The aggregate amount of interest due on these obligations, excluding leases, is: 2025 – $747; 2026 – $666; 2027 – $605; 2028 – $566; 2029 – $562; after 2029 – $4,355. Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements Information related to these off-balance sheet matters is included in Note 24 Other Contingencies and Commitments, under the heading “Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements.” Direct Guarantees Information related to guarantees is included in Note 24 Other Contingencies and Commitments under the heading “Guarantees.” Indemnifications Information related to indemnifications is included in Note 24 Other Contingencies and Commitments under the heading “Indemnifications.” Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 41 Financial Ratios and Metrics The following represent several metrics the company believes are useful measures to monitor the financial health of the company and its performance over time: Current Ratio Current assets divided by current liabilities, which indicates the company’s ability to repay its short-term liabilities with short-term assets. The current ratio in all periods is adversely affected by the fact that Chevron’s inventories are valued on a last-in, first-out basis. At year-end 2024, the book value of inventory was lower than replacement costs, based on average acquisition costs during the year, by approximately $6.0 billion. At December 31 Millions of dollars 2024 2023 2022 Current assets $ 40,911 $ 41,128 $ 50,343 Current liabilities 38,558 32,258 34,208 Current Ratio 1.1 1.3 1.5 Interest Coverage Ratio Income before income tax expense, plus interest and debt expense and amortization of capitalized interest, less net income attributable to noncontrolling interests, divided by before-tax interest costs. This ratio indicates the company’s ability to pay interest on outstanding debt. Year ended December 31 Millions of dollars 2024 2023 2022 Income (Loss) Before Income Tax Expense $ 27,506 $ 29,584 $ 49,674 Plus: Interest and debt expense 594 469 516 Plus: Before-tax amortization of capitalized interest 214 223 199 Less: Net income attributable to noncontrolling interests 88 42 143 Subtotal for calculation 28,226 30,234 50,246 Total financing interest and debt costs $ 773 $ 617 $ 630 Interest Coverage Ratio 36.5 49.0 79.8 Free Cash Flow The cash provided by operating activities less capital expenditures, which represents the cash available to creditors and investors after investing in the business. Year ended December 31 Millions of dollars 2024 2023 2022 Net cash provided by operating activities $ 31,492 $ 35,609 $ 49,602 Less: Capital expenditures 16,448 15,829 11,974 Free Cash Flow $ 15,044 $ 19,780 $ 37,628 Debt Ratio Total debt as a percentage of total debt plus Chevron Corporation Stockholders’ Equity, which indicates the company’s leverage. At December 31 Millions of dollars 2024 2023 2022 Short-term debt $ 4,406 $ 529 $ 1,964 Long-term debt 20,135 20,307 21,375 Total debt 24,541 20,836 23,339 Total Chevron Corporation Stockholders’ Equity 152,318 160,957 159,282 Total debt plus total Chevron Corporation Stockholders’ Equity $ 176,859 $ 181,793 $ 182,621 Debt Ratio 13.9 % 11.5 % 12.8 % Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 42 Net Debt Ratio Total debt less cash and cash equivalents, time deposits and marketable securities as a percentage of total debt less cash and cash equivalents, time deposits and marketable securities, plus Chevron Corporation Stockholders’ Equity, which indicates the company’s leverage, net of its cash balances. At December 31 Millions of dollars 2024 2023 2022 Short-term debt $ 4,406 $ 529 $ 1,964 Long-term debt 20,135 20,307 21,375 Total Debt 24,541 20,836 23,339 Less: Cash and cash equivalents 6,781 8,178 17,678 Less: Time deposits 4 — — Less: Marketable securities — 45 223 Total adjusted debt 17,756 12,613 5,438 Total Chevron Corporation Stockholders’ Equity 152,318 160,957 159,282 Total adjusted debt plus total Chevron Corporation Stockholders’ Equity $ 170,074 $ 173,570 $ 164,720 Net Debt Ratio 10.4 % 7.3 % 3.3 % Capital Employed The sum of Chevron Corporation Stockholders’ Equity, total debt and noncontrolling interests, which represents the net investment in the business. At December 31 Millions of dollars 2024 2023 2022 Chevron Corporation Stockholders’ Equity $ 152,318 $ 160,957 $ 159,282 Plus: Short-term debt 4,406 529 1,964 Plus: Long-term debt 20,135 20,307 21,375 Plus: Noncontrolling interest 839 972 960 Capital Employed at December 31 $ 177,698 $ 182,765 $ 183,581 Return on Average Capital Employed (ROCE) Net income attributable to Chevron (adjusted for after-tax interest expense and noncontrolling interest) divided by average capital employed. Average capital employed is computed by averaging the sum of capital employed at the beginning and end of the year. ROCE is a ratio intended to measure annual earnings as a percentage of historical investments in the business. Year ended December 31 Millions of dollars 2024 2023 2022 Net income attributable to Chevron $ 17,661 $ 21,369 $ 35,465 Plus: After-tax interest and debt expense 539 432 476 Plus: Noncontrolling interest 88 42 143 Net income after adjustments 18,288 21,843 36,084 Average capital employed $ 180,232 $ 183,173 $ 177,445 Return on Average Capital Employed 10.1 % 11.9 % 20.3 % Return on Stockholders’ Equity (ROSE) Net income attributable to Chevron divided by average Chevron Corporation Stockholders’ Equity. Average stockholders’ equity is computed by averaging the sum of stockholders’ equity at the beginning and end of the year. ROSE is a ratio intended to measure earnings as a percentage of shareholder investments. Year ended December 31 Millions of dollars 2024 2023 2022 Net income attributable to Chevron $ 17,661 $ 21,369 $ 35,465 Chevron Corporation Stockholders’ Equity at December 31 152,318 160,957 159,282 Average Chevron Corporation Stockholders’ Equity 156,638 160,120 149,175 Return on Average Stockholders’ Equity 11.3 % 13.3 % 23.8 % Financial and Derivative Instrument Market Risk The market risk associated with the company’s portfolio of financial and derivative instruments is discussed below. The estimates of financial exposure to market risk do not represent the company’s projection of future market changes. The actual impact of future market changes could differ materially due to factors discussed elsewhere in this report, including those set forth under the heading Item 1A. Risk Factors on Form 10-K. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 43 Derivative Commodity Instruments Chevron is exposed to market risks related to the price volatility of crude oil, refined products, NGLs, natural gas, liquefied natural gas and refinery feedstocks. The company uses derivative commodity instruments to manage these exposures on a portion of its activity, including firm commitments and anticipated transactions for the purchase, sale and storage of crude oil, refined products, NGLs, natural gas, liquefied natural gas and feedstock for company refineries. The company also uses derivative commodity instruments for limited trading purposes. The results of these activities were not material to the company’s financial position, results of operations or cash flows in 2024. The company’s market exposure positions are monitored on a daily basis by an internal Risk Control group in accordance with the company’s risk management policies. The company’s risk management practices and its compliance with policies are reviewed by the Audit Committee of the company’s Board of Directors. Derivatives beyond those designated as normal purchase and normal sale contracts are recorded at fair value on the Consolidated Balance Sheet with resulting gains and losses reflected in income. Fair values are derived principally from published market quotes and other independent third-party quotes. The change in fair value of Chevron’s derivative commodity instruments in 2024 was not material to the company’s results of operations. The company uses the Monte Carlo simulation method as its Value-at-Risk (VaR) model to estimate the maximum potential loss in fair value, at the 95 percent confidence level with a one-day holding period, from the effect of adverse changes in market conditions on derivative commodity instruments held or issued. Based on these inputs, the VaR for the company’s primary risk exposures in the area of derivative commodity instruments at December 31, 2024 and 2023 was not material to the company’s cash flows or results of operations. Foreign Currency The company may enter into foreign currency derivative contracts to manage some of its foreign currency exposures. These exposures include revenue and anticipated purchase transactions, including foreign currency capital expenditures and lease commitments. The foreign currency derivative contracts, if any, are recorded at fair value on the balance sheet with resulting gains and losses reflected in income. There were no open foreign currency derivative contracts at December 31, 2024. Interest Rates The company may enter into interest rate swaps from time to time as part of its overall strategy to manage the interest rate risk on its debt. Interest rate swaps, if any, are recorded at fair value on the balance sheet with resulting gains and losses reflected in income. At year-end 2024, the company had no interest rate swaps. Transactions With Related Parties Chevron enters into a number of business arrangements with related parties, principally its equity affiliates. These arrangements include long-term supply or offtake agreements and long-term purchase agreements. Refer to “Other Information” in Note 15 Investments and Advances for further discussion. Management believes these agreements have been negotiated on terms consistent with those that would have been negotiated with an unrelated party. Litigation and Other Contingencies Climate Change Information related to climate change-related matters is included in Note 16 Litigation under the heading “Climate Change.” Louisiana Information related to Louisiana coastal matters is included in Note 16 Litigation under the heading “Louisiana.” Environmental The following table displays the annual changes to the company’s before-tax environmental remediation reserves, including those for U.S. federal Superfund sites and analogous sites under state laws. Millions of dollars 2024 2023 2022 Balance at January 1 $ 936 $ 868 $ 960 Net additions 264 327 182 Expenditures (255) (259) (274) Balance at December 31 $ 945 $ 936 $ 868 The company records asset retirement obligations when there is a legal obligation associated with the retirement of long- lived assets and the liability can be reasonably estimated. These asset retirement obligations include costs related to environmental issues. The liability balance of approximately $12.7 billion for asset retirement obligations at year-end 2024 is related primarily to upstream properties. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 44 For the company’s other ongoing operating assets, such as refineries and chemicals facilities, no provisions are made for exit or cleanup costs that may be required when such assets reach the end of their useful lives unless a decision to sell or otherwise decommission the facility has been made, as the indeterminate settlement dates for the asset retirements prevent estimation of the fair value of the asset retirement obligation. The company records decommissioning obligations for previously divested assets when it is probable that the decommissioning obligations would revert to the Company and costs can be reasonably estimated. At the end of 2024, the liability balance was $2.5 billion. Refer to Note 24 Other Contingencies and Commitments for additional discussion of decommissioning obligations for previously divested assets. Refer to the discussion below for additional information on environmental matters and their impact on Chevron, and on the company’s 2024 environmental expenditures. Refer to Note 24 Other Contingencies and Commitments for additional discussion of environmental remediation provisions. Refer also to Note 25 Asset Retirement Obligations for additional discussion of the company’s asset retirement obligations. Suspended Wells Information related to suspended wells is included in Note 21 Accounting for Suspended Exploratory Wells. Income Taxes Information related to income tax contingencies is included in Note 17 Taxes and in Note 24 Other Contingencies and Commitments under the heading “Income Taxes.” Other Contingencies Information related to other contingencies is included in Note 24 Other Contingencies and Commitments under the heading “Other Contingencies.” Environmental Matters The company is subject to various international and U.S. federal, state and local environmental, health and safety laws, regulations and market-based programs. These laws, regulations and programs continue to evolve and are expected to increase in both number and complexity over time and govern not only the manner in which the company conducts its operations, but also the products it sells. Consideration of environmental issues and the responses to those issues through international agreements and national, regional or state legislation or regulations are integrated into the company’s strategy and planning, capital investment reviews and risk management tools and processes, where applicable. They are also factored into the company’s long-range supply, demand and energy price forecasts. These forecasts reflect long-range effects from electric vehicle and renewable fuel penetration, energy efficiency standards, climate-related policy actions, and demand response to oil and natural gas prices. In addition, legislation and regulations intended to address hydraulic fracturing also continue to evolve in many jurisdictions where we operate. Refer to Item 1A. Risk Factors of the company’s Annual Report on Form 10-K for a discussion of some of the inherent risks of increasingly restrictive environmental and other regulation that could materially impact the company’s results of operations or financial condition. Refer to Business Environment and Outlook on pages 25 through 27 for a discussion of legislative and regulatory efforts to address climate change. Most of the costs of complying with existing laws and regulations pertaining to company operations and products are embedded in the normal costs of doing business. However, it is not possible to predict with certainty the amount of additional investments in new or existing technology or facilities or the amounts of increased operating costs to be incurred in the future to prevent, control, reduce or eliminate releases of hazardous materials or other pollutants into the environment; remediate and restore areas damaged by prior releases of hazardous materials; or comply with new environmental laws or regulations. Although these costs may be significant to the results of operations in any single period, the company does not presently expect them to have a material adverse effect on the company’s liquidity or financial position. Accidental leaks and spills requiring cleanup may occur in the ordinary course of business. The company may incur expenses for corrective actions at various owned and previously owned facilities and at third-party-owned waste disposal sites used by the company. An obligation may arise when operations are closed or sold or at non-Chevron sites where company products have been handled or disposed of. Most of the expenditures to fulfill these obligations relate to facilities and sites where past operations followed practices and procedures that were considered acceptable at the time but now require investigative or remedial work or both to meet current standards. Using definitions and guidelines established by the American Petroleum Institute, Chevron estimated its worldwide environmental spending in 2024 at approximately $2.5 billion for its consolidated companies. Included in these expenditures were approximately $0.6 billion of environmental capital expenditures and $1.9 billion of costs associated Management’s Discussion and Analysis of Financial Condition and Results of Operations Chevron Corporation 2024 Annual Report 45 with the prevention, control, abatement or elimination of hazardous substances and pollutants from operating, closed or divested sites, and the decommissioning and restoration of sites. For 2025, total worldwide environmental capital expenditures are estimated at $0.6 billion. These capital costs are in addition to the ongoing costs of complying with environmental regulations and the costs to remediate previously contaminated sites. Critical Accounting Estimates and Assumptions Management makes many estimates and assumptions in the application of accounting principles generally accepted in the United States of America (GAAP) that may have a material impact on the company’s consolidated financial statements and related disclosures and on the comparability of such information over different reporting periods. Such estimates and assumptions affect reported amounts of assets, liabilities, revenues and expenses, as well as disclosures of contingent assets and liabilities. Estimates and assumptions are based on management’s experience and other information available prior to the issuance of the financial statements. Materially different results can occur as circumstances change and additional information becomes known. The discussion in this section of “critical” accounting estimates and assumptions is according to the disclosure guidelines of the SEC, wherein: 1. the nature of the estimates and assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters, or the susceptibility of such matters to change; and 2. the impact of the estimates and assumptions on the company’s financial condition or operating performance is material. The development and selection of accounting estimates and assumptions, including those deemed “critical,” and the associated disclosures in this discussion have been discussed with the Audit Committee of the Board of Directors. The areas of accounting and the associated “critical” estimates and assumptions made by the company are as follows: Oil and Gas Reserves Crude oil, NGLs and natural gas reserves are estimates of future production that impact certain asset and expense accounts included in the Consolidated Financial Statements. Proved reserves are the estimated quantities of oil and gas that geoscience and engineering data demonstrate with reasonable certainty to be economically producible in the future under existing economic conditions, operating methods and government regulations. Proved reserves include both developed and undeveloped volumes. Proved developed reserves represent volumes expected to be recovered through existing wells with existing equipment and operating methods. Proved undeveloped reserves are volumes expected to be recovered from new wells on undrilled proved acreage, or from existing wells where a relatively major expenditure is required for recompletion. Variables impacting Chevron’s estimated volumes of crude oil, NGLs and natural gas reserves include field performance, available technology, commodity prices, and development, production and carbon costs. The estimates of crude oil, NGLs and natural gas reserves are important to the timing of expense recognition for costs incurred and to the valuation of certain oil and gas producing assets. Impacts of oil and gas reserves on Chevron’s Consolidated Financial Statements, using the successful efforts method of accounting, include the following: 1. Depreciation, Depletion and Amortization (DD&A) - Capitalized exploratory drilling and development costs are depreciated on a unit-of-production (UOP) basis using proved developed reserves. Acquisition costs of proved properties are amortized on a UOP basis using total proved reserves. During 2024, Chevron’s UOP DD&A for oil and gas properties was $13.0 billion, and proved developed reserves at the beginning of 2024 were 6.8 billion barrels for consolidated companies. If the estimates of proved reserves used in the UOP calculations for consolidated operations had been lower by five percent across all oil and gas properties, UOP DD&A in 2024 would have increased by approximately $700 million. 2. Impairment - Oil and gas reserves are used in assessing oil and gas producing properties for impairment. A significant reduction in the estimated reserves of a property would trigger an impairment review. Proved reserves (and, in some cases, a portion of unproved resources) are used to estimate future production volumes in the cash flow model. For a further discussion of estimates and assumptions used in impairment assessments, see Impairment of Properties, Plant and Equipment and Investments in Affiliates below. Refer to Table V, “Proved Reserve Quantity Information,” for the changes in proved reserve estimates for each of the three years ended December 31, 2022, 2023 and 2024, and to Table VII, “Changes in the Standardized Measure of Discounted Future Net Cash Flows From Proved Reserves” for estimates of proved reserve values for each of the three years ended December 31, 2022, 2023 and 2024. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 46 This Oil and Gas Reserves commentary should be read in conjunction with the Properties, Plant and Equipment section of Note 1 Summary of Significant Accounting Policies, which includes a description of the “successful efforts” method of accounting for oil and gas exploration and production activities. Impairment of Properties, Plant and Equipment and Investments in Affiliates The company assesses its properties, plant and equipment (PP&E) for possible impairment whenever events or changes in circumstances indicate that the carrying value of the assets may not be recoverable. If the carrying value of an asset exceeds the future undiscounted cash flows expected from the asset, an impairment charge is recorded for the excess of the carrying value of the asset over its estimated fair value. Determination as to whether and how much an asset is impaired involves management estimates on highly uncertain matters, such as future commodity prices, operating expenses, carbon costs, production profiles, the pace of the energy transition, and the outlook for global or regional market supply-and-demand conditions for crude oil, NGLs, natural gas, commodity chemicals and refined products. However, the impairment reviews and calculations are based on assumptions that are generally consistent with the company’s business plans and long-term investment decisions. Refer also to the discussion of impairments of properties, plant and equipment in Note 18 Properties, Plant and Equipment and to the section on Properties, Plant and Equipment in Note 1 Summary of Significant Accounting Policies. The company performs impairment assessments when triggering events arise to determine whether any write-down in the carrying value of an asset or asset group is required. For example, when significant downward revisions to crude oil, NGLs and natural gas reserves are made for any single field or concession, an impairment review is performed to determine if the carrying value of the asset remains recoverable. Similarly, a significant downward revision in the company’s crude oil, NGLs or natural gas price outlook would trigger impairment reviews for impacted upstream assets. In addition, impairments could occur due to changes in national, state or local environmental regulations or laws, including those designed to stop or impede the development or production of oil and gas. Also, if the expectation of sale of a particular asset or asset group in any period has been deemed more likely than not, an impairment review is performed, and if the estimated future undiscounted cash flows exceed the carrying value of the asset or asset group, no impairment charge is required. Such calculations are reviewed each period until the asset or asset group is disposed. Assets that are not impaired on a held-and-used basis could possibly become impaired if a decision is made to sell such assets. That is, the assets would be impaired if they are classified as held-for-sale and the estimated proceeds from the sale, less costs to sell, are less than the assets’ associated carrying values. Investments in common stock of affiliates that are accounted for under the equity method, as well as investments in other securities of these equity investees, are reviewed for impairment when the fair value of the investment falls below the company’s carrying value. When this occurs, a determination must be made as to whether this loss is other-than-temporary, in which case the investment is impaired. Because of the number of differing assumptions potentially affecting whether an investment is impaired in any period or the amount of the impairment, a sensitivity analysis is not practicable. A sensitivity analysis of the impact on earnings for these periods if other assumptions had been used in impairment reviews and impairment calculations is not practicable, given the broad range of the company’s PP&E and the number of assumptions involved in the estimates. That is, favorable changes to some assumptions might have avoided the need to impair any assets in these periods, whereas unfavorable changes might have caused an additional unknown number of other assets to become impaired, or resulted in larger impacts on impaired assets. Asset Retirement Obligations In the determination of fair value for an asset retirement obligation (ARO), the company uses various assumptions and judgments, including such factors as the existence of a legal obligation, estimated amounts and timing of settlements, discount and inflation rates, and the expected impact of advances in technology and process improvements. A sensitivity analysis of the ARO impact on earnings for 2024 is not practicable, given the broad range of the company’s long-lived assets and the number of assumptions involved in the estimates. That is, favorable changes to some assumptions would have reduced estimated future obligations, thereby lowering accretion expense and amortization costs, whereas unfavorable changes would have the opposite effect. Refer to Note 25 Asset Retirement Obligations for additional discussions on asset retirement obligations. Pension and Other Post-Employment Benefit Plans Note 23 Employee Benefit Plans includes information on the funded status of the company’s pension and other post-employment benefit (OPEB) plans reflected on the Consolidated Balance Sheet; the components of pension and OPEB expense reflected on the Consolidated Statement of Income; and the related underlying assumptions. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 47 The determination of pension plan expense and obligations is based on a number of actuarial assumptions. Two critical assumptions are the expected long-term rate of return on plan assets and the discount rate applied to pension plan obligations. Critical assumptions in determining expense and obligations for OPEB plans, which provide for certain health care and life insurance benefits for qualifying retired employees and which are not funded, are the discount rate and the assumed health care cost-trend rates. Information related to the company’s processes to develop these assumptions is included in Note 23 Employee Benefit Plans under the relevant headings. Actual rates may vary significantly from estimates because of unanticipated changes beyond the company’s control. For 2024, the company used an expected long-term rate of return of 7.0 percent and a discount rate for service costs of 5.0 percent and a discount rate for interest cost of 4.8 percent for the primary U.S. pension plan. The actual return for 2024 was 3.6 percent. For the 10 years ended December 31, 2024, actual asset returns averaged 4.9 percent for this plan. Additionally, with the exception of four years within this 10-year period, actual asset returns for this plan equaled or exceeded 7.0 percent during each year. Total pension expense for 2024 was $551 million. An increase in the expected long-term return on plan assets or the discount rate would reduce pension plan expense, and vice versa. As an indication of the sensitivity of pension expense to the long-term rate of return assumption, a one percent increase in this assumption for the company’s primary U.S. pension plan, which accounted for about 63 percent of companywide pension expense, would have reduced total pension plan expense for 2024 by approximately $84 million. A one percent increase in the discount rates for this same plan would have reduced pension expense for 2024 by approximately $106 million. The aggregate funded status recognized at December 31, 2024, was a net liability of approximately $0.8 billion. An increase in the discount rate would decrease the pension obligation, thus changing the funded status of a plan. At December 31, 2024, the company used a discount rate of 5.7 percent to measure the obligations for the primary U.S. pension plan. As an indication of the sensitivity of pension liabilities to the discount rate assumption, a 0.25 percent increase in the discount rate applied to the company’s primary U.S. pension plan, which accounted for about 66 percent of the companywide pension obligation, would have reduced the plan obligation by approximately $261 million, and would have increased the plan’s surplus from $573 million to $834 million. For the company’s OPEB plans, expense for 2024 was $91 million, and the total liability, all unfunded at the end of 2024, was $1.9 billion. For the primary U.S. OPEB plan, the company used a discount rate for service cost of 5.1 percent and a discount rate for interest cost of 4.9 percent to measure expense in 2024, and a 5.6 percent discount rate to measure the benefit obligations at December 31, 2024. Discount rate changes, similar to those used in the pension sensitivity analysis, resulted in an immaterial impact on 2024 OPEB expense and OPEB liabilities at the end of 2024. Differences between the various assumptions used to determine expense and the funded status of each plan and actual experience are included in actuarial gain/loss. Refer to page 85 in Note 23 Employee Benefit Plans for more information on the $3.2 billion of before-tax actuarial losses recorded by the company as of December 31, 2024. In addition, information related to company contributions is included on page 88 in Note 23 Employee Benefit Plans under the heading “Cash Contributions and Benefit Payments.” Contingent Losses Management also makes judgments and estimates in recording liabilities for claims, litigation, tax matters, transferred liabilities from previously divested assets, and environmental remediation. Actual costs can frequently vary from estimates for a variety of reasons. For example, the costs for settlement of claims and litigation can vary from estimates based on differing interpretations of laws, opinions on culpability and assessments on the amount of damages. The costs for decommissioning obligations for previously divested assets can also vary from estimates. Recording of liabilities for such costs typically requires judgment to assess the likelihood of decommissioning obligations reverting to the company, the timing of decommissioning activity, regulatory requirements and the scope of decommissioning activities. Similarly, liabilities for environmental remediation are subject to change because of changes in laws, regulations and their interpretation, the determination of additional information on the extent and nature of site contamination, and improvements in technology. Under the accounting rules, a liability is generally recorded for these types of contingencies if management determines the loss to be both probable and estimable. The company generally reports these losses as “Operating expenses,” “Selling, general and administrative expenses” or “Other income (loss)” on the Consolidated Statement of Income. An exception to this handling is for income tax matters, for which benefits are recognized only if management determines the tax position is more likely than not (i.e., likelihood greater than 50 percent) to be allowed by the tax jurisdiction. For additional discussion of income tax uncertainties, refer to Note 24 Other Contingencies and Commitments under the heading “Income Taxes.” Management’s Discussion and Analysis of Financial Condition and Results of Operations Chevron Corporation 2024 Annual Report 48 Refer also to the business segment discussions elsewhere in this section for the effect on earnings from losses associated with certain litigation, environmental remediation and tax matters for the three years ended December 31, 2024. An estimate as to the sensitivity to earnings for these periods if other assumptions had been used in recording these liabilities is not practicable because of the number of contingencies that must be assessed, the number of underlying assumptions and the wide range of reasonably possible outcomes, both in terms of the probability of loss and the estimates of such loss. For further information, refer to “Changes in management’s estimates and assumptions may have a material impact on the company’s consolidated financial statements and financial or operational performance in any given period” in Item 1A. Risk Factors, on page 27 of the company’s Annual Report on Form 10-K. New Accounting Standards Refer to Note 4 New Accounting Standards for information regarding new accounting standards. Management’s Discussion and Analysis of Financial Condition and Results of Operations Financial Table of Contents Chevron Corporation 2024 Annual Report 49 Quarterly Results Unaudited 2024 2023 Millions of dollars, except per-share amounts 4th Q 3rd Q 2nd Q 1st Q 4th Q 3rd Q 2nd Q 1st Q Revenues and Other Income Sales and other operating revenues $ 48,334 $ 48,926 $ 49,574 $ 46,580 $ 48,933 $ 51,922 $ 47,216 $ 48,842 Income from equity affiliates 688 1,261 1,206 1,441 990 1,313 1,240 1,588 Other income (loss) 3,204 482 401 695 (2,743) 845 440 363 Total Revenues and Other Income 52,226 50,669 51,181 48,716 47,180 54,080 48,896 50,793 Costs and Other Deductions Purchased crude oil and products 30,148 30,450 30,867 27,741 28,477 32,328 28,984 29,407 Operating expenses 7,622 6,695 6,614 6,533 6,510 6,299 6,057 6,021 Selling, general and administrative expenses 1,585 1,191 1,048 1,010 969 1,163 1,128 881 Exploration expenses 449 154 263 129 254 301 169 190 Depreciation, depletion and amortization 4,973 4,214 4,004 4,091 6,254 4,025 3,521 3,526 Taxes other than on income 1,141 1,263 1,188 1,124 1,062 1,021 1,041 1,096 Interest and debt expense 199 164 113 118 120 114 120 115 Other components of net periodic benefit costs 50 49 48 48 44 91 39 38 Total Costs and Other Deductions 46,167 44,180 44,145 40,794 43,690 45,342 41,059 41,274 Income (Loss) Before Income Tax Expense 6,059 6,489 7,036 7,922 3,490 8,738 7,837 9,519 Income Tax Expense (Benefit) 2,800 1,993 2,593 2,371 1,247 2,183 1,829 2,914 Net Income (Loss) $ 3,259 $ 4,496 $ 4,443 $ 5,551 $ 2,243 $ 6,555 $ 6,008 $ 6,605 Less: Net income (loss) attributable to noncontrolling interests 20 9 9 50 (16) 29 (2) 31 Net Income (Loss) Attributable to Chevron Corporation $ 3,239 $ 4,487 $ 4,434 $ 5,501 $ 2,259 $ 6,526 $ 6,010 $ 6,574 Per Share of Common Stock Net Income (Loss) Attributable to Chevron Corporation – Basic $ 1.85 $ 2.49 $ 2.43 $ 2.99 $ 1.23 $ 3.48 $ 3.22 $ 3.48 – Diluted $ 1.84 $ 2.48 $ 2.43 $ 2.97 $ 1.22 $ 3.48 $ 3.20 $ 3.46 Dividends per share $ 1.63 $ 1.63 $ 1.63 $ 1.63 $ 1.51 $ 1.51 $ 1.51 $ 1.51 Financial Table of Contents Chevron Corporation 2024 Annual Report 50 Management’s Responsibility for Financial Statements To the Stockholders of Chevron Corporation Management of Chevron Corporation is responsible for preparing the accompanying consolidated financial statements and the related information appearing in this report. The statements were prepared in accordance with accounting principles generally accepted in the United States of America and fairly represent the transactions and financial position of the company. The financial statements include amounts that are based on management’s best estimates and judgments. As stated in its report included herein, the independent registered public accounting firm of PricewaterhouseCoopers LLP has audited the company’s consolidated financial statements in accordance with the standards of the Public Company Accounting Oversight Board (United States). The Board of Directors of Chevron has an Audit Committee composed of directors who are not officers or employees of the company. The Audit Committee meets regularly with members of management, the internal auditors and the independent registered public accounting firm to review accounting, internal control, auditing and financial reporting matters. Both the internal auditors and the independent registered public accounting firm have free and direct access to the Audit Committee without the presence of management. The company’s management has evaluated, with the participation of the Chief Executive Officer and Chief Financial Officer, the effectiveness of the company’s disclosure controls and procedures (as defined in the Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, 2024. Based on that evaluation, management concluded that the company’s disclosure controls are effective in ensuring that information required to be recorded, processed, summarized and reported are done within the time periods specified in the U.S. Securities and Exchange Commission’s rules and forms. Management’s Report on Internal Control Over Financial Reporting The company’s management is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in the Exchange Act Rules 13a-15(f) and 15d-15(f). The company’s management, including the Chief Executive Officer and Chief Financial Officer, conducted an evaluation of the effectiveness of the company’s internal control over financial reporting based on the Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on the results of this evaluation, the company’s management concluded that internal control over financial reporting was effective as of December 31, 2024. The effectiveness of the company’s internal control over financial reporting as of December 31, 2024, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in its report included herein. /s/ MICHAEL K. WIRTH /s/ EIMEAR P. BONNER /s/ ALANA K. KNOWLES Michael K. Wirth Eimear P. Bonner Alana K. Knowles Chairman of the Board Vice President Vice President and Chief Executive Officer and Chief Financial Officer and Controller February 21, 2025 Financial Table of Contents Chevron Corporation 2024 Annual Report 51 Report of Independent Registered Public Accounting Firm To the Board of Directors and Stockholders of Chevron Corporation Opinions on the Financial Statements and Internal Control over Financial Reporting We have audited the accompanying consolidated balance sheet of Chevron Corporation and its subsidiaries (the “Company”) as of December 31, 2024 and 2023, and the related consolidated statements of income, of comprehensive income, of equity and of cash flows for each of the three years in the period ended December 31, 2024, including the related notes and financial statement schedule listed in the index appearing under Item 15(a)(2) (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO. Basis for Opinions The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control Over Financial Reporting. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions. Definition and Limitations of Internal Control over Financial Reporting A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements. Financial Table of Contents Chevron Corporation 2024 Annual Report 52 Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. Critical Audit Matters The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. The Impact of Proved Developed Crude Oil and Natural Gas Reserves on Upstream Property, Plant, and Equipment, Net As described in Notes 1 and 18 to the consolidated financial statements, the Company’s upstream property, plant and equipment, net balance was $129.1 billion as of December 31, 2024, and depreciation, depletion and amortization expense was $15.5 billion for the year ended December 31, 2024. The Company follows the successful efforts method of accounting for crude oil and natural gas exploration and production activities. Depreciation and depletion of all capitalized costs of proved crude oil and natural gas producing properties, except mineral interests, are expensed using the unit-of-production method, generally by individual field, as the proved developed reserves are produced. Depletion expenses for capitalized costs of proved mineral interests are recognized using the unit-of-production method by individual field as the related proved reserves are produced. As disclosed by management, variables impacting the Company’s estimated volumes of proved crude oil, natural gas liquids (NGLs) and natural gas reserves include field performance, available technology, commodity prices, and development, production and carbon costs. Reserves are estimated by Company asset teams composed of earth scientists and engineers. As part of the internal control process related to reserves estimation, the Company maintains a Reserves Advisory Committee (RAC) (the Company’s earth scientists, engineers and RAC are collectively referred to as “management’s specialists”). The principal considerations for our determination that performing procedures relating to the impact of proved developed crude oil and natural gas reserves on upstream property, plant, and equipment, net is a critical audit matter are (i) the significant judgment by management, including the use of management’s specialists, when developing the estimates of proved developed crude oil and natural gas reserves, which in turn led to (ii) a high degree of auditor judgment, subjectivity, and effort in performing procedures and evaluating audit evidence obtained related to the data, methods, and assumptions used by management and its specialists in developing the estimates of proved developed crude oil and natural gas reserves. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s estimates of proved developed crude oil and natural gas reserves. The work of management’s specialists was used in performing the procedures to evaluate the reasonableness of the proved developed crude oil and natural gas reserves. As a basis for using this work, the specialists’ qualifications were understood and the Company’s relationship with the specialists was assessed. The procedures performed also included evaluation of the methods and assumptions used by the specialists, tests of data used by the specialists and an evaluation of the specialists’ findings related to estimated future production volumes by comparing the estimate to relevant historical and current period information, as applicable. /s/ PricewaterhouseCoopers LLP San Francisco, California February 21, 2025 We have served as the Company’s auditor since 1935. Financial Table of Contents Chevron Corporation 2024 Annual Report 53 Year ended December 31 2024 2023 2022 Revenues and Other Income Sales and other operating revenues $ 193,414 $ 196,913 $ 235,717 Income (loss) from equity affiliates 4,596 5,131 8,585 Other income (loss) 4,782 (1,095) 1,950 Total Revenues and Other Income 202,792 200,949 246,252 Costs and Other Deductions Purchased crude oil and products 119,206 119,196 145,416 Operating expenses 27,464 24,887 24,714 Selling, general and administrative expenses 4,834 4,141 4,312 Exploration expenses 995 914 974 Depreciation, depletion and amortization 17,282 17,326 16,319 Taxes other than on income 4,716 4,220 4,032 Interest and debt expense 594 469 516 Other components of net periodic benefit costs 195 212 295 Total Costs and Other Deductions 175,286 171,365 196,578 Income (Loss) Before Income Tax Expense 27,506 29,584 49,674 Income Tax Expense (Benefit) 9,757 8,173 14,066 Net Income (Loss) 17,749 21,411 35,608 Less: Net income (loss) attributable to noncontrolling interests 88 42 143 Net Income (Loss) Attributable to Chevron Corporation $ 17,661 $ 21,369 $ 35,465 Per Share of Common Stock Net Income (Loss) Attributable to Chevron Corporation - Basic $ 9.76 $ 11.41 $ 18.36 - Diluted $ 9.72 $ 11.36 $ 18.28 See accompanying Notes to the Consolidated Financial Statements. Consolidated Statement of Income Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 54 Year ended December 31 2024 2023 2022 Net Income (Loss) $ 17,749 $ 21,411 $ 35,608 Currency translation adjustment Unrealized net change arising during period (67) 11 (41) Unrealized holding gain (loss) on securities Net gain (loss) arising during period (8) 1 (1) Derivatives Net derivatives gain (loss) on hedge transactions (50) (11) 65 Reclassification to net income 25 33 (80) Income tax benefit (cost) on derivatives transactions 6 (5) 3 Total (19) 17 (12) Defined benefit plans Actuarial gain (loss) Amortization to net income of net actuarial loss and settlements 247 244 599 Actuarial gain (loss) arising during period 228 (550) 1,050 Prior service credits (cost) Amortization to net income of net prior service costs and curtailments (10) (13) (19) Prior service (costs) credits arising during period (48) (29) (96) Defined benefit plans sponsored by equity affiliates - benefit (cost) (19) 6 100 Income tax benefit (cost) on defined benefit plans (104) 151 (489) Total 294 (191) 1,145 Other Comprehensive Gain (Loss), Net of Tax 200 (162) 1,091 Comprehensive Income (Loss) 17,949 21,249 36,699 Comprehensive loss (income) attributable to noncontrolling interests (88) (42) (143) Comprehensive Income (Loss) Attributable to Chevron Corporation $ 17,861 $ 21,207 $ 36,556 See accompanying Notes to the Consolidated Financial Statements. Consolidated Statement of Comprehensive Income Financial Table of Contents Millions of dollars Chevron Corporation 2024 Annual Report 55 Consolidated Balance Sheet Financial Table of Contents Millions of dollars, except per-share amounts At December 31 2024 2023 Assets Cash and cash equivalents $ 6,781 $ 8,178 Time deposits 4 — Marketable securities — 45 Accounts and notes receivable (less allowance: 2024 - $259; 2023 - $301) 20,684 19,921 Inventories: Crude oil and products 6,490 6,059 Chemicals 502 406 Materials, supplies and other 2,082 2,147 Total inventories 9,074 8,612 Prepaid expenses and other current assets 4,368 4,372 Total Current Assets 40,911 41,128 Long-term receivables, net (less allowances: 2024 - $352; 2023 - $340) 877 942 Investments and advances 47,438 46,812 Properties, plant and equipment, at cost 345,933 346,081 Less: Accumulated depreciation, depletion and amortization 198,134 192,462 Properties, plant and equipment, net 147,799 153,619 Deferred charges and other assets 14,854 13,734 Goodwill 4,578 4,722 Assets held for sale 481 675 Total Assets $ 256,938 $ 261,632 Liabilities and Equity Short-term debt $ 4,406 $ 529 Accounts payable 22,079 20,423 Accrued liabilities 8,486 7,655 Federal and other taxes on income 1,872 1,863 Other taxes payable 1,715 1,788 Total Current Liabilities 38,558 32,258 Long-term debt1 20,135 20,307 Deferred credits and other noncurrent obligations 22,094 24,226 Noncurrent deferred income taxes 19,137 18,830 Noncurrent employee benefit plans 3,857 4,082 Total Liabilities2 $ 103,781 $ 99,703 Preferred stock (authorized 100,000,000 shares; $1.00 par value; none issued) — — Common stock (authorized 6,000,000,000 shares; $0.75 par value; 2,442,676,580 shares issued at December 31, 2024 and 2023) 1,832 1,832 Capital in excess of par value 21,671 21,365 Retained earnings 205,852 200,025 Accumulated other comprehensive losses (2,760) (2,960) Deferred compensation and benefit plan trust (240) (240) Treasury stock, at cost (2024 - 673,664,306 shares; 2023 - 577,028,776 shares) (74,037) (59,065) Total Chevron Corporation Stockholders’ Equity 152,318 160,957 Noncontrolling interests (includes redeemable noncontrolling interest of $0 and $166 at December 31, 2024 and 2023) 839 972 Total Equity 153,157 161,929 Total Liabilities and Equity $ 256,938 $ 261,632 1 Includes finance lease liabilities of $546 and $574 at December 31, 2024 and 2023, respectively. 2 Refer to Note 24 Other Contingencies and Commitments. See accompanying Notes to the Consolidated Financial Statements. Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 56 Year ended December 31 2024 2023 2022 Operating Activities Net Income (Loss) $ 17,749 $ 21,411 $ 35,608 Adjustments Depreciation, depletion and amortization 17,282 17,326 16,319 Dry hole expense 429 436 486 Distributions more (less) than income from equity affiliates (366) (885) (4,730) Net before-tax gains on asset retirements and sales (1,685) (138) (550) Net foreign currency effects (629) 578 (412) Deferred income tax provision 1,240 298 2,124 Net decrease (increase) in operating working capital 1,211 (3,185) 2,125 Decrease (increase) in long-term receivables 114 150 153 Net decrease (increase) in other deferred charges (1,225) (300) (212) Cash contributions to employee pension plans (844) (1,120) (1,322) Other (1,784) 1,038 13 Net Cash Provided by Operating Activities 31,492 35,609 49,602 Investing Activities Acquisition of businesses, net of cash received — 55 (2,862) Capital expenditures (16,448) (15,829) (11,974) Proceeds and deposits related to asset sales and returns of investment 7,704 669 2,635 Net maturities of (investments in) time deposits (4) — — Net sales (purchases) of marketable securities 45 175 117 Net repayment (borrowing) of loans by equity affiliates (233) (302) (24) Net Cash Used for Investing Activities (8,936) (15,232) (12,108) Financing Activities Net borrowings (repayments) of short-term obligations 4,868 135 263 Proceeds from issuances of long-term debt 478 150 — Repayments of long-term debt and other financing obligations (1,778) (4,340) (8,742) Cash dividends - common stock (11,801) (11,336) (10,968) Net contributions from (distributions to) noncontrolling interests (195) (40) (114) Net sales (purchases) of treasury shares (15,044) (14,678) (5,417) Net Cash Provided by (Used for) Financing Activities (23,472) (30,109) (24,978) Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash (97) (114) (190) Net Change in Cash, Cash Equivalents and Restricted Cash (1,013) (9,846) 12,326 Cash, Cash Equivalents and Restricted Cash at January 1 9,275 19,121 6,795 Cash, Cash Equivalents and Restricted Cash at December 31 $ 8,262 $ 9,275 $ 19,121 See accompanying Notes to the Consolidated Financial Statements. Consolidated Statement of Cash Flows Financial Table of Contents Millions of dollars Chevron Corporation 2024 Annual Report 57 Acc. Other Treasury Chevron Corp. Common Retained Comprehensive Stock Stockholders’ Noncontrolling Total Stock1 Earnings Income (Loss) (at cost) Equity Interests Equity Balance at December 31, 2021 $ 18,874 $ 165,546 $ (3,889) $ (41,464) $ 139,067 $ 873 $ 139,940 Treasury stock transactions 63 — — — 63 — 63 Net income (loss) — 35,465 — — 35,465 143 35,608 Cash dividends ($5.68 per share) — (10,968) — — (10,968) (118) (11,086) Stock dividends — (3) — — (3) — (3) Other comprehensive income — — 1,091 — 1,091 — 1,091 Purchases of treasury shares — — — (11,255) (11,255) — (11,255) Issuances of treasury shares 1,315 — — 4,523 5,838 — 5,838 Other changes, net — (16) — — (16) 62 46 Balance at December 31, 2022 $ 20,252 $ 190,024 $ (2,798) $ (48,196) $ 159,282 $ 960 $ 160,242 Treasury stock transactions 174 — — — 174 — 174 PDC Energy, Inc. acquisition 2,550 — — 3,970 6,520 — 6,520 Net income (loss) — 21,369 — — 21,369 42 21,411 Cash dividends ($6.04 per share) — (11,336) — — (11,336) (54) (11,390) Stock dividends — (9) — — (9) — (9) Other comprehensive income — — (162) — (162) — (162) Purchases of treasury shares — — — (15,085) (15,085) — (15,085) Issuances of treasury shares 17 — — 246 263 — 263 Other changes, net (36) (23) — — (59) 24 (35) Balance at December 31, 2023 $ 22,957 $ 200,025 $ (2,960) $ (59,065) $ 160,957 $ 972 $ 161,929 Treasury stock transactions 255 — — — 255 — 255 Net income (loss) — 17,661 — — 17,661 88 17,749 Cash dividends ($6.52 per share) — (11,801) — — (11,801) (210) (12,011) Stock dividends — (22) — — (22) — (22) Other comprehensive income — — 200 — 200 — 200 Purchases of treasury shares2 — — — (15,374) (15,374) — (15,374) Issuances of treasury shares 51 — — 402 453 — 453 Other changes, net — (11) — — (11) (11) (22) Balance at December 31, 2024 $ 23,263 $ 205,852 $ (2,760) $ (74,037) $ 152,318 $ 839 $ 153,157 Common Stock Share Activity Issued3 Treasury Outstanding Balance at December 31, 2021 2,442,676,580 (512,870,523) 1,929,806,057 Purchases — (69,912,961) (69,912,961) Issuances — 55,323,247 55,323,247 Balance at December 31, 2022 2,442,676,580 (527,460,237) 1,915,216,343 Purchases — (92,849,905) (92,849,905) Issuances — 43,281,366 43,281,366 Balance at December 31, 2023 2,442,676,580 (577,028,776) 1,865,647,804 Purchases — (100,444,608) (100,444,608) Issuances — 3,809,078 3,809,078 Balance at December 31, 2024 2,442,676,580 (673,664,306) 1,769,012,274 1 Beginning and ending balances for all periods include capital in excess of par, common stock issued at par for $1,832, and $(240) associated with Chevron’s Benefit Plan Trust. Changes reflect capital in excess of par. 2 Includes excise tax on share repurchases. 3 Beginning and ending total issued share balances include 14,168,000 shares associated with Chevron’s Benefit Plan Trust. See accompanying Notes to the Consolidated Financial Statements. Consolidated Statement of Equity Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 58 Note 1 Summary of Significant Accounting Policies General The company’s Consolidated Financial Statements are prepared in accordance with accounting principles generally accepted in the United States of America. These require the use of estimates and assumptions that affect the assets, liabilities, revenues and expenses reported in the financial statements, as well as amounts included in the notes thereto, including discussion and disclosure of contingent liabilities. Although the company uses its best estimates and judgments, actual results could differ from these estimates as circumstances change and additional information becomes known. Prior years’ data have been reclassified in certain cases to conform to the 2024 presentation basis. Subsidiary and Affiliated Companies The Consolidated Financial Statements include the accounts of controlled subsidiary companies more than 50 percent-owned and any variable interest entities in which the company is the primary beneficiary. Undivided interests in oil and gas joint ventures and certain other assets are consolidated on a proportionate basis. Investments in and advances to affiliates in which the company has a substantial ownership interest of approximately 20 percent to 50 percent, or for which the company exercises significant influence but not control over policy decisions, are accounted for by the equity method. Investments in affiliates are assessed for possible impairment when events indicate that the fair value of the investment may be below the company’s carrying value. When such a condition is deemed to be other than temporary, the carrying value of the investment is written down to its fair value, and the amount of the write-down is included in net income. In making the determination as to whether a decline is other than temporary, the company considers such factors as the duration and extent of the decline, the investee’s financial performance, and the company’s ability and intention to retain its investment for a period that will be sufficient to allow for any anticipated recovery in the investment’s market value. The new cost basis of investments in these equity investees is not changed for subsequent recoveries in fair value. Differences between the company’s carrying value of an equity investment and its underlying equity in the net assets of the affiliate are assigned to the extent practicable to specific assets and liabilities based on the company’s analysis of the various factors giving rise to the difference. When appropriate, the company’s share of the affiliate’s reported earnings is adjusted quarterly to reflect the difference between these allocated values and the affiliate’s historical book values. Noncontrolling Interests Ownership interests in the company’s subsidiaries held by parties other than the parent are presented separately from the parent’s equity on the Consolidated Balance Sheet. The amount of consolidated net income attributable to the parent and the noncontrolling interests are both presented on the face of the Consolidated Statement of Income and Consolidated Statement of Equity. Included within noncontrolling interest is redeemable noncontrolling interest. Fair Value Measurements The three levels of the fair value hierarchy of inputs the company uses to measure the fair value of an asset or a liability are as follows. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Level 3 inputs are inputs that are not observable in the market. Derivatives The majority of the company’s activity in derivative commodity instruments is intended to manage the financial risk posed by physical transactions. For some of this derivative activity, the company may elect to apply fair value or cash flow hedge accounting with changes in fair value recorded as components of accumulated other comprehensive income (loss). For other similar derivative instruments, generally because of the short-term nature of the contracts or their limited use, the company does not apply hedge accounting, and changes in the fair value of those contracts are reflected in current income. For the company’s commodity trading activity, gains and losses from derivative instruments are reported in current income. The company may enter into interest rate swaps from time to time as part of its overall strategy to manage the interest rate risk on its debt. Interest rate swaps related to a portion of the company’s fixed-rate debt, if any, may be accounted for as fair value hedges. Interest rate swaps related to floating-rate debt, if any, are recorded at fair value on the balance sheet with resulting gains and losses reflected in income. Where Chevron is a party to master netting arrangements, fair value receivable and payable amounts recognized for derivative instruments executed with the same counterparty are generally offset on the balance sheet. Inventories Crude oil, products and chemicals inventories are generally stated at cost, using a last-in, first-out method. In the aggregate, these costs are below market. “Materials, supplies and other” inventories are primarily stated at cost or net realizable value. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 59 Properties, Plant and Equipment The successful efforts method is used for crude oil and natural gas exploration and production activities. All costs for development wells, related plant and equipment, proved mineral interests in crude oil and natural gas properties, and related asset retirement obligation (ARO) assets are capitalized. Costs of exploratory wells are capitalized pending determination of whether the wells found proved reserves. Costs of wells that are assigned proved reserves remain capitalized. Costs also are capitalized for exploratory wells that have found crude oil and natural gas reserves even if the reserves cannot be classified as proved when the drilling is completed, provided the exploratory well has found a sufficient quantity of reserves to justify its completion as a producing well and the company is making sufficient progress assessing the reserves and the economic and operating viability of the project. All other exploratory wells and costs are expensed. Refer to Note 21 Accounting for Suspended Exploratory Wells for additional discussion of accounting for suspended exploratory well costs. Long-lived assets to be held and used, including proved crude oil and natural gas properties, are assessed for possible impairment by comparing their carrying values with their associated undiscounted, future net cash flows. Events that can trigger assessments for possible impairments include write-downs of proved reserves based on field performance, significant decreases in the market value of an asset (including changes to the commodity price forecast or carbon costs), significant change in the extent or manner of use of or a physical change in an asset, and a more likely than not expectation that a long-lived asset or asset group will be sold or otherwise disposed of significantly sooner than the end of its previously estimated useful life. Impaired assets are written down to their estimated fair values, generally their discounted, future net cash flows. For proved crude oil and natural gas properties, the company performs impairment reviews on a country, concession, PSC, development area or field basis, as appropriate. In downstream, impairment reviews are performed on the basis of a refinery, a plant, a marketing/lubricants area or distribution area, as appropriate. Impairment amounts are recorded as incremental “Depreciation, depletion and amortization” expense. Long-lived assets that are held for sale are evaluated for possible impairment by comparing the carrying value of the asset with its fair value less the cost to sell. If the net book value exceeds the fair value less cost to sell, the asset is considered impaired and adjusted to the lower value. Refer to Note 9 Fair Value Measurements relating to fair value measurements. The fair value of a liability for an ARO is recorded as an asset and a liability when there is a legal obligation associated with the retirement of a long-lived asset and the amount can be reasonably estimated. Refer also to Note 25 Asset Retirement Obligations relating to AROs. Depreciation and depletion of all capitalized costs of proved crude oil and natural gas producing properties, except mineral interests, are expensed using the unit-of-production method, generally by individual field, as the proved developed reserves are produced. Depletion expenses for capitalized costs of proved mineral interests are recognized using the unit-of- production method by individual field as the related proved reserves are produced. Impairments of capitalized costs of unproved mineral interests are expensed. The capitalized costs of all other plant and equipment are depreciated or amortized over their estimated useful lives. In general, the declining-balance method is used to depreciate plant and equipment in the United States; the straight-line method is generally used to depreciate international plant and equipment and to amortize finance lease right-of-use assets. Gains or losses are not recognized for normal retirements of properties, plant and equipment subject to composite group amortization or depreciation. Gains or losses from abnormal retirements are recorded as expenses, and from sales as “Other income.” Expenditures for maintenance (including those for planned major maintenance projects), repairs and minor renewals to maintain facilities in operating condition are generally expensed as incurred. Major replacements and renewals are capitalized. Leases Leases are classified as operating or finance leases. Both operating and finance leases recognize lease liabilities and associated right-of-use assets. The company has elected the short-term lease exception and therefore only recognizes right- of-use assets and lease liabilities for leases with a term greater than one year. The company has elected the practical expedient to not separate non-lease components from lease components for most asset classes except for certain asset classes that have significant non-lease (i.e., service) components. Where leases are used in joint ventures, the company recognizes 100 percent of the right-of-use assets and lease liabilities when the company is the sole signatory for the lease (in most cases, where the company is the operator of a joint venture). Lease costs reflect only the costs associated with the operator’s working interest share. The lease term includes the committed lease term identified in the contract, taking into account renewal and termination options that management is Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 60 reasonably certain to exercise. The company uses its incremental borrowing rate as a proxy for the discount rate based on the term of the lease unless the implicit rate is available. Decommissioning Obligations from Previously Divested Assets Some assets are divested with their related liabilities, including decommissioning obligations, to a buyer that results in de-recognition of the liability from the balance sheet. In certain instances, such transferred obligations may return to the company and result in losses. To the extent the current owners of the company’s previously divested assets default on their decommissioning obligations, regulators may require that Chevron assume such obligations. The company would accrue losses associated with these obligations when management determines the loss to be both probable and reasonably estimable. This typically requires judgment to assess the likelihood of decommissioning obligations reverting to the company, the timing of decommissioning activity, regulatory requirements and the scope of decommissioning activities. For more information on decommissioning obligations related to previously divested assets, refer to Note 24 Other Contingencies and Commitments. Goodwill Goodwill resulting from a business combination is not subject to amortization. The company tests such goodwill at the reporting unit level for impairment annually at December 31, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of the reporting unit below its carrying amount. Environmental Expenditures Environmental expenditures that relate to ongoing operations or to conditions caused by past operations are expensed. Expenditures that create future benefits or contribute to future revenue generation are capitalized. Liabilities related to future remediation costs are recorded when environmental assessments or cleanups or both are probable and the costs can be reasonably estimated. For crude oil, natural gas and mineral-producing properties, a liability for an ARO is made in accordance with accounting standards for asset retirement and environmental obligations. Refer to Note 25 Asset Retirement Obligations for a discussion of the company’s AROs. For U.S. federal Superfund sites and analogous sites under state laws, the company records a liability for its designated share of the probable and estimable costs, and probable amounts for other potentially responsible parties when mandated by the regulatory agencies because the other parties are not able to pay their respective shares. The gross amount of environmental liabilities is based on the company’s best estimate of future costs using currently available technology and applying current regulations and the company’s own internal environmental policies. Future amounts are not discounted. Recoveries or reimbursements are recorded as assets when receipt is reasonably assured. Currency Translation The U.S. dollar is the functional currency for substantially all of the company’s consolidated operations and those of its equity affiliates. For those operations, all gains and losses from currency remeasurement are included in current period income. The cumulative translation effects for those few entities, both consolidated and affiliated, using functional currencies other than the U.S. dollar are included in “Currency translation adjustment” on the Consolidated Statement of Equity. Revenue Recognition The company accounts for each delivery order of crude oil, NGLs, natural gas, petroleum and chemical products as a separate performance obligation. Revenue is recognized when the performance obligation is satisfied, which typically occurs at the point in time when control of the product transfers to the customer. Payment is generally due within 30 days of delivery. The company accounts for delivery transportation as a fulfillment cost, not a separate performance obligation, and recognizes these costs as an operating expense in the period when revenue for the related commodity is recognized. Revenue is measured as the amount the company expects to receive in exchange for transferring commodities to the customer. The company’s commodity sales are typically based on prevailing market-based prices and may include discounts and allowances. Until market prices become known under terms of the company’s contracts, the transaction price included in revenue is based on the company’s estimate of the most likely outcome. Discounts and allowances are estimated using a combination of historical and recent data trends. When deliveries contain multiple products, an observable standalone selling price is generally used to measure revenue for each product. The company includes estimates in the transaction price only to the extent that a significant reversal of revenue is not probable in subsequent periods. Stock Options and Other Share-Based Compensation The company issues stock options and other share-based compensation to certain employees. For equity awards, such as stock options and certain restricted stock units, total compensation cost is based on the grant date fair value, and for liability awards, such as stock appreciation rights, total compensation cost is based on the settlement value. The company recognizes stock-based compensation expense for all awards over the service period required to earn the award, which is the shorter of the vesting period or the time period in Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 61 which an employee becomes eligible to retain the award at retirement. For more information on stock options and other share-based compensation, refer to Note 22 Stock Options and Other Share-Based Compensation. Note 2 Changes in Accumulated Other Comprehensive Losses The change in Accumulated Other Comprehensive Losses (AOCL) presented on the Consolidated Balance Sheet and the impact of significant amounts reclassified from AOCL on information presented in the Consolidated Statement of Income for the year ended December 31, 2024, are reflected in the table below. Currency Translation Adjustments Unrealized Holding Gains (Losses) on Securities Derivatives Defined Benefit Plans Total Balance at December 31, 2021 $ (162) $ (11) $ — $ (3,716) $ (3,889) Components of Other Comprehensive Income (Loss)1: Before Reclassifications (41) (1) 68 703 729 Reclassifications2, 3 — — (80) 442 362 Net Other Comprehensive Income (Loss) (41) (1) (12) 1,145 1,091 Balance at December 31, 2022 $ (203) $ (12) $ (12) $ (2,571) $ (2,798) Components of Other Comprehensive Income (Loss)1: Before Reclassifications 11 1 (16) (397) (401) Reclassifications2, 3 — — 33 206 239 Net Other Comprehensive Income (Loss) 11 1 17 (191) (162) Balance at December 31, 2023 $ (192) $ (11) $ 5 $ (2,762) $ (2,960) Components of Other Comprehensive Income (Loss)1: Before Reclassifications (67) (8) (44) 119 — Reclassifications2, 3 — — 25 175 200 Net Other Comprehensive Income (Loss) (67) (8) (19) 294 200 Balance at December 31, 2024 $ (259) $ (19) $ (14) $ (2,468) $ (2,760) 1 All amounts are net of tax. 2 Refer to Note 23 Employee Benefit Plans, for reclassified components, including amortization of actuarial gains or losses, amortization of prior service costs and settlement losses, totaling $237 that are included in employee benefit costs for the year ended December 31, 2024. Related income taxes for the same period, totaling $62, are reflected in Income Tax Expense on the Consolidated Statement of Income. All other reclassified amounts were insignificant. 3 Refer to Note 10 Financial and Derivative Instruments for cash flow hedging. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 62 Note 3 Information Relating to the Consolidated Statement of Cash Flows Year ended December 31 2024 2023 2022 Distributions more (less) than income from equity affiliates includes the following: Distributions from equity affiliates $ 4,230 $ 4,246 $ 3,855 (Income) loss from equity affiliates (4,596) (5,131) (8,585) Distributions more (less) than income from equity affiliates $ (366) $ (885) $ (4,730) Net decrease (increase) in operating working capital was composed of the following: Decrease (increase) in accounts and notes receivable $ (932) $ 1,187 $ (2,317) Decrease (increase) in inventories (574) (320) (930) Decrease (increase) in prepaid expenses and other current assets (16) (1,202) (226) Increase (decrease) in accounts payable and accrued liabilities 2,569 (49) 2,750 Increase (decrease) in income and other taxes payable 164 (2,801) 2,848 Net decrease (increase) in operating working capital $ 1,211 $ (3,185) $ 2,125 Net cash provided by operating activities includes the following cash payments: Interest on debt (net of capitalized interest) $ 587 $ 465 $ 525 Income taxes 8,458 10,416 9,148 Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts: Proceeds and deposits related to asset sales $ 7,509 $ 446 $ 1,435 Returns of investment from equity affiliates 195 223 1,200 Proceeds and deposits related to asset sales and returns of investment $ 7,704 $ 669 $ 2,635 Net maturities (investments) of time deposits consisted of the following gross amounts: Investments in time deposits $ (6) $ — $ — Maturities of time deposits 2 — — Net maturities of (investments in) time deposits $ (4) $ — $ — Net sales (purchases) of marketable securities consisted of the following gross amounts: Marketable securities purchased $ — $ (289) $ (7) Marketable securities sold 45 464 124 Net sales (purchases) of marketable securities $ 45 $ 175 $ 117 Net repayment (borrowing) of loans by equity affiliates: Borrowing of loans by equity affiliates $ (304) $ (368) $ (108) Repayment of loans by equity affiliates 71 66 84 Net repayment (borrowing) of loans by equity affiliates $ (233) $ (302) $ (24) Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts: Repayments of short-term obligations $ (840) $ — $ — Proceeds from issuances of short-term debt obligations 4,539 — — Net borrowings (repayments) of short-term obligations with three months or less maturity 1,169 135 263 Net borrowings (repayments) of short-term obligations $ 4,868 $ 135 $ 263 Net sales (purchases) of treasury shares consists of the following gross and net amounts: Shares issued for share-based compensation plans $ 330 $ 261 $ 5,838 Shares purchased under share repurchase and deferred compensation plans (15,229) (14,939) (11,255) Share repurchase excise tax payments (145) — — Net sales (purchases) of treasury shares $ (15,044) $ (14,678) $ (5,417) Net contributions from (distributions to) noncontrolling interests consisted of the following gross and net amounts: Distributions to noncontrolling interests $ (210) $ (54) $ (118) Contributions from noncontrolling interests 15 14 4 Net contributions from (distributions to) noncontrolling interests $ (195) $ (40) $ (114) The “Other” line in the Operating Activities section includes changes in asset retirement obligations, decommissioning obligations associated with previously divested assets, post-employment benefit obligations and other long-term liabilities. Refer also to Note 25 Asset Retirement Obligations for a discussion of the company’s AROs activity, including revisions that did not involve cash receipts or payments. The Consolidated Statement of Cash Flows excludes changes to the Consolidated Balance Sheet that did not affect cash. “Depreciation, depletion and amortization” and “Deferred income tax provision” collectively include approximately $400 Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 63 in non-cash reductions to “Properties, plant and equipment” and “Investments and advances” in 2024 relating to impairments. “Operating expenses” and “Deferred income tax provision” include an approximately $715 severance charge related to non-cash increases to “Net decrease (increase) in operating working capital” and “Other” associated with employee severance. The cash outlay for severance payments is expected to take place through 2026. The components of “Capital expenditures” are presented in the following table: Year ended December 31 2024 2023 2022 Additions to properties, plant and equipment* $ 15,544 $ 14,788 $ 10,349 Additions to investments 573 690 1,147 Current-year dry hole expenditures 331 326 309 Payments for other assets and liabilities, net — 25 169 Capital expenditures $ 16,448 $ 15,829 $ 11,974 * Excludes non-cash movements of $395 in 2024, $1,559 in 2023 and $316 in 2022. The table below quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet: Year ended December 31 2024 2023 2022 Cash and cash equivalents $ 6,781 $ 8,178 $ 17,678 Restricted cash included in “Prepaid expenses and other current assets” 281 275 630 Restricted cash included in “Deferred charges and other assets” 1,200 822 813 Total cash, cash equivalents and restricted cash $ 8,262 $ 9,275 $ 19,121 Note 4 New Accounting Standards Segment Reporting (Topic 280) Improvements to Reportable Segment Disclosures The company has adopted the Financial Accounting Standards Board (FASB) Accounting Standard Update (ASU) 2023-07 which is effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. The standard requires companies to disclose significant segment expenses. The adoption of this ASU did not have an impact on the company’s consolidated financial position or results of operations. For additional information, refer to Note 14 Operating Segments and Geographic Data. Income Taxes (Topic 740) Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09, which becomes effective for fiscal years beginning after December 15, 2024. The standard requires companies to disclose specific categories in the income tax rate reconciliation table and the amount of income taxes paid per major jurisdiction. The company does not expect the standard to have a material effect on its consolidated financial statements and continues to evaluate disclosure presentation alternatives. Income Statement (Topic 220) Reporting Comprehensive Income - Expense Disaggregation Disclosures In November 2024, the FASB issued ASU 2024-03, which becomes effective for fiscal years beginning after December 15, 2026, and interim periods within fiscal years beginning after December 15, 2027. The standard requires companies to disclose disaggregated information about certain income statement expense line items. The company does not expect the standard to have a material effect on its consolidated financial statements and has begun evaluating disclosure presentation alternatives. Note 5 Lease Commitments The company enters into leasing arrangements as a lessee; any lessor arrangements are not significant. Operating lease arrangements mainly involve land, bareboat charters, terminals, drill ships, drilling rigs, time chartered vessels, office buildings and warehouses, and exploration and production equipment. Finance leases primarily include facilities, vessels and office buildings. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 64 Details of the right-of-use assets and lease liabilities for operating and finance leases, including the balance sheet presentation, are as follows: At December 31, 2024 At December 31, 2023 Operating Leases Finance Leases Operating Leases Finance Leases Deferred charges and other assets $ 5,315 $ — $ 5,422 $ — Properties, plant and equipment, net — 570 — 583 Right-of-use assets* $ 5,315 $ 570 $ 5,422 $ 583 Accrued liabilities $ 1,519 $ — $ 1,538 $ — Short-term debt — 58 — 60 Current lease liabilities 1,519 58 1,538 60 Deferred credits and other noncurrent obligations 3,551 — 3,696 — Long-term debt — 546 — 574 Noncurrent lease liabilities 3,551 546 3,696 574 Total lease liabilities $ 5,070 $ 604 $ 5,234 $ 634 Weighted-average remaining lease term (in years) 6.3 13.2 6.7 12.6 Weighted-average discount rate 3.7 % 4.6 % 3.3 % 4.5 % * Includes non-cash additions of $2,205 and $40 in 2024, and $2,556 and $233 in 2023 for right-of-use assets obtained in exchange for new and modified lease liabilities for operating and finance leases, respectively. Total lease costs consist of both amounts recognized in the Consolidated Statement of Income during the period and amounts capitalized as part of the cost of another asset. Total lease costs incurred for operating and finance leases were as follows: Year-ended December 31 2024 2023 2022 Operating lease costs* $ 3,447 $ 2,984 $ 2,359 Finance lease costs 83 52 57 Total lease costs $ 3,530 $ 3,036 $ 2,416 * Includes variable and short-term lease costs. Cash paid for amounts included in the measurement of lease liabilities was as follows: Year-ended December 31 2024 2023 2022 Operating cash flows from operating leases $ 2,468 $ 2,271 $ 1,892 Investing cash flows from operating leases 979 713 467 Operating cash flows from finance leases 26 15 18 Financing cash flows from finance leases 67 42 44 At December 31, 2024, the estimated future undiscounted cash flows for operating and finance leases were as follows: At December 31, 2024 Operating Leases Finance Leases Year 2025 $ 1,665 $ 83 2026 1,162 80 2027 833 73 2028 555 69 2029 275 64 Thereafter 1,276 445 Total $ 5,766 $ 814 Less: Amounts representing interest 696 210 Total lease liabilities $ 5,070 $ 604 Additionally, the company has $403 in future undiscounted cash flows for operating leases not yet commenced. These leases are primarily for drilling rigs, time chartered vessels, exploration and production equipment and storage tanks. For Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 65 those leasing arrangements where the underlying asset is not yet constructed, the lessor is primarily involved in the design and construction of the asset. Note 6 Summarized Financial Data – Chevron U.S.A. Inc. Chevron U.S.A. Inc. (CUSA) is a major subsidiary of Chevron Corporation. CUSA and its subsidiaries manage and operate most of Chevron’s U.S. businesses. Assets include those related to the exploration and production of crude oil, natural gas, and natural gas liquids (NGLs) and those associated with the refining, marketing, supply and distribution of products derived from petroleum, excluding most of the regulated pipeline operations of Chevron. CUSA also holds the company’s investment in the Chevron Phillips Chemical Company LLC joint venture, which is accounted for using the equity method. The summarized financial information for CUSA and its consolidated subsidiaries is as follows: Year ended December 31 2024 2023 2022 Sales and other operating revenues $ 149,925 $ 152,347 $ 183,032 Total costs and other deductions 145,582 144,482 166,955 Net income (loss) attributable to CUSA 4,151 4,598 13,315 At December 31 2024 2023 Current assets $ 20,153 $ 19,489 Other assets 58,485 54,460 Current liabilities 25,825 20,624 Other liabilities 21,455 22,227 Total CUSA net equity $ 31,358 $ 31,098 Memo: Total debt $ 8,917 $ 9,740 Note 7 Summarized Financial Data – Tengizchevroil LLP Chevron has a 50 percent equity ownership interest in Tengizchevroil LLP (TCO). Refer to Note 15 Investments and Advances for a discussion of TCO operations. Summarized financial information for 100 percent of TCO is presented in the table below: Year ended December 31 2024 2023 2022 Sales and other operating revenues $ 18,872 $ 19,758 $ 23,975 Costs and other deductions 10,616 10,193 11,956 Net income attributable to TCO 5,779 6,569 8,566 At December 31 2024 2023 Current assets $ 4,753 $ 3,919 Other assets 58,057 57,454 Current liabilities 3,203 2,372 Other liabilities 12,459 12,782 Total TCO net equity $ 47,148 $ 46,219 Note 8 Restructuring and Reorganization Costs In 2024, the company announced plans to achieve $2-3 billion in structural cost reductions by the end of 2026. As a result, the company recorded severance accruals during fourth quarter 2024 for employee reduction programs related to an enterprise-wide restructuring, which is expected to be substantially completed by the end of 2026. A charge of $980 was recorded in fourth quarter 2024, with $706 reported as “Operating expenses” and $274 reported as “Selling, general and administrative expenses” on the Consolidated Statement of Income. Approximately $240 is associated with employee reductions in U.S. Upstream, $197 in International Upstream, $247 in U.S. Downstream, $22 in International Downstream and $274 in All Other. Approximately $560 is classified as current and $430 is classified as long-term on the Consolidated Balance Sheet at December 31, 2024. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 66 The following table summarizes the accrued severance liability. Amounts Before Tax Balance at January 1, 2024 $ 6 Accruals/Adjustments 987 Payments (3) Balance at December 31, 2024 $ 990 Note 9 Fair Value Measurements Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets. The fair values reflect the cash that would have been received if the instruments were sold at December 31, 2024. Derivatives The company records most of its derivative instruments – other than any commodity derivative contracts that are accounted for as normal purchase and normal sale – on the Consolidated Balance Sheet at fair value, with the offsetting amount to the Consolidated Statement of Income. The company designates certain derivative instruments as cash flow hedges, if applicable. Derivatives classified as Level 1 include futures, swaps and options contracts valued using quoted prices from active markets such as the New York Mercantile Exchange. Derivatives classified as Level 2 include swaps, options and forward contracts, the fair values of which are obtained from third-party broker quotes, industry pricing services and exchanges. The company obtains multiple sources of pricing information for the Level 2 instruments. Since this pricing information is generated from observable market data, it has historically been very consistent. The company does not materially adjust this information. Properties, Plant and Equipment In 2024, the company did not have any individually material impairments of long lived assets measured at fair value on a nonrecurring basis. In 2023, the company impaired a portion of its U.S. upstream assets, primarily in California, due to continuing regulatory challenges in the state that have resulted in lower anticipated future investment levels in its business plans. Investments and Advances The company did not have any material impairments of investments and advances measured at fair value on a nonrecurring basis to report in 2024 or 2023. The tables below show the fair value hierarchy for assets and liabilities measured at fair value on a recurring and nonrecurring basis at December 31, 2024 and 2023. Assets and Liabilities Measured at Fair Value on a Recurring Basis At December 31, 2024 At December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Marketable securities $ — $ — $ — $ — $ 45 $ 45 $ — $ — Derivatives - not designated 137 127 10 — 152 24 128 — Derivatives - designated — — — — 7 7 — — Total assets at fair value $ 137 $ 127 $ 10 $ — $ 204 $ 76 $ 128 $ — Derivatives - not designated 136 47 89 — 262 160 102 — Derivatives - designated 17 17 — — — — — — Total liabilities at fair value $ 153 $ 64 $ 89 $ — $ 262 $ 160 $ 102 $ — Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis At December 31 At December 31 Before-Tax Loss Before-Tax Loss Total Level 1 Level 2 Level 3 Year 2024 Total Level 1 Level 2 Level 3 Year 2023 Properties, plant and equipment, net (held and used) $ 324 $ — $ — $ 324 $ 226 $ 484 $ — $ — $ 484 $ 2,175 Properties, plant and equipment, net (held for sale) 616 — 616 — 274 — — — — 5 Investments and advances 36 — 36 — 289 207 5 165 37 352 Total nonrecurring assets at fair value $ 976 $ — $ 652 $ 324 $ 789 $ 691 $ 5 $ 165 $ 521 $ 2,532 Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 67 At year-end 2024, the company had assets measured at fair value Level 3 using unobservable inputs of $324. The carrying value of these assets were written down to fair value based on estimates derived from discounted cash flow models. Cash flows were determined using estimates of future production, an outlook of future price based on published prices and a discount rate believed to be consistent with those used by principal market participants. Assets and Liabilities Not Required to Be Measured at Fair Value The company holds cash equivalents in U.S. and non- U.S. portfolios. The instruments classified as cash equivalents are primarily bank time deposits with maturities of 90 days or less and money market funds. “Cash and cash equivalents” had carrying/fair values of $6,781 and $8,178 at December 31, 2024, and December 31, 2023, respectively. The fair values of cash and cash equivalents are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at December 31, 2024. “Cash and cash equivalents” do not include investments with a carrying/fair value of $1,481 and $1,097 at December 31, 2024, and December 31, 2023, respectively. At December 31, 2024, these investments are classified as Level 1 and include restricted funds mainly related to certain upstream decommissioning activities, a tax-deferred transaction and financing programs. Long-term debt, excluding finance lease liabilities, of $10,810 and $14,612 at December 31, 2024, and December 31, 2023, respectively, had estimated fair values of $9,791 and $13,709, respectively. Long-term debt primarily includes corporate issued bonds. At December 31, 2024, the fair value of corporate bonds is $9,243 and classified as Level 1 and the fair value of other long-term debt classified as Level 2 is $548. The carrying values of other short-term financial assets and liabilities on the Consolidated Balance Sheet approximate their fair values. Fair value remeasurements of other financial instruments at December 31, 2024 and 2023, were not material. Note 10 Financial and Derivative Instruments Derivative Commodity Instruments The company’s derivative commodity instruments principally include crude oil, natural gas, liquefied natural gas and refined product futures, swaps, options, and forward contracts. The company applies cash flow hedge accounting to certain commodity transactions, where appropriate, to manage the market price risk associated with forecasted sales of crude oil. The company’s derivatives are not material to the company’s financial position, results of operations or liquidity. The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodity derivative activities. The company uses derivative commodity instruments traded on the New York Mercantile Exchange and on electronic platforms of the Inter-Continental Exchange and Chicago Mercantile Exchange. In addition, the company enters into swap contracts and option contracts principally with major financial institutions and other oil and gas companies in the “over- the-counter” markets, which are governed by International Swaps and Derivatives Association agreements and other master netting arrangements. Depending on the nature of the derivative transactions, bilateral collateral arrangements may also be required. Derivative instruments measured at fair value at December 31, 2024, 2023 and 2022, and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are as follows: Consolidated Balance Sheet: Fair Value of Derivatives At December 31 Type of Contract Balance Sheet Classification 2024 2023 Commodity Accounts and notes receivable $ 122 $ 151 Commodity Long-term receivables, net 15 8 Total assets at fair value $ 137 $ 159 Commodity Accounts payable $ 127 $ 216 Commodity Deferred credits and other noncurrent obligations 26 46 Total liabilities at fair value $ 153 $ 262 Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 68 Consolidated Statement of Income: The Effect of Derivatives Gain/(Loss) Year ended December 31 Type of Contract Statement of Income Classification 2024 2023 2022 Commodity Sales and other operating revenues $ (57) $ (304) $ (651) Commodity Purchased crude oil and products 28 (154) (226) Commodity Other income (loss) 6 (47) 10 $ (23) $ (505) $ (867) The amount reclassified from AOCL to “Sales and other operating revenues” from designated hedges was a net loss of $25 in 2024, compared with a net loss of $33 in the prior year. At December 31, 2024, before-tax deferred losses in AOCL related to outstanding crude oil price hedging contracts were $17, all of which is expected to be reclassified into earnings during the next 12 months as the hedged crude oil sales are recognized in earnings. The table below represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at December 31, 2024 and 2023. Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities Gross Amounts Recognized Gross Amounts Offset Net Amounts Presented Gross Amounts Not Offset Net Amounts At December 31, 2024 Derivative Assets - not designated $ 1,895 $ 1,758 $ 137 $ 3 $ 134 Derivative Assets - designated $ — $ — $ — $ — $ — Derivative Liabilities - not designated $ 1,894 $ 1,758 $ 136 $ 2 $ 134 Derivative Liabilities - designated $ 17 $ — $ 17 $ — $ 17 At December 31, 2023 Derivative Assets - not designated $ 2,394 $ 2,242 $ 152 $ 4 $ 148 Derivative Assets - designated $ 8 $ 1 $ 7 $ — $ 7 Derivative Liabilities - not designated $ 2,504 $ 2,242 $ 262 $ 15 $ 247 Derivative Liabilities - designated $ 1 $ 1 $ — $ — $ — Derivative assets and liabilities are classified on the Consolidated Balance Sheet as “Accounts and notes receivable,” “Long-term receivables,” “Accounts payable,” and “Deferred credits and other noncurrent obligations.” Amounts not offset on the Consolidated Balance Sheet represent positions that do not meet all the conditions for “a right of offset.” Concentrations of Credit Risk The company’s financial instruments that are exposed to concentrations of credit risk consist primarily of its cash equivalents, marketable securities, derivative financial instruments and trade receivables. The company’s short-term investments are placed with a wide array of financial institutions with high credit ratings. Company investment policies limit the company’s exposure both to credit risk and to concentrations of credit risk. Similar policies on diversification and creditworthiness are applied to the company’s counterparties in derivative instruments. For a discussion of credit risk on trade receivables, see Note 28 Financial Instruments - Credit Losses. Note 11 Assets Held for Sale At December 31, 2024, the company classified $481 of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream and downstream operations that were sold in early 2025, or are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2024 were not material. Note 12 Equity Retained earnings at December 31, 2024 and 2023, included $35,349 and $34,359, respectively, for the company’s share of undistributed earnings of equity affiliates. At December 31, 2024, about 96 million shares of Chevron’s common stock remained available for issuance from the 104 million shares that were reserved for issuance under the 2022 Chevron Long-Term Incentive Plan. In addition, 559,513 shares remain available for issuance from the 1,600,000 shares of the company’s common stock that were reserved for awards under the Chevron Corporation Non-Employee Directors’ Equity Compensation and Deferral Plan. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 69 Note 13 Earnings Per Share Basic earnings per share (EPS) is based upon “Net Income (Loss) Attributable to Chevron Corporation” (“earnings”) and includes the effects of deferrals of salary and other compensation awards that are invested in Chevron stock units by certain officers and employees of the company. Diluted EPS includes the effects of these items as well as the dilutive effects of outstanding stock options awarded under the company’s stock option programs (refer to Note 22 Stock Options and Other Share-Based Compensation). The table below sets forth the computation of basic and diluted EPS: Year ended December 31 2024 2023 2022 Basic EPS Calculation Earnings available to common stockholders - Basic* $ 17,661 $ 21,369 $ 35,465 Weighted-average number of common shares outstanding 1,810 1,873 1,931 Add: Deferred awards held as stock units — — — Total weighted-average number of common shares outstanding 1,810 1,873 1,931 Earnings per share of common stock - Basic $ 9.76 $ 11.41 $ 18.36 Diluted EPS Calculation Earnings available to common stockholders - Diluted* $ 17,661 $ 21,369 $ 35,465 Weighted-average number of common shares outstanding 1,810 1,873 1,931 Add: Deferred awards held as stock units — — — Add: Dilutive effect of employee stock-based awards 7 7 9 Total weighted-average number of common shares outstanding 1,817 1,880 1,940 Earnings per share of common stock - Diluted $ 9.72 $ 11.36 $ 18.28 * There was no effect of dividend equivalents paid on stock units or dilutive impact of employee stock-based awards on earnings. Note 14 Operating Segments and Geographic Data Although each subsidiary of Chevron is responsible for its own affairs, Chevron Corporation manages its investments in these subsidiaries and their affiliates. The investments are grouped into two business segments, Upstream and Downstream, representing the company’s “reportable segments” and “operating segments.” Upstream operations consist primarily of exploring for, developing, producing and transporting crude oil and natural gas; liquefaction, transportation and regasification associated with LNG; transporting crude oil by major international oil export pipelines; processing, transporting, storage and marketing of natural gas; carbon capture and storage; and a gas-to-liquids plant. Downstream operations consist primarily of refining of crude oil into petroleum products; marketing of crude oil, refined products, and lubricants; manufacturing and marketing of renewable fuels; transporting of crude oil and refined products by pipeline, marine vessel, motor equipment and rail car; and manufacturing and marketing of commodity petrochemicals, plastics for industrial uses, and fuel and lubricant additives. All Other activities of the company include worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, and technology activities. The company’s segments are managed by “segment managers” who report to the “chief operating decision maker” (CODM), which is comprised of the company’s Executive Committee, as referenced in Item 10 Executive Officers. The segments represent components of the company that engage in activities from which revenues are earned and expenses are incurred. Each segment has discrete financial information available. The CODM regularly reviews the operating results of these segments to assess their performance and make decisions about resources to be allocated to the segments. The company's primary country of operation is the United States of America, its country of domicile, while other components of the company's operations are reported as “International” (outside the United States). Segment Sales and Other Operating Revenues Products are transferred between operating segments at internal product values that approximate market prices. Revenues for the upstream segment are derived primarily from the production and sale of crude oil, natural gas and NGLs, as well as the sale of third-party production of natural gas. Revenues for the downstream segment are derived from the refining and marketing of petroleum products such as gasoline, jet fuel, gas oils, lubricants, residual fuel oils and other products derived from crude oil. This segment also generates revenues from the manufacture and sale of fuel and lubricant additives, renewable fuels, and the transportation and trading of refined products and crude oil. “All Other” activities include revenues from insurance operations, real estate activities and technology companies. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 70 Segment Expenses Purchased crude oil and products, operating and selling, general and administrative (SG&A) expense, and depreciation, depletion and amortization are the company’s significant segment expenses. Operating and SG&A expenses include transportation, employee costs, service and fees, fuel and utilities, materials and supplies, SG&A expenses and other components of periodic benefit costs. Other costs and deductions primarily represent taxes other than on income, exploration expense and interest and debt expenses. Segment Earnings The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Non-billable costs remain at the corporate level in “All Other.” Segmented income statements for the years ended December 31, 2024, 2023 and 2022 are presented below: Upstream Downstream Segment Total All Other Total Year Ended December 31, 2024 U.S. Int'l. U.S. Int'l. Sales and other operating revenues before elimination $ 44,302 $ 43,466 $ 80,417 $ 77,430 $ 245,615 $ 617 $ 246,232 Intersegment revenue elimination (29,662) (11,258) (9,745) (1,668) (52,333) (485) (52,818) Sales and Other Operating Revenues 14,640 32,208 70,672 75,762 193,282 132 193,414 Income (loss) from equity affiliates (62) 3,642 1,010 10 4,600 (4) 4,596 Other income (loss)1 346 3,460 358 96 4,260 522 4,782 Total Revenues and Other Income 14,924 39,310 72,040 75,868 202,142 650 202,792 Intersegment product transfers2 25,305 4,190 (26,845) (2,833) (183) 183 — Less expenses: Purchased crude oil and products 13,326 9,445 33,514 62,921 119,206 — 119,206 Operating and SG&A expenses 7,708 6,412 9,425 6,034 29,579 2,914 32,493 Depreciation, depletion and amortization 7,562 7,935 1,091 360 16,948 334 17,282 Other costs and deductions3 1,805 1,156 550 2,071 5,582 723 6,305 Total Costs and Other Deductions 30,401 24,948 44,580 71,386 171,315 3,971 175,286 Income Tax Expense (Benefit) 2,198 7,548 84 397 10,227 (470) 9,757 Less: Net income (loss) attributable to non- controlling interests 28 4 — 56 88 — 88 Net Income (Loss) Attributable to Chevron Corporation $ 7,602 $ 11,000 $ 531 $ 1,196 $ 20,329 $ (2,668) $ 17,661 Values have been adjusted for eliminations, unless otherwise specified. 1 Includes interest income of $296 in “All Other.” 2 Valuation of product transfers between operating segments. 3 Includes interest expense of $539 in “All Other.” Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 71 Upstream Downstream Segment Total All Other Total Year ended December 31, 2023 U.S. Int'l. U.S. Int'l. Sales and other operating revenues before elimination $ 40,115 $ 43,805 $ 83,567 $ 78,058 $ 245,545 $ 597 $ 246,142 Intersegment revenue elimination (26,307) (11,871) (8,793) (1,794) (48,765) (464) (49,229) Sales and Other Operating Revenues 13,808 31,934 74,774 76,264 196,780 133 196,913 Income (loss) from equity affiliates (387) 4,272 736 519 5,140 (9) 5,131 Other income (loss)1 (2,536) 776 444 39 (1,277) 182 (1,095) Total Revenues and Other Income 10,885 36,982 75,954 76,822 200,643 306 200,949 Intersegment product transfers2 23,665 4,274 (23,887) (4,184) (132) 132 — Less expenses: Purchased crude oil and products 13,019 7,270 37,176 61,731 119,196 — 119,196 Operating and SG&A expenses 6,879 5,837 8,432 6,058 27,206 2,034 29,240 Depreciation, depletion and amortization 7,666 8,109 931 301 17,007 319 17,326 Other costs and deductions3 1,676 1,010 515 1,782 4,983 620 5,603 Total Costs and Other Deductions 29,240 22,226 47,054 69,872 168,392 2,973 171,365 Income Tax Expense (Benefit) 1,141 5,733 1,109 519 8,502 (329) 8,173 Less: Net income (loss) attributable to non- controlling interests 21 7 — 14 42 — 42 Net Income (Loss) Attributable to Chevron Corporation $ 4,148 $ 13,290 $ 3,904 $ 2,233 $ 23,575 $ (2,206) $ 21,369 Values have been adjusted for eliminations, unless otherwise specified. 1 Includes interest income of $491 in “All Other.” 2 Valuation of product transfers between operating segments. 3 Includes interest expense of $432 in “All Other.” Upstream Downstream Segment Total All Other Total Year Ended December 31, 2022 U.S. Int'l. U.S. Int'l. Sales and other operating revenues before elimination $ 50,822 $ 56,156 $ 91,824 $ 87,741 $ 286,543 $ 518 $ 287,061 Intersegment revenue elimination (29,870) (13,815) (5,529) (1,728) (50,942) (402) (51,344) Sales and Other Operating Revenues 20,952 42,341 86,295 86,013 235,601 116 235,717 Income (loss) from equity affiliates (22) 6,648 1,003 962 8,591 (6) 8,585 Other income (loss)1 103 1,272 527 (8) 1,894 56 1,950 Total Revenues and Other Income 21,033 50,261 87,825 86,967 246,086 166 246,252 Intersegment product transfers2 29,801 7,078 (31,245) (5,706) (72) 72 — Less expenses: Purchased crude oil and products 21,008 12,717 40,483 71,208 145,416 — 145,416 Operating and SG&A expenses 6,799 6,810 7,829 5,094 26,532 2,789 29,321 Depreciation, depletion and amortization 5,012 9,830 913 311 16,066 253 16,319 Other costs and deductions3 1,699 1,230 446 1,515 4,890 632 5,522 Total Costs and Other Deductions 34,518 30,587 49,671 78,128 192,904 3,674 196,578 Income Tax Expense (Benefit) 3,678 9,055 1,515 280 14,528 (462) 14,066 Less: Net income (loss) attributable to non- controlling interests 17 34 — 92 143 — 143 Net Income (Loss) Attributable to Chevron Corporation $ 12,621 $ 17,663 $ 5,394 $ 2,761 $ 38,439 $ (2,974) $ 35,465 Values have been adjusted for eliminations, unless otherwise specified. 1 Includes interest income of $261 in “All Other.” 2 Valuation of product transfers between operating segments. 3 Includes interest expense of $476 in “All Other.” Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 72 Segment Assets Segment assets do not include intercompany investments or receivables. Assets at year-end 2024 and 2023 are as follows: At December 31 2024 2023 Upstream United States $ 60,914 $ 58,750 International 123,343 131,685 Goodwill 4,226 4,370 Total Upstream 188,483 194,805 Downstream United States 34,253 33,066 International 22,165 21,070 Goodwill 352 352 Total Downstream 56,770 54,488 Total Segment Assets 245,253 249,293 All Other United States 8,382 10,292 International 3,303 2,047 Total All Other 11,685 12,339 Total Assets – United States 103,549 102,108 Total Assets – International 148,811 154,802 Goodwill 4,578 4,722 Total Assets $ 256,938 $ 261,632 Other Segment Information Additional information for the segmentation of major equity affiliates is contained in Note 15 Investments and Advances. Information related to properties, plant and equipment by segment is contained in Note 18 Properties, Plant and Equipment. Information related to unusual items is contained in Note 27 Other Financial Information. Note 15 Investments and Advances Equity in earnings, together with investments in and advances to companies accounted for using the equity method and other investments accounted for at or below cost, is shown in the following table. For certain equity affiliates, Chevron pays its share of some income taxes directly. For such affiliates, the equity in earnings does not include these taxes, which are reported on the Consolidated Statement of Income as “Income tax expense.” Investments and Advances Equity in Earnings At December 31 Year ended December 31 2024 2023 2024 2023 2022 Upstream Tengizchevroil $ 27,368 $ 26,954 $ 3,033 $ 3,375 $ 4,386 Caspian Pipeline Consortium 719 797 180 158 128 Angola LNG Limited 1,665 1,762 405 513 1,857 Other 1,716 2,106 (38) (161) 255 Total Upstream 31,468 31,619 3,580 3,885 6,626 Downstream Chevron Phillips Chemical Company LLC 8,571 7,765 903 608 867 GS Caltex Corporation 4,144 4,309 58 437 874 Other 2,432 2,426 60 210 224 Total Downstream 15,147 14,500 1,021 1,255 1,965 All Other Other 3 (6) (5) (9) (6) Total equity method $ 46,618 $ 46,113 $ 4,596 $ 5,131 $ 8,585 Other non-equity method investments 820 699 Total investments and advances $ 47,438 $ 46,812 Total United States $ 11,960 $ 10,985 $ 944 $ 340 $ 975 Total International $ 35,478 $ 35,827 $ 3,652 $ 4,791 $ 7,610 Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 73 Descriptions of major equity affiliates and non-equity investments, including significant differences between the company’s carrying value of its investments and its underlying equity in the net assets of the affiliates, are as follows: Tengizchevroil Chevron has a 50 percent equity ownership interest in TCO, which operates the Tengiz and Korolev crude oil fields in Kazakhstan. At December 31, 2024, the company’s carrying value of its investment in TCO was about $73 higher than the amount of underlying equity in TCO’s net assets. This difference results from Chevron acquiring a portion of its interest in TCO at a value greater than the underlying book value for that portion of TCO’s net assets. Included in the investment is a loan to TCO to fund the development of the Wellhead Pressure Management Project (WPMP) and Future Growth Project (FGP) with a principal balance of $4,500. Caspian Pipeline Consortium Chevron has a 15 percent interest in the Caspian Pipeline Consortium, which provides the critical export route for crude oil from both TCO and Karachaganak. Angola LNG Limited Chevron has a 36.4 percent interest in Angola LNG Limited, which processes and liquefies natural gas produced in Angola for delivery to international markets. Chevron Phillips Chemical Company LLC Chevron owns 50 percent of Chevron Phillips Chemical Company LLC. Included in the investment balance is a loan with a principal balance of $669 to fund a portion of the Golden Triangle Polymers Project in Orange, Texas, in which Chevron Phillips Chemical Company LLC owns 51 percent. GS Caltex Corporation Chevron owns 50 percent of GS Caltex Corporation, a joint venture with GS Energy in South Korea. The joint venture imports, produces and markets petroleum products, petrochemicals and lubricants. Other Information “Sales and other operating revenues” on the Consolidated Statement of Income includes $13,850, $13,623 and $16,286 with affiliated companies for 2024, 2023 and 2022, respectively. “Purchased crude oil and products” includes $6,547, $7,404 and $10,171 with affiliated companies for 2024, 2023 and 2022, respectively. “Accounts and notes receivable” on the Consolidated Balance Sheet includes $1,258 and $1,480 due from affiliated companies at December 31, 2024 and 2023, respectively. “Accounts payable” includes $556 and $591 due to affiliated companies at December 31, 2024 and 2023, respectively. The following table provides summarized financial information on a 100 percent basis for all equity affiliates as well as Chevron’s total share, which includes Chevron’s net loans to affiliates of $4,731, $4,494 and $4,278 at December 31, 2024, 2023 and 2022, respectively. Affiliates Chevron Share Year ended December 31 2024 2023 2022 2024 2023 2022 Total revenues $ 46,081 $ 49,306 $ 100,184 $ 21,765 $ 23,217 $ 48,323 Income before income tax expense* 13,127 15,304 23,811 6,088 7,209 10,876 Net income attributable to affiliates 10,253 11,618 19,077 4,802 5,485 8,595 At December 31 Current assets $ 21,697 $ 22,772 $ 26,632 $ 9,323 $ 10,110 $ 11,671 Noncurrent assets 104,396 105,965 101,557 49,435 48,753 46,428 Current liabilities 12,906 14,085 16,319 5,084 6,698 7,708 Noncurrent liabilities 22,651 23,797 22,943 7,278 6,342 5,980 Total affiliates’ net equity $ 90,536 $ 90,855 $ 88,927 $ 46,396 $ 45,823 $ 44,411 * Chevron’s net income attributable to affiliates is recorded in the company’s before-tax consolidated earnings in accordance with U.S. Generally Accepted Accounting Principles. The total income tax expense recorded by the company’s equity affiliates in 2024 was $2,874, with Chevron’s share being $1,286. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 74 Note 16 Litigation Climate Change Governmental and other plaintiffs in various jurisdictions across the United States have brought legal proceedings against fossil fuel producing companies, including Chevron entities, purporting to seek legal and equitable relief to address alleged impacts of climate change. Chevron entities are or were among the codefendants in 32 separate lawsuits filed by various U.S. cities and counties, four U.S. states, the District of Columbia, the Commonwealth of Puerto Rico, two Native American tribes, and a trade group in both federal and state courts.3 The lawsuits have asserted various causes of action, including public nuisance, private nuisance, failure to warn, fraud, conspiracy to commit fraud, design defect, product defect, trespass, negligence, impairment of public trust, equitable relief for pollution, impairment and destruction of natural resources, unjust enrichment, violations of consumer and environmental protection statutes, violations of unfair competition statutes, violations of a federal antitrust statute, and violations of federal and state RICO statutes, based upon, among other things, the company’s production of oil and gas products and alleged misrepresentations or omissions relating to climate change risks associated with those products. Further such proceedings are likely to be brought by other parties. While defendants have sought to remove cases filed in state court to federal court, most of those cases have been remanded to state court and the U.S. Supreme Court has denied petitions for writ of certiorari on jurisdictional questions to date. The U.S. Supreme Court has also denied petitions for certiorari to review a decision from the Hawaii Supreme Court allowing claims brought by the City and County of Honolulu to proceed past the pleadings. The unprecedented legal theories set forth in these proceedings include claims for damages (both compensatory and punitive), injunctive and other forms of equitable relief, including without limitation abatement, contribution to abatement funds, disgorgement of profits and equitable relief for pollution, impairment and destruction of natural resources, civil penalties and liability for fees and costs of suits. Due to the unprecedented nature of the suits, the company is unable to estimate any range of possible liability, but given the uncertainty of litigation there can be no assurance that the cases will not have a material adverse effect on the company’s results of operations and financial condition. Management believes that these proceedings are legally and factually meritless and detract from constructive efforts to address the important policy issues presented by climate change and will vigorously defend against such proceedings. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts 3 The cases are: Municipality of Bayamon et al. v. Exxon Mobil Corp., et al., No. 22-cv-1550 (D.P.R.); City of Annapolis v. BP P.L.C., et al., No. C-02- CV-21-000250 (Md. Cir. Ct.) (dismissed on the merits, Plaintiff’s appeal pending); Anne Arundel County v. BP P.L.C., et al., No. C-02-CV-21-000565 (Md. Cir. Ct.) (dismissed on the merits, Plaintiff’s appeal pending); Mayor and City Council of Baltimore v. BP P.L.C., et al., No. 24-C-18-004219 (Md. Cir. Ct.) (dismissed on the merits, Plaintiff’s appeal pending); People ex rel. Bonta v. Exxon Mobil Corp., et al., No. CGC-23-609134 (Cal. Super. Ct.); Bucks County v. BP P.L.C., et al., No. 2024-01836 (Pa. Ct. Com. Pl.); City of Charleston v. Brabham Oil Co., et al., No. 2020-CP-10-3975 (S.C. Ct. of Com. Pl.); District of Columbia v. Exxon Mobil Corp., et al., No. 2020-CA-002892-B (D.C. Super. Ct.); Delaware ex rel. Jennings v. BP America Inc., et al., C.A. No. N20C-09-097 (Del.Super. Ct.); City of Hoboken v. Exxon Mobil Corp., et al., No. HUD-L-003179-20 (N.J. Super. Ct.); City and County of Honolulu, et al. v. Sunoco LP, et al., No. 1CCV-20-0000380 (Haw. Cir. Ct.); City of Imperial Beach v. Chevron Corp., et al., No. C17-01227 (Cal. Super. Ct.); King County v. BP P.L.C., et al., No. 18-2-11859-0 (Wash. Super. Ct.) (voluntarily dismissed); Makah Indian Tribe v. Exxon Mobil Corp., et al., No. 23-25216-1-SEA (Wash. Super. Ct.); County of Marin v. Chevron Corp., et al., No. 17-cv-02586 (Cal. Super. Ct.); County of Maui v. Sunoco LP, et al., No. 2CCV-20-0000283 (Haw. Cir. Ct.); County of Multnomah v. Exxon Mobil Corp., et al., No. 23-cv-25164 (Or. Cir. Ct.); Municipality of San Juan, Puerto Rico v. Exxon Mobil Corp., et al., No. 23-cv-01608 (D.P.R.); City of Oakland v. BP P.L.C., et al., No. RG17875889 (Cal. Super. Ct.); Platkin, et al. v. Exxon Mobil Corp., et al., No. MER-L-001797-22 (N.J. Super. Ct.) (dismissed on the merits, appeal may be filed); Estado Libre Asociado de Puerto Rico [Commonwealth of Puerto Rico] v. Exxon Mobil Corp., et al., No. SJ2024CV06512 (Tribunal de Primera Instancia, Estado Libre Asociado de P.R.) [P.R. Ct. of First Instance, Commonwealth of P.R.]; City of New York v. Chevron Corp., et al., No. 18-cv-00182 (S.D.N.Y.) (dismissed on the merits); Pacific Coast Federation of Fishermen’s Associations, Inc. v. Chevron Corp., et al., No. CGC-18-571285 (Cal. Super. Ct.) (voluntarily dismissed); State of Rhode Island v. Chevron Corp., et al., C.A. No. PC-2018-4716 (R.I. Super. Ct.); City of Richmond v. Chevron Corp., et al., No. C18-00055 (Cal. Super. Ct.); City of San Francisco v. BP P.L.C., et al., No. CGC-17-561370 (Cal. Super. Ct.); County of San Mateo v. Chevron Corp., et al., No. 17- CIV-03222 (Cal. Super. Ct.); City of Santa Cruz v. Chevron Corp., et al., No. 17-CV-03243 (Cal. Super. Ct.); County of Santa Cruz v. Chevron Corp., et al., No. 17-CV-03242 (Cal. Super. Ct.); Shoalwater Bay Indian Tribe v. Exxon Mobil Corp., et al., No. 23-2-25215-2-SEA (Wash. Super. Ct.); City of Chicago v. BP P.L.C., et al., No. 2024CH01024 (Ill. Cir. Ct.); Maine v. BP P.L.C. et al., No. PORSC-CV-24-442 (Me. Super. Ct.). Chevron Corporation 2024 Annual Report 75 Louisiana Seven coastal parishes and the State of Louisiana have filed lawsuits in Louisiana against numerous oil and gas companies seeking damages for coastal erosion in or near oil fields located within Louisiana’s coastal zone under Louisiana’s State and Local Coastal Resources Management Act (SLCRMA). Chevron entities are defendants in 37 of these cases.4 The lawsuits allege that the defendants’ historical operations were conducted without necessary permits or failed to comply with permits obtained and seek damages and other relief, including the costs of restoring coastal wetlands allegedly impacted by oil field operations. Further such proceedings may be brought by other parties. The Supreme Court denied a petition for writ of certiorari on jurisdictional questions impacting certain of these cases, and those cases have been or will be remanded to Louisiana state court, one of which has been set for trial and is scheduled to begin in March 2025. Federal jurisdictional questions are still being decided for the remaining cases in the United States federal court system. Due to the unprecedented nature of the suits, the company is unable to estimate any range of possible liability, but given the uncertainty of litigation there can be no assurance that the cases will not have a material adverse effect on the company’s results of operations and financial condition. Management believes that the claims lack legal and factual merit and will continue to vigorously defend against such proceedings. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts 4 The cases are: Jefferson Parish v. Atlantic Richfield Company, et al., No. 732-768 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. Chevron U.S.A. Holdings, Inc., et al., No. 732-769 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. Destin Operating Company, Inc., et al., No. 732-770 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. Canlan Oil Company, et al., No. 732-771 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. Anadarko E&P Onshore LLC, et al., No. 732-772 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. ExxonMobil Corporation, et al., No. 732-774 (24th Jud. Dist. Ct., Jefferson Par.); Jefferson Parish v. Equitable Petroleum Corporation, et al., No. 732-775 (24th Jud. Dist. Ct., Jefferson Par.); Plaquemines Parish v. ConocoPhillips Co., et al., No. 60-982 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. HHE Energy Co., et al., No. 60-983 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Exchange Oil & Gas Corp., et al., No. 60-984 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. LLOG Exploration & Production Co., et al., No. 60-985 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Equitable Petroleum Corporation, et al., No. 60-986 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. June Energy, et al., No. 60-987 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Linder Oil Company, et al., No. 60-988 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Riverwood Production Company, et al., No. 60-989 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Helis Oil & Gas Company, et al., No. 60-990 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Northcoast Oil Company, et al., No. 60-992 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Goodrich Petroleum Company, L.L.C., et al., No. 60-994 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Devon Energy Production Company, L.P., et al., No. 60-995 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Rozel Operating Co., et al., No. 60-996 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Palm Energy Offshore, L.L.C., et al., No. 60-997 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Great Southern Oil & Gas Company, Inc., et al., No. 60-998 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Hilcorp Energy Company, et al., No. 60-999 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Apache Oil Corporation, et al., No. 61-000 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. Campbell Energy Corporation, et al., No. 61-001 (25th Jud. Dist. Ct., Plaquemines Par.); Plaquemines Parish v. TotalPetrochemicals & Refining USA, Inc., et al., No. 61-002 (25th Jud. Dist. Ct., Plaquemines Par.); Cameron Parish v. Alpine Exploration Companies, Inc., et al., No. 10-19580 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. Apache Corporation (of Delaware), et al., No. 10-19579 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. Ballard Exploration Company, Inc., et al., No. 10-19574 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. Bay Coquille, Inc., et al., No. 10-19581 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. BEPCO, LP, et al., No. 10-19572 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. BP America Production Company, et al., No. 10-19576 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. Brammer Engineering, Inc., et al., No. 10-19573 (38th Jud. Dist. Ct., Cameron Par.); Cameron Parish v. Burlington Resources, et al., No. 10-19575 (38th Jud. Dist. Ct., Cameron Par.); Stutes v. Gulfport Energy Corporation, et al., No. 102,146 (15th Jud. Dist. Ct., Vermilion Par.); St. Bernard Parish v. Atlantic Richfield, et al., No. 16-1228 (34th Jud. Dist. Ct. St., Bernard Par.); City of New Orleans v. Apache Louisiana Mins, LLC, et al., No. 19-cv-08290, (E.D. La.). Chevron Corporation 2024 Annual Report 76 Note 17 Taxes Income Taxes Year ended December 31 2024 2023 2022 Income tax expense (benefit) U.S. federal Current $ 854 $ 895 $ 1,723 Deferred 748 666 2,240 State and local Current 275 211 482 Deferred 10 1 39 Total United States 1,887 1,773 4,484 International Current 7,388 6,745 9,738 Deferred 482 (345) (156) Total International 7,870 6,400 9,582 Total income tax expense (benefit) $ 9,757 $ 8,173 $ 14,066 The reconciliation between the U.S. statutory federal income tax rate and the company’s effective income tax rate is detailed in the following table: Year ended December 31 2024 2023 2022 Income (loss) before income taxes United States $ 8,056 $ 8,565 $ 21,005 International 19,450 21,019 28,669 Total income (loss) before income taxes 27,506 29,584 49,674 Theoretical tax (at U.S. statutory rate of 21%) 5,776 6,213 10,432 Equity affiliate accounting effect (845) (1,072) (1,678) Effect of income taxes from international operations 4,742 3,001 5,041 State and local taxes on income, net of U.S. federal income tax benefit 214 252 508 Prior year tax adjustments, claims and settlements 1 (30) (32) (90) Tax credits (28) (20) (6) Other U.S. 1, 2 (72) (169) (141) Total income tax expense (benefit) $ 9,757 $ 8,173 $ 14,066 Effective income tax rate 3 35.5 % 27.6 % 28.3 % 1 Includes one-time tax costs (benefits) associated with changes in uncertain tax positions. 2 Includes one-time tax costs (benefits) associated with changes in valuation allowances (2024 - $(12); 2023 - $(84); 2022 - $(36)). 3 The company’s effective tax rate is reflective of equity income reported on an after-tax basis as part of the “Total Income (Loss) Before Income Tax Expense,” in accordance with U.S. Generally Accepted Accounting Principles. Chevron’s share of its equity affiliates’ total income tax expense in 2024 was $1,286. The 2024 increase in income tax expense of $1,584 and the change in the company’s effective tax rate from 27.6 percent in 2023 to 35.5 percent in 2024 were primarily a result of the tax impacts from the asset sales in Canada. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 77 The company records its deferred taxes on a tax-jurisdiction basis. The reported deferred tax balances are composed of the following: At December 31 2024 2023 Deferred tax liabilities Properties, plant and equipment $ 20,648 $ 20,303 Investments and other 5,254 4,263 Total deferred tax liabilities 25,902 24,566 Deferred tax assets Foreign tax credits (15,261) (13,560) Asset retirement obligations/environmental reserves (4,220) (4,543) Employee benefits (2,050) (1,785) Deferred credits (292) (268) Tax loss carryforwards (3,034) (3,492) Other accrued liabilities (1,137) (1,416) Inventory (68) (126) Operating leases (1,352) (1,479) Miscellaneous (4,180) (3,652) Total deferred tax assets (31,594) (30,321) Deferred tax assets valuation allowance 21,313 20,416 Total deferred income taxes, net $ 15,621 $ 14,661 Deferred tax liabilities increased by $1,336 from year-end 2023, driven by deferred tax impacts resulting from the asset sales in Canada and foreign exchange impacts. Deferred tax assets increased by $1,273 from year-end 2023. This increase was primarily related to increases in foreign tax credits and foreign exchange impacts, partially offset by decreases in tax loss carryforwards and other accrued liabilities. The overall valuation allowance, which increased by $897 from year-end 2023, relates to deferred tax assets for U.S. foreign tax credit carryforwards, tax loss carryforwards and temporary differences. The valuation allowance reduces the deferred tax assets to amounts that are, in management’s assessment, more likely than not to be realized. At the end of 2024, the company had gross tax loss carryforwards of approximately $9,231 and tax credit carryforwards of approximately $288, primarily related to various international tax jurisdictions. Whereas some of these tax loss carryforwards do not have an expiration date, others expire at various times from 2025 through 2043. U.S. foreign tax credit carryforwards of $15,261 will expire between 2025 and 2034. At December 31, 2024 and 2023, deferred taxes were classified on the Consolidated Balance Sheet as follows: At December 31 2024 2023 Deferred charges and other assets $ (3,516) $ (4,169) Noncurrent deferred income taxes 19,137 18,830 Total deferred income taxes, net $ 15,621 $ 14,661 Income taxes, including U.S. state and foreign withholding taxes, are not accrued for unremitted earnings of international operations that have been or are intended to be reinvested indefinitely, or where no taxable temporary differences exist that are attributable to an investment in a foreign entity. The indefinite reinvestment assertion continues to apply for the purpose of determining deferred tax liabilities for U.S. state and foreign withholding tax purposes. It is not practicable to estimate the amount of state and foreign withholding taxes that might be payable on the possible remittance of earnings that are intended to be reinvested indefinitely. The company does not anticipate incurring significant additional taxes on remittances of earnings that are not indefinitely reinvested. Uncertain Income Tax Positions The company recognizes a tax benefit in the financial statements for an uncertain tax position only if management’s assessment is that the position is more likely than not (i.e., a likelihood greater than 50 percent) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in the accounting standards for income taxes refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods. The following table indicates the changes to the company’s unrecognized tax benefits for the years ended December 31, 2024, 2023 and 2022. The term “unrecognized tax benefits” in the accounting standards for income taxes refers to the Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 78 differences between a tax position taken or expected to be taken in a tax return and the benefit measured and recognized in the financial statements. Interest and penalties are not included. 2024 2023 2022 Balance at January 1 $ 5,452 $ 5,323 $ 5,288 Foreign currency effects — (27) (2) Additions based on tax positions taken in current year 236 248 30 Additions for tax positions taken in prior years 101 265 234 Reductions based on tax positions taken in current year (54) (104) — Reductions for tax positions taken in prior years (883) (251) (117) Settlements with taxing authorities in current year — (2) (110) Balance at December 31 $ 4,852 $ 5,452 $ 5,323 Approximately 76 percent of the $4,852 of unrecognized tax benefits at December 31, 2024, would have an impact on the effective tax rate if subsequently recognized. Certain of these unrecognized tax benefits relate to tax carryforwards that may require a full valuation allowance at the time of any such recognition. The company and its subsidiaries are subject to income taxation and audits throughout the world. With certain exceptions, income tax examinations are completed through 2016 for the United States and 2007 for other major jurisdictions. The company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in the various jurisdictions. Both the outcome of these tax matters and the timing of resolution and/or closure of the tax audits are highly uncertain. Of the amount of unrecognized tax benefits the company has identified as of December 31, 2024, it is reasonably possible that developments on tax matters in certain tax jurisdictions may result in decreases of approximately 68 percent within the next 12 months. Given the number of years that still remain subject to examination and the number of matters being examined in the various tax jurisdictions, the company is unable to estimate the range of possible adjustments to the balance of unrecognized tax benefits. On the Consolidated Statement of Income, the company reports interest and penalties related to liabilities for uncertain tax positions as “Income Tax Expense (Benefit).” As of December 31, 2024, accrued expense of $268 for anticipated interest and penalties was included on the Consolidated Balance Sheet, compared with accrued expense of $229 as of year-end 2023. Income tax expense (benefit) associated with interest and penalties was $40, $124 and $152 in 2024, 2023 and 2022, respectively. Taxes Other Than on Income Year ended December 31 2024 2023 2022 United States Import duties and other levies $ 8 $ (9) $ 10 Property and other miscellaneous taxes 977 818 609 Payroll taxes 296 286 248 Taxes on production 842 801 989 Total United States 2,123 1,896 1,856 International Import duties and other levies 90 72 63 Property and other miscellaneous taxes 2,283 2,004 1,789 Payroll taxes 125 121 122 Taxes on production 95 127 202 Total International 2,593 2,324 2,176 Total taxes other than on income $ 4,716 $ 4,220 $ 4,032 Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 79 Note 18 Properties, Plant and Equipment1 At December 31 Year ended December 31 Gross Investment at Cost Net Investment Additions at Cost2 Depreciation Expense3 2024 2023 2022 2024 2023 2022 2024 2023 2022 2024 2023 2022 Upstream United States $ 124,439 $ 117,955 $ 96,590 $ 52,428 $ 50,390 $ 37,031 $ 9,591 $ 20,408 $ 6,461 $ 7,562 $ 7,666 $ 5,012 International 176,401 183,996 188,556 76,642 84,561 88,549 4,426 4,130 2,599 7,935 8,109 9,830 Total Upstream 300,840 301,951 285,146 129,070 134,951 125,580 14,017 24,538 9,060 15,497 15,775 14,842 Downstream United States 32,336 31,192 29,802 13,667 13,521 12,827 1,217 1,623 2,742 1,091 931 913 International 8,331 8,401 8,281 2,946 3,122 3,226 245 237 246 360 301 311 Total Downstream 40,667 39,593 38,083 16,613 16,643 16,053 1,462 1,860 2,988 1,451 1,232 1,224 All Other United States 4,304 4,390 4,402 2,082 1,991 1,931 355 311 230 328 313 247 International 122 147 154 34 34 27 7 15 12 6 6 6 Total All Other 4,426 4,537 4,556 2,116 2,025 1,958 362 326 242 334 319 253 Total United States 161,079 153,537 130,794 68,177 65,902 51,789 11,163 22,342 9,433 8,981 8,910 6,172 Total International 184,854 192,544 196,991 79,622 87,717 91,802 4,678 4,382 2,857 8,301 8,416 10,147 Total $ 345,933 $ 346,081 $ 327,785 $ 147,799 $ 153,619 $ 143,591 $ 15,841 $ 26,724 $ 12,290 $ 17,282 $ 17,326 $ 16,319 1 Other than the United States and Australia, no other country accounted for 10 percent or more of the company’s net properties, plant and equipment (PP&E) in 2024. Australia had PP&E of $38,969, $41,409 and $44,012 in 2024, 2023 and 2022, respectively. Gross Investment at Cost and Additions at Cost for 2023 each include $10,487 associated with the PDC acquisition. 2 Net of dry hole expense related to prior years’ expenditures of $98, $110 and $177 in 2024, 2023 and 2022, respectively. 3 Depreciation expense includes accretion expense of $586, $593 and $560 in 2024, 2023 and 2022, respectively, and impairments and write-offs of $500, $2,180 and $950 in 2024, 2023 and 2022, respectively. Note 19 Short-Term Debt At December 31 2024 2023 Commercial paper $ 5,386 $ — Notes payable to banks and others with originating terms of one year or less 131 469 Current maturities of long-term debt* 4,012 1,667 Current maturities of long-term finance leases 58 60 Redeemable long-term obligations 3,069 2,876 Subtotal 12,656 5,072 Reclassified to long-term debt (8,250) (4,543) Total short-term debt $ 4,406 $ 529 * Inclusive of unamortized premiums of $0 at December 31, 2024 and $17 at December 31, 2023. Redeemable long-term obligations consist primarily of tax-exempt variable-rate put bonds that are included as current liabilities because they become redeemable at the option of the bondholders during the year following the balance sheet date. The company may periodically enter into interest rate swaps on a portion of its short-term debt. At December 31, 2024, the company had no interest rate swaps on short-term debt. At December 31, 2024, the company had $8,250 in 364-day committed credit facilities with various major banks that enable the refinancing of short-term obligations. The credit facilities allow the company the option to convert outstanding short-term obligations into a term loan for a period of up to one year from the facilities termination date. This supports commercial paper borrowing and can also be used for general corporate purposes. The company’s practice has been to replace expiring commitments with new commitments on substantially the same terms, maintaining levels management believes appropriate. Any borrowings under these facilities would be unsecured indebtedness at interest rates based on the Secured Overnight Financing Rate (SOFR), or an average of base lending rates published by specified banks and on terms reflecting the company’s strong credit rating. No borrowings were outstanding under these facilities at December 31, 2024. The company classified $8,250 and $4,543 of short-term debt as long-term at December 31, 2024 and 2023, respectively. Settlement of these obligations is not expected to require the use of working capital within one year, as the company had the intent and the ability, as evidenced by committed credit facilities, to continue refinancing them. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 80 Note 20 Long-Term Debt Total long-term debt including finance lease liabilities at December 31, 2024, was $20,135. The company’s long-term debt outstanding at year-end 2024 and 2023 was as follows: At December 31 2024 2023 Weighted Average Interest Rate (%)1 Range of Interest Rates (%)2 Principal Principal Notes due 2025 1.724 0.687 - 3.326 4,000 4,000 Notes due 2026 2.954 2,250 2,250 Notes due 2027 2.379 1.018 - 8.000 2,000 2,000 Notes due 2028 3.850 600 600 Notes due 2029 3.250 500 500 Notes due 2030 2.236 1,500 1,500 Debentures due 2031 8.625 102 102 Debentures due 2032 8.416 8.000 - 8.625 183 183 Notes due 2040 2.978 293 293 Notes due 2041 6.000 397 397 Notes due 2043 5.250 330 330 Notes due 2044 5.050 222 222 Notes due 2047 4.950 187 187 Notes due 2049 4.200 237 237 Notes due 2050 2.763 2.343 - 3.078 1,750 1,750 Debentures due 2097 7.250 60 60 Bank loans due 2025 to 2027 3.321 3.306 - 3.367 205 — Medium-term notes, maturing from 2033 to 2038 6.101 4.324 - 7.840 20 20 Notes due 2024 — 1,650 Total including debt due within one year 14,836 16,281 Debt due within one year (4,012) (1,650) Fair market value adjustment for debt acquired in the Noble acquisition 529 578 Reclassified from short-term debt 8,250 4,543 Unamortized discounts and debt issuance costs (14) (19) Finance lease liabilities3 546 574 Total long-term debt $ 20,135 $ 20,307 1 Weighted-average interest rate at December 31, 2024. 2 Range of interest rates at December 31, 2024. 3 For details on finance lease liabilities, see Note 5 Lease Commitments. Chevron has an automatic shelf registration statement that expires in November 2027. This registration statement is for an unspecified amount of nonconvertible debt securities issued or guaranteed by Chevron Corporation or CUSA. Long-term debt excluding finance lease liabilities with a principal balance of $14,836 matures as follows: 2025 – $4,012; 2026 – $2,290; 2027 – $2,153; 2028 – $600; 2029 – $500; and after 2029 – $5,281. See Note 9 Fair Value Measurements for information concerning the fair value of the company’s long-term debt. Note 21 Accounting for Suspended Exploratory Wells The company continues to capitalize exploratory well costs after the completion of drilling when the well has found a sufficient quantity of reserves to justify completion as a producing well, and the business unit is making sufficient progress assessing the reserves and the economic and operating viability of the project. If either condition is not met or if the company obtains information that raises substantial doubt about the economic or operational viability of the project, the exploratory well would be assumed to be impaired, and its costs, net of any salvage value, would be charged to expense. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 81 The following table indicates the changes to the company’s suspended exploratory well costs for the three years ended December 31, 2024: 2024 2023 2022 Beginning balance at January 1 $ 1,648 $ 1,627 $ 2,109 Additions to capitalized exploratory well costs pending the determination of proved reserves 14 88 72 Reclassifications to wells, facilities and equipment based on the determination of proved reserves — — (481) Capitalized exploratory well costs charged to expense — (67) (73) Ending balance at December 31 $ 1,662 $ 1,648 $ 1,627 The following table provides an aging of capitalized well costs and the number of projects for which exploratory well costs have been capitalized for a period greater than one year since the completion of drilling: At December 31 2024 2023 2022 Exploratory well costs capitalized for a period of one year or less $ 17 $ 78 $ 73 Exploratory well costs capitalized for a period greater than one year 1,645 1,570 1,554 Balance at December 31 $ 1,662 $ 1,648 $ 1,627 Number of projects with exploratory well costs that have been capitalized for a period greater than one year* 14 13 12 *Certain projects have multiple wells or fields or both. Of the $1,645 of exploratory well costs capitalized for more than one year at December 31, 2024, $847 is related to seven projects that had drilling activities underway or firmly planned for the near future. The $798 balance is related to seven projects in areas requiring a major capital expenditure before production could begin and for which additional drilling efforts were not underway or firmly planned for the near future. Additional drilling was not deemed necessary because the presence of hydrocarbons had already been established, and other activities were in process to enable a future decision on project development. The projects for the $798 referenced above had the following activities associated with assessing the reserves and the projects’ economic viability: (a) $383 (five projects) – undergoing front-end engineering and design with final investment decision expected within four years; (b) $415 (two projects) – development alternatives under review. While progress was being made on all 14 projects, the decision on the recognition of proved reserves under SEC rules in some cases may not occur for several years because of the complexity, scale and negotiations associated with the projects. Approximately half of these decisions are expected to occur in the next five years. The $1,645 of suspended well costs capitalized for a period greater than one year as of December 31, 2024, represents 75 exploratory wells in 14 projects. The tables below contain the aging of these costs on a well and project basis: Aging based on drilling completion date of individual wells: Amount Number of wells 2000-2009 $ 263 14 2010-2014 1,122 49 2015-2023 260 12 Total $ 1,645 75 Aging based on drilling completion date of last suspended well in project: Amount Number of projects 2008-2012 $ 292 2 2013-2016 1,082 6 2017-2024 271 6 Total $ 1,645 14 Note 22 Stock Options and Other Share-Based Compensation Compensation expense for stock options for 2024, 2023 and 2022 was $90 ($68 after tax), $85 ($65 after tax) and $60 ($46 after tax), respectively. In addition, compensation expense for stock appreciation rights, restricted stock, performance shares and restricted stock units for 2024, 2023 and 2022 was $510 ($388 after tax), $(100) ($(76) after tax) and $1,013 ($770 after tax), respectively. No significant stock-based compensation cost was capitalized at December 31, 2024, or December 31, 2023. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 82 Cash received in payment for option exercises under all share-based payment arrangements for 2024, 2023 and 2022 was $356, $263 and $5,835, respectively. Actual tax benefits realized for the tax deductions from option exercises were $24, $20 and $216 for 2024, 2023 and 2022, respectively. Cash paid to settle performance shares, restricted stock units and stock appreciation rights was $395, $566 and $556 for 2024, 2023 and 2022, respectively. On May 25, 2022, stockholders approved the Chevron 2022 Long-Term Incentive Plan (2022 LTIP). Awards under the 2022 LTIP may take the form of, but are not limited to, stock options, restricted stock, restricted stock units, stock appreciation rights, performance shares and non-stock grants. From May 2022 through May 2032, no more than 104 million shares may be issued under the 2022 LTIP. For awards issued on or after May 25, 2022, no more than 48 million of those shares may be issued in the form of full value awards such as share-settled restricted stock, share-settled restricted stock units, share-settled performance shares and other share-settled awards that do not require full payment in cash or property for shares underlying such awards by the award recipient. Contractual terms of equity awards vary between three years for the performance shares and special restricted stock units with cliff vesting at the end of the contractual period, five years for standard restricted stock units with cliff vesting at the end of the contractual period and 10 years for the stock options and stock appreciation rights with graded vesting provisions by which one-third of each award vests around each of the first, second and third anniversaries of the date of grant. Commencing for grants issued in January 2023 and after, standard restricted stock units vest ratably on an annual basis over a three-year period. Forfeitures of performance shares, restricted stock units, and stock appreciation rights are recognized as they occur. Forfeitures of stock options are estimated using historical forfeiture data dating back to 1990. Fair Value and Assumptions The fair market values of stock options and stock appreciation rights granted in 2024, 2023 and 2022 were measured on the date of grant using the Black-Scholes option-pricing model with the following weighted- average assumptions: Year ended December 31 2024 2023 2022 Expected term in years1 6.5 6.4 6.9 Volatility2 33.0 % 32.5 % 31.3 % Risk-free interest rate based on zero coupon U.S. treasury note 3.98 % 3.43 % 1.79 % Dividend yield 4.1 % 3.5 % 5.0 % Weighted-average fair value per option granted $ 38.00 $ 45.82 $ 23.56 1 Expected term is based on historical exercise and post-vesting cancellation data. 2 Volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term. A summary of option activity during 2024 is presented below: Shares (Thousands) Weighted-Average Exercise Price Averaged Remaining Contractual Term (Years) Aggregate Intrinsic Value Outstanding at January 1, 2024 24,375 $ 118.72 Granted 2,730 $ 152.35 Exercised (3,504) $ 101.60 Forfeited (433) $ 260.55 Outstanding at December 31, 2024 23,168 $ 122.62 5.06 $ 687 Exercisable at December 31, 2024 18,372 $ 114.15 4.15 $ 675 The total intrinsic value (i.e., the difference between the exercise price and the market price) of options exercised during 2024, 2023 and 2022 was $190, $167 and $2,369, respectively. During this period, the company continued its practice of issuing treasury shares upon exercise of these awards. As of December 31, 2024, there was $320 of total unrecognized before-tax compensation cost related to nonvested share- based compensation arrangements granted under the plan. That cost is expected to be recognized over a weighted-average period of 1.9 years. At January 1, 2024, the number of LTIP performance shares outstanding was equivalent to 4,419,310 shares. During 2024, 1,525,452 performance shares were granted, 1,966,923 shares vested with cash proceeds distributed to recipients and 118,400 shares were forfeited. At December 31, 2024, there were 3,859,439 performance shares outstanding, of which 2,815,575 are payable in cash and 1,043,864 are payable in shares. The fair value of the liability recorded for these instruments payable in cash was $307 and was measured largely using the Monte Carlo simulation method. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 83 At January 1, 2024, the number of restricted stock units outstanding was equivalent to 5,060,242 shares. During 2024, 1,813,119 restricted stock units were granted, 1,340,664 units vested with cash proceeds distributed to recipients and 132,899 units were forfeited. At December 31, 2024, there were 5,399,798 restricted stock units outstanding, of which 3,346,557 are payable in cash and 2,053,241 are payable in shares. The fair value of the liability recorded for the vested portion of these instruments payable in cash was $387, valued at the stock price as of December 31, 2024. In addition, outstanding stock appreciation rights that were granted under the LTIP totaled 535,122 equivalent shares as of December 31, 2024. The fair value of the liability recorded for the vested portion of these instruments was $23. Note 23 Employee Benefit Plans The company has defined benefit pension plans for many employees. The company typically prefunds defined benefit plans as required by local regulations or in certain situations where prefunding provides economic advantages. In the United States, all qualified plans are subject to the Employee Retirement Income Security Act (ERISA) minimum funding standard. The company does not typically fund U.S. nonqualified pension plans that are not subject to funding requirements under laws and regulations because contributions to these pension plans may be less economic and investment returns may be less attractive than the company’s other investment alternatives. The company also sponsors other post-employment benefit (OPEB) plans that provide medical and dental benefits, as well as life insurance for some active and qualifying retired employees. The plans are unfunded, and the company and retirees share the costs. For the company’s main U.S. medical plan, the increase to the pre-Medicare company contribution for retiree medical coverage is limited to no more than 4 percent each year. Certain life insurance benefits are paid by the company. The company recognizes the overfunded or underfunded status of each of its defined benefit pension and OPEB plans as an asset or liability on the Consolidated Balance Sheet. The funded status of the company’s pension and OPEB plans for 2024 and 2023 follows: Pension Benefits 2024 2023 Other Benefits U.S. Int’l. U.S. Int’l. 2024 2023 Change in Benefit Obligation Benefit obligation at January 1 $ 10,392 $ 3,605 $ 9,713 $ 3,354 $ 2,017 $ 1,938 Service cost 357 54 342 58 34 33 Interest cost 465 191 448 193 98 97 Plan participants’ contributions — 2 — 3 54 63 Plan amendments — 18 — 28 30 — Actuarial (gain) loss (382) (274) 603 17 (144) 103 Foreign currency exchange rate changes — (88) — 180 (6) 5 Benefits paid (692) (217) (714) (218) (202) (222) Actual expenses/taxes — (2) — — — — Divestitures/Acquisitions — — — (14) — — Curtailment — — — 2 (1) — Special termination costs — — — 2 — — Benefit obligation at December 31 10,140 3,289 10,392 3,605 1,880 2,017 Change in Plan Assets Fair value of plan assets at January 1 9,137 3,398 7,942 3,286 — — Actual return on plan assets 338 (133) 889 46 — — Foreign currency exchange rate changes — (77) — 181 — — Employer contributions 754 90 1,020 100 148 159 Plan participants’ contributions — 2 — 3 54 63 Benefits paid (692) (217) (714) (218) (202) (222) Actual expenses — (2) — — — — Fair value of plan assets at December 31 9,537 3,061 9,137 3,398 — — Funded status at December 31 $ (603) $ (228) $ (1,255) $ (207) $ (1,880) $ (2,017) Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 84 Amounts recognized on the Consolidated Balance Sheet for the company’s pension and OPEB plans at December 31, 2024 and 2023, include: Pension Benefits 2024 2023 Other Benefits U.S. Int’l. U.S. Int’l. 2024 2023 Deferred charges and other assets $ 607 $ 655 $ 31 $ 703 $ — $ — Accrued liabilities (146) (71) (145) (73) (149) (154) Noncurrent employee benefit plans (1,064) (812) (1,141) (837) (1,731) (1,863) Net amount recognized at December 31 $ (603) $ (228) $ (1,255) $ (207) $ (1,880) $ (2,017) For the year ended December 31, 2024, the decrease in benefit obligations was primarily due to actuarial gains caused by higher discount rates used to value the obligations. For the year ended December 31, 2023, the increase in benefit obligations was primarily due to actuarial losses caused by lower discount rates used to value the obligations. Amounts recognized on a before-tax basis in “Accumulated other comprehensive loss” for the company’s pension and OPEB plans were $3,376 and $3,792 at the end of 2024 and 2023, respectively. These amounts consisted of: Pension Benefits 2024 2023 Other Benefits U.S. Int’l. U.S. Int’l. 2024 2023 Net actuarial (gain) loss $ 2,796 $ 849 $ 3,161 $ 823 $ (401) $ (266) Prior service (credits) costs 33 133 37 126 (34) (89) Total recognized at December 31 $ 2,829 $ 982 $ 3,198 $ 949 $ (435) $ (355) The accumulated benefit obligations for all U.S. and international pension plans were $9,053 and $3,066, respectively, at December 31, 2024, and $9,284 and $3,378, respectively, at December 31, 2023. Information for U.S. and international pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2024 and 2023, was: Pension Benefits 2024 2023 U.S. Int’l. U.S. Int’l. Projected benefit obligations $ 1,214 $ 884 $ 1,203 $ 913 Accumulated benefit obligations 1,145 744 1,108 773 Fair value of plan assets 7 1 — 4 The components of net periodic benefit cost and amounts recognized in the Consolidated Statement of Comprehensive Income for 2024, 2023 and 2022 are shown in the table below: Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 85 Pension Benefits 2024 2023 2022 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2024 2023 2022 Net Periodic Benefit Cost Service cost $ 357 $ 54 $ 342 $ 58 $ 432 $ 83 $ 34 $ 33 $ 43 Interest cost 465 191 448 193 318 137 98 97 60 Expected return on plan assets (597) (196) (557) (204) (624) (176) — — — Amortization of prior service costs (credits) 4 11 4 8 2 6 (25) (25) (27) Recognized actuarial (gains) losses 243 18 199 8 218 15 (15) (19) 13 Settlement losses (gains) — 1 56 — 363 (6) — — — Curtailment losses (gains) — — — 2 — (5) (1) — — Special termination benefits — — — 2 — — — — — Acquisition/Divestiture losses (gains) — — — (2) — — — — — Total net periodic benefit cost 472 79 492 65 709 54 91 86 89 Changes Recognized in Comprehensive Income Net actuarial (gain) loss during period (122) 45 270 172 (279) (257) (151) 108 (514) Amortization of actuarial (gain) loss (243) (19) (255) (8) (581) (5) 15 19 (13) Prior service (credits) costs during period — 18 — 28 40 38 30 1 18 Amortization of prior service (costs) credits (4) (11) (4) (8) (2) (6) 25 25 27 Total changes recognized in other comprehensive income (369) 33 11 184 (822) (230) (81) 153 (482) Recognized in Net Periodic Benefit Cost and Other Comprehensive Income $ 103 $ 112 $ 503 $ 249 $ (113) $ (176) $ 10 $ 239 $ (393) Assumptions The following weighted-average assumptions were used to determine benefit obligations and net periodic benefit costs for years ended December 31: Pension Benefits 2024 2023 2022 Other Benefits U.S. Int’l. U.S. Int’l. U.S. Int’l. 2024 2023 2022 Assumptions used to determine benefit obligations: Discount rate 5.7 % 6.0 % 5.0 % 5.5 % 5.2 % 5.8 % 5.7 % 5.1 % 5.3 % Rate of compensation increase 4.5 % 3.9 % 4.5 % 3.9 % 4.5 % 4.2 % N/A N/A N/A Assumptions used to determine net periodic benefit cost: Discount rate for service cost 5.0 % 5.5 % 5.2 % 5.8 % 3.6 % 2.8 % 5.2 % 5.4 % 3.1 % Discount rate for interest cost 4.8 % 5.5 % 5.0 % 5.8 % 2.8 % 2.8 % 5.1 % 5.2 % 2.4 % Expected return on plan assets 7.0 % 5.9 % 7.0 % 6.1 % 6.6 % 3.9 % N/A N/A N/A Rate of compensation increase 4.5 % 3.9 % 4.5 % 4.2 % 4.5 % 4.1 % N/A N/A N/A Expected Return on Plan Assets The company’s estimated long-term rates of return on pension assets are driven primarily by actual historical asset-class returns, an assessment of expected future performance, advice from external actuarial firms and the incorporation of specific asset-class risk factors. Asset allocations are periodically updated using pension plan asset/liability studies, and the company’s estimated long-term rates of return are consistent with these studies. For 2024, the company used an expected long-term rate of return of 7.0 percent for U.S. pension plan assets, which account for 73 percent of the company’s pension plan assets at the beginning of the year. The market-related value of assets of the main U.S. pension plan used in the determination of pension expense was based on the market values in the three months preceding the year-end measurement date. Management considers the three-month time period long enough to minimize the effects of distortions from day-to-day market volatility and still be contemporaneous to the end of the year. For other plans, market value of assets as of year-end is used in calculating the pension expense. Discount Rate The discount rate assumptions used to determine the U.S. and international pension and OPEB plan obligations and expense reflect the rate at which benefits could be effectively settled, and are equal to the equivalent single rate resulting from yield curve analysis. This analysis considered the projected benefit payments specific to the company’s plans and the yields on high-quality bonds. The projected cash flows were discounted to the valuation date using the yield curve for the main U.S. pension and OPEB plans. The effective discount rates derived from this analysis were 5.7 percent, 5.0 percent, and 5.2 percent for 2024, 2023, and 2022, respectively, for the main U.S. pension plan and 5.6 percent, 5.0 percent, and 5.2 percent for 2024, 2023, and 2022, respectively, for the main U.S. OPEB plans. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 86 Other Benefit Assumptions For the measurement of accumulated post-employment benefit obligation at December 31, 2024, for the main U.S. OPEB plan, the assumed health care cost-trend rates start with 8.4 percent in 2025 and gradually decline to 4.5 percent for 2034 and beyond. For this measurement at December 31, 2023, the assumed health care cost- trend rates started with 8.4 percent in 2024 and gradually declined to 4.5 percent for 2033 and beyond. Plan Assets and Investment Strategy The fair value measurements of the company’s pension plans for 2024 and 2023 are as follows: U.S. Int’l. Total Level 1 Level 2 Level 3 NAV Total Level 1 Level 2 Level 3 NAV At December 31, 2023 Equities U.S.1 $ 1,691 $ 1,689 $ 1 $ 1 $ — $ 188 $ 188 $ — $ — $ — International 1,128 1,128 — — — 124 124 — — — Collective Trusts/Mutual Funds2 1,269 4 — — 1,265 95 6 — — 89 Fixed Income Government 82 — 82 — — 172 101 71 — — Corporate 964 — 964 — — 431 4 427 — — Bank Loans 5 — 5 — — — — — — — Mortgage/Asset Backed 1 — 1 — — 5 — 5 — — Collective Trusts/Mutual Funds2 2,293 — — — 2,293 1,819 — — — 1,819 Mixed Funds3 — — — — — 85 8 77 — — Real Estate4 1,087 — — — 1,087 147 — 24 — 123 Alternative Investments — — — — — 9 — 9 — — Cash and Cash Equivalents 548 12 — — 536 81 74 1 — 6 Other5 69 (2) 14 56 1 242 — 11 81 150 Total at December 31, 2023 $ 9,137 $ 2,831 $ 1,067 $ 57 $ 5,182 $ 3,398 $ 505 $ 625 $ 81 $ 2,187 At December 31, 2024 Equities U.S.1 $ 1,866 $ 1,866 $ — $ — $ — $ 180 $ 180 $ — $ — $ — International 1,208 1,197 — 11 — 107 97 — 10 — Collective Trusts/Mutual Funds2 1,191 4 — — 1,187 98 6 13 — 79 Fixed Income Government 132 — 132 — — 167 99 68 — — Corporate 1,042 — 1,042 — — 403 2 401 — — Bank Loans 10 — 10 — — — — — — — Mortgage/Asset Backed 1 — 1 — — 4 — 4 — — Collective Trusts/Mutual Funds2 2,342 — — — 2,342 1,594 2 10 — 1,582 Mixed Funds3 — — — — — 76 — 76 — — Real Estate4 1,383 — — — 1,383 105 — 16 — 89 Alternative Investments — — — — — 9 — 9 — — Cash and Cash Equivalents 289 13 — — 276 108 90 — — 18 Other5 73 (3) 13 63 — 209 — 12 68 129 Total at December 31, 2024 $ 9,537 $ 3,077 $ 1,198 $ 74 $ 5,188 $ 3,060 $ 476 $ 609 $ 78 $ 1,897 1 There were no investments in the company’s common stock at December 31, 2024 or December 31, 2023. 2 Collective Trusts/Mutual Funds for U.S. plans are entirely index funds; for International plans, they are mostly unit trust and index funds. 3 Mixed funds are composed of funds that invest in both equity and fixed-income instruments in order to diversify and lower risk. 4 The year-end valuations of the U.S. real estate assets are based on third-party appraisals that occur at least once a year for each property in the portfolio. 5 The “Other” asset class includes net payables for securities purchased but not yet settled (Level 1); dividends and interest- and tax-related receivables (Level 2); insurance contracts (Level 3); and investments in private-equity limited partnerships (NAV). Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 87 The effects of fair value measurements using significant unobservable inputs on changes in Level 3 plan assets are outlined below: Equity U.S. Int’l. Real Estate Other Total Total at December 31, 2022 $ — $ — $ 38 $ 139 $ 177 Actual Return on Plan Assets: Assets held at the reporting date 1 — 5 — 6 Assets sold during the period — — — (2) (2) Purchases, Sales and Settlements — — — — — Transfers in and/or out of Level 3 — — (43) — (43) Total at December 31, 2023 $ 1 $ — $ — $ 137 $ 138 Actual Return on Plan Assets: Assets held at the reporting date (1) 11 — — 10 Assets sold during the period — 2 — 9 11 Purchases, Sales and Settlements — 2 — (9) (7) Transfers in and/or out of Level 3 — 6 — (6) — Total at December 31, 2024 $ — $ 21 $ — $ 131 $ 152 The primary investment objectives of the pension plans are to achieve the highest rate of total return within prudent levels of risk and liquidity, to diversify and mitigate potential downside risk associated with the investments, and to provide adequate liquidity for benefit payments and portfolio management. The company’s U.S. and U.K. pension plans comprise 95 percent of the total pension assets. Both the U.S. and U.K. plans have an Investment Committee that regularly meets during the year to review the asset holdings and their returns. To assess the plans’ investment performance, long-term asset allocation policy benchmarks have been established. For the primary U.S. pension plan, the company’s Investment Committee has established the following approved asset allocation ranges: Equities 30–60 percent, Fixed Income 30–50 percent, Real Estate 5–25 percent, Alternative Investments 0–5 percent and Cash 0–15 percent. For the U.K. pension plan, the U.K. Board of Trustees has established the following asset allocation guidelines: Equities 5–15 percent, Fixed Income 63–93 percent, Real Estate 5–15 percent, and Cash 0–7 percent. The other significant international pension plans also have established maximum and minimum asset allocation ranges that vary by plan. Actual asset allocation within approved ranges is based on a variety of factors, including market conditions and liquidity constraints. To mitigate concentration and other risks, assets are invested across multiple asset classes with active investment managers and passive index funds. The company does not prefund its OPEB obligations. Cash Contributions and Benefit Payments In 2024, the company contributed $754 and $90 to its U.S. and international pension plans, respectively. In 2025, the company expects contributions to be approximately $750 to its U.S. plans and $100 to its international pension plans. Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments, tax law changes and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations. The company anticipates paying OPEB benefits of approximately $150 in 2025; $148 was paid in 2024. The following benefit payments, which include estimated future service, are expected to be paid by the company in the next 10 years: Pension Benefits Other U.S. Int’l. Benefits 2025 $ 899 $ 205 $ 149 2026 901 213 147 2027 894 221 145 2028 879 226 144 2029 871 231 143 2030-2034 4,251 1,279 709 Employee Savings Investment Plan Eligible employees of Chevron and certain of its subsidiaries participate in the Chevron Employee Savings Investment Plan (ESIP). Compensation expense for the ESIP totaled $330, $320 and $283 in 2024, 2023 and 2022, respectively. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 88 Benefit Plan Trusts Prior to its acquisition by Chevron, Texaco established a benefit plan trust for funding obligations under some of its benefit plans. At year-end 2024, the trust contained 14.2 million shares of Chevron treasury stock. The trust will sell the shares or use the dividends from the shares to pay benefits only to the extent that the company does not pay such benefits. The company intends to continue to pay its obligations under the benefit plans. The trustee will vote the shares held in the trust as instructed by the trust’s beneficiaries. The shares held in the trust are not considered outstanding for earnings-per-share purposes until distributed or sold by the trust in payment of benefit obligations. Employee Incentive Plans The Chevron Incentive Plan is an annual cash bonus plan for eligible employees that links awards to corporate and individual performance in the prior year. Charges to expense for cash bonuses were $965, $809 and $1,169 in 2024, 2023 and 2022, respectively. Chevron also has the LTIP for officers and other regular salaried employees of the company and its subsidiaries who hold positions of significant responsibility. Awards under the LTIP consist of stock options and other share-based compensation that are described in Note 22 Stock Options and Other Share- Based Compensation. Note 24 Other Contingencies and Commitments Income Taxes The company calculates its income tax expense and liabilities quarterly. These liabilities generally are subject to audit and are not finalized with the individual taxing authorities until several years after the end of the annual period for which income taxes have been calculated. Refer to Note 17 Taxes for a discussion of the periods for which tax returns have been audited for the company’s major tax jurisdictions and a discussion for all tax jurisdictions of the differences between the amount of tax benefits recognized in the financial statements and the amount taken or expected to be taken in a tax return. Settlement of open tax years, as well as other tax issues in countries where the company conducts its businesses, are not expected to have a material effect on the consolidated financial position or liquidity of the company and, in the opinion of management, adequate provisions have been made for all years under examination or subject to future examination. Guarantees The company has one guarantee to an equity affiliate totaling $98. This guarantee is associated with certain payments under a terminal use agreement entered into by an equity affiliate. Over the approximate 3-year remaining term of this guarantee, the maximum guarantee amount will be reduced as certain fees are paid by the affiliate. There are numerous cross-indemnity agreements with the affiliate and the other partners to permit recovery of amounts paid under the guarantee. Chevron has recorded no liability for this guarantee. Indemnifications The company often includes standard indemnification provisions in its arrangements with its partners, suppliers and vendors in the ordinary course of business, the terms of which range in duration and sometimes are not limited. The company may be obligated to indemnify such parties for losses or claims suffered or incurred in connection with its service or other claims made against such parties. Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements The company and its subsidiaries have certain contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which may relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business. The aggregate amounts of required payments under throughput and take-or-pay agreements are: 2025 – $1,039; 2026 – $1,129; 2027 – $1,304; 2028 – $1,326; 2029 – $1,236; after 2029 – $6,882. The aggregate amount of required payments for other unconditional purchase obligations are: 2025 – $436; 2026 – $653; 2027 – $477; 2028 – $380; 2029 – $186; after 2029 – $907. A portion of these commitments may ultimately be shared with project partners. Total payments under the agreements were $1,354 in 2024, $1,420 in 2023 and $1,866 in 2022. Environmental The company is subject to loss contingencies pursuant to laws, regulations, private claims and legal proceedings related to environmental matters that are subject to legal settlements or that in the future may require the company to take action to correct or ameliorate the effects on the environment of prior release of chemicals or petroleum substances by the company or other parties. Such contingencies may exist for various operating, closed and divested sites, including, but not limited to, U.S. federal Superfund sites and analogous sites under state laws, refineries, chemical plants, marketing facilities, crude oil fields and mining sites. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 89 Although the company has provided for known environmental obligations that are probable and reasonably estimable, it is likely that the company will continue to incur additional liabilities. The amount of additional future costs are not fully determinable due to such factors as the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions that may be required, the determination of the company’s liability in proportion to other responsible parties, and the extent to which such costs are recoverable from third parties. These future costs may be material to results of operations in the period in which they are recognized, but the company does not expect these costs will have a material effect on its consolidated financial position or liquidity. Chevron’s environmental reserve as of December 31, 2024, was $945. Included in this balance was $220 related to remediation activities at sites for which the company has been identified as a potentially responsible party under the provisions of the U.S. federal Superfund law which provide for joint and several liability for all responsible parties. Any future actions by regulatory agencies to require Chevron to assume other potentially responsible parties’ costs at designated hazardous waste sites are not expected to have a material effect on the company’s results of operations, consolidated financial position or liquidity. Of the remaining year-end 2024 environmental reserves balance of $725, $440 is related to the company’s U.S. downstream operations, $49 to its international downstream operations, and $236 to its upstream operations. Liabilities at all sites were primarily associated with the company’s plans and activities to remediate soil or groundwater contamination or both. The company manages environmental liabilities under specific sets of regulatory requirements, which in the United States include the Resource Conservation and Recovery Act and various state and local regulations. No single remediation site at year-end 2024 had a recorded liability that was material to the company’s results of operations, consolidated financial position or liquidity. Refer to Note 25 Asset Retirement Obligations for a discussion of the company’s asset retirement obligations. Decommissioning Obligations for Previously Divested Assets Some assets are divested along with their related liabilities, such as decommissioning obligations. In certain instances, such transferred obligations have returned and may continue to return to the company. For example, in fourth quarter 2023, the company recognized charges for decommissioning obligations from certain previously divested assets in the Gulf of America. To the extent the current owners of the company’s previously divested assets default on their decommissioning obligations, regulators may require that Chevron assume such obligations. The company could have additional significant obligations revert, primarily in the United States. The company is not currently aware of any such obligations that are reasonably possible to be material. The liability balance at the end of 2023 was $2,708, $235 was spent in 2024, and the balance at the end of 2024 was $2,478. Other Contingencies The company and its affiliates continue to review and analyze their operations and may close, retire, sell, exchange, acquire or restructure assets to achieve operational or strategic benefits and to improve competitiveness and profitability. These activities, individually or together, may result in significant gains or losses in future periods. Chevron receives claims from and submits claims to customers; trading partners; joint venture partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; suppliers; and individuals. The amounts of these claims, individually and in the aggregate, may be significant and take lengthy periods to resolve, and may result in gains or losses in future periods. Note 25 Asset Retirement Obligations The company records the fair value of a liability for an asset retirement obligation (ARO) both as an asset and a liability when there is a legal obligation associated with the retirement of a tangible long-lived asset and the liability can be reasonably estimated. The legal obligation to perform the asset retirement activity is unconditional, even though uncertainty may exist about the timing and/or method of settlement that may be beyond the company’s control. This uncertainty about the timing and/or method of settlement is factored into the measurement of the liability when sufficient information exists to reasonably estimate fair value. The ARO liability is initially recognized at its fair value with an increase to the related asset. Subsequent accretion of the liability and depreciation of the asset is recorded over time. The company evaluates its ARO estimates regularly or when there is significant new information about costs, timing, and duration of asset retirement activity. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 90 AROs are primarily recorded for the company’s crude oil and natural gas producing assets. No significant AROs associated with any legal obligations to retire downstream long-lived assets have been recognized, as indeterminate settlement dates for the asset retirements prevent estimation of the fair value of the associated ARO. The company performs periodic reviews of its downstream long-lived assets for any changes in facts and circumstances that might require recognition of a retirement obligation. The following table indicates the changes to the company’s before-tax asset retirement obligations in 2024, 2023 and 2022: 2024 2023 2022 Balance at January 1 $ 13,833 $ 12,701 $ 12,808 Liabilities assumed in the PDC acquisition — 220 — Liabilities incurred 83 183 9 Liabilities settled (2,083) (1,471) (1,102) Reduction due to asset sales (171) (94) (179) Accretion expense 588 593 560 Revisions in estimated cash flows 417 1,701 605 Balance at December 31 $ 12,667 $ 13,833 $ 12,701 In the table above, the amount associated with “Revisions in estimated cash flows” primarily reflects increased cost estimates and scope changes to decommission wells, equipment and facilities. The long-term portion of the $12,667 balance at the end of 2024 was $11,429. Note 26 Revenue Revenue from contracts with customers is presented in “Sales and other operating revenues” along with some activity that is accounted for outside the scope of Accounting Standard Codification (ASC) 606, which is not material to this line, on the Consolidated Statement of Income. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another (including buy/sell arrangements) are combined and recorded on a net basis and reported in “Purchased crude oil and products” on the Consolidated Statement of Income. Refer to Note 14 Operating Segments and Geographic Data for additional information on the company’s segmentation of revenue. Receivables related to revenue from contracts with customers are included in “Accounts and notes receivable” on the Consolidated Balance Sheet, net of the allowance for doubtful accounts. The net balance of these receivables was $14,227 and $13,641 at December 31, 2024 and 2023, respectively. Other items included in “Accounts and notes receivable” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of ASC 606. Contract assets and related costs are reflected in “Prepaid expenses and other current assets” and contract liabilities are reflected in “Accrued liabilities” and “Deferred credits and other noncurrent obligations” on the Consolidated Balance Sheet. Amounts for these items are not material to the company’s financial position. Note 27 Other Financial Information Earnings in 2024 included after-tax gains of approximately $246 relating to the sale of certain properties. Of this amount, approximately $231 and $15 related to upstream and downstream, respectively. Earnings in 2023 included after-tax gains of approximately $143 relating to the sale of certain properties, of which approximately $110 and $33 related to upstream and downstream assets, respectively. Earnings in 2022 included after-tax gains of approximately $390 relating to the sale of certain properties, of which approximately $300 and $90 related to upstream and downstream assets, respectively. Earnings in 2024 included after-tax charges of approximately $715 for severance ($208 in All Other, $188 in U.S. Downstream, $183 in U.S. Upstream, $119 in International Upstream, $17 in International Downstream) and $400 for impairments ($185 in International Downstream, $125 in International Upstream, $90 in U.S. Downstream). Earnings in 2023 included after-tax charges of approximately $1,950 for decommissioning obligations from previously divested oil and gas production assets in the U.S. Upstream Gulf of America, $1,765 for U.S. Upstream impairments, mainly in California, and several tax items with a net benefit of $655 in International Upstream. Earnings in 2022 included after-tax charges of approximately $1,075 for impairments and other asset write-offs related to International Upstream, $600 for an early contract termination in U.S. Upstream, and $271 for pension settlement costs in All Other. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 91 Other financial information is as follows: Year ended December 31 2024 2023 2022 Total financing interest and debt costs $ 773 $ 617 $ 630 Less: Capitalized interest 179 148 114 Interest and debt expense $ 594 $ 469 $ 516 Research and development expenses $ 353 $ 320 $ 268 Excess of replacement cost over the carrying value of inventories (LIFO method) $ 5,997 $ 6,455 $ 9,061 LIFO profits (losses) on inventory drawdowns included in earnings $ (111) $ 14 $ 122 Foreign currency effects* $ 520 $ (224) $ 669 * Includes $45, $(11) and $253 in 2024, 2023 and 2022, respectively, for the company’s share of equity affiliates’ foreign currency effects. The company has $4,578 in goodwill on the Consolidated Balance Sheet, of which $4,226 is in the upstream segment primarily related to the 2005 acquisition of Unocal and $352 is in the downstream segment related to the 2022 acquisition of Renewable Energy Group, Inc. The company tested this goodwill for impairment during 2024, and no impairment was required. Note 28 Financial Instruments - Credit Losses Chevron’s expected credit loss allowance balance was $611 and $641 at December 31, 2024, and December 31, 2023, respectively, with a majority of the allowance relating to non-trade receivable balances. The majority of the company’s receivable balance is concentrated in trade receivables, with a balance of $18,338 at December 31, 2024, which reflects the company’s diversified sources of revenues and is dispersed across the company’s broad worldwide customer base. As a result, the company believes the concentration of credit risk is limited. The company routinely assesses the financial strength of its customers. When the financial strength of a customer is not considered sufficient, alternative risk mitigation measures may be deployed, including requiring prepayments, letters of credit or other acceptable forms of collateral. Once credit is extended and a receivable balance exists, the company applies a quantitative calculation to current trade receivable balances that reflects credit risk predictive analysis, including probability of default and loss given default, which takes into consideration current and forward-looking market data as well as the company’s historical loss data. This statistical approach becomes the basis of the company’s expected credit loss allowance for current trade receivables with payment terms that are typically short-term in nature, with most due in less than 90 days. Chevron’s non-trade receivable balance was $3,835 at December 31, 2024, which includes receivables from certain governments in their capacity as joint venture partners. Joint venture partner balances that are paid as per contract terms or not yet due are subject to the statistical analysis described above while past due balances are subject to additional qualitative management quarterly review. This management review includes review of reasonable and supportable repayment forecasts. Non-trade receivables also include employee and tax receivables that are deemed immaterial and low risk. Loans to equity affiliates and non-equity investees are also considered non-trade and associated allowances of zero and $219 at December 31, 2024, and December 31, 2023, respectively, are included within “Investments and advances” on the Consolidated Balance Sheet. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 92 Note 29 Acquisition of PDC Energy, Inc. On August 7, 2023, the company acquired PDC Energy, Inc. (PDC), an independent exploration and production company with operations in the Denver-Julesburg Basin in Colorado and the Delaware Basin in west Texas. The aggregate purchase price of PDC was $6,520, with approximately 41 million shares of Chevron common stock issued as consideration in the transaction. The shares represented approximately two percent of the shares of Chevron common stock outstanding immediately after the transaction closed on August 7, 2023. The acquisition was accounted for as a business combination under ASC 805, which requires assets acquired and liabilities assumed to be measured at their acquisition date fair value. Oil and gas properties were valued using a discounted cash flow approach that incorporated internally generated price assumptions and production profiles together with appropriate operating cost and development cost assumptions. Debt assumed in the acquisition was valued based on observable market prices for PDC’s debt. As a result of measuring the assets acquired and the liabilities assumed at fair value, there was no goodwill or bargain purchase recognized. The following table summarizes the fair values assigned to assets acquired and liabilities assumed: At August 7, 2023 Current assets $ 630 Properties, plant and equipment 10,487 Other assets 118 Total assets acquired 11,235 Current liabilities 1,376 Long-term debt 1,473 Deferred income tax 1,397 Other liabilities 469 Total liabilities assumed 4,715 Purchase Price $ 6,520 Pro forma financial information is not disclosed as the acquisition was deemed not to have a material impact on the company’s results of operations. Note 30 Agreement to Acquire Hess Corporation On October 23, 2023, Chevron Corporation announced it had entered into a definitive agreement with Hess Corporation (Hess) to acquire all of its outstanding shares in an all-stock transaction, valued at approximately $53,000, pursuant to which Hess stockholders will receive 1.0250 shares of Chevron common stock for each Hess share. The transaction was unanimously approved by the Boards of Directors of both companies. On May 28, 2024, a majority of Hess stockholders voted to approve the merger. Following the Federal Trade Commission’s (FTC) review of the transaction, on September 30, 2024, the FTC announced that a majority of the Commission voted to accept a consent agreement among the FTC, Chevron and Hess, resolving the concerns the FTC identified during its review of the transaction. Chevron and Hess have taken and will continue to take appropriate steps to maintain our ability to close the merger under the Hart-Scott-Rodino Act of 1976, as amended. The filing of an arbitration relating to the right of first refusal contained in the Stabroek Block operating agreement among Hess Guyana Exploration Limited, a wholly owned subsidiary of Hess, and affiliates of Exxon Mobil Corporation, and China National Offshore Oil Corporation has delayed completion of the transaction. An arbitration decision against Hess Guyana and in favor of Exxon Guyana and CNOOC Guyana would cause the transaction not to be completed. The arbitration merits hearing has been scheduled for May 2025, with a decision expected in approximately the following three months. Chevron and Hess are working to complete the merger as soon as practicable. However, neither Chevron nor Hess can predict the actual date on which the transaction will be completed, if at all, because it is subject to conditions beyond each company’s control. See Item 1A. Risk Factors of the company’s Annual Report on Form 10-K for a discussion of risks related to the Hess acquisition. Notes to the Consolidated Financial Statements Financial Table of Contents Millions of dollars, except per-share amounts Chevron Corporation 2024 Annual Report 93 In accordance with FASB and SEC disclosure requirements for oil and gas producing activities, this section provides supplemental information on oil and gas exploration and producing activities of the company in seven separate tables. Tables I through IV provide historical cost information pertaining to costs incurred in exploration, property acquisitions and development, capitalized costs and results of operations. Tables V through VII present information on the company’s estimated net proved reserve quantities, standardized measure of estimated discounted future net cash flows related to Table I - Costs Incurred in Exploration, Property Acquisitions and Development1 Consolidated Companies Affiliated Companies Other Millions of dollars U.S. Americas Africa Asia Australia Europe Total TCO Other Year Ended December 31, 2024 Exploration Wells $ 193 $ 2 $ 155 $ 94 $ 4 $ — $ 448 $ — $ — Geological and geophysical 173 81 47 23 3 — 327 — — Other 62 62 70 15 30 — 239 — — Total exploration 428 145 272 132 37 — 1,014 — — Property acquisitions2 Proved - Other 11 — 95 — — — 106 — — Unproved - Other 69 38 22 — — — 129 — — Total property acquisitions 80 38 117 — — — 235 — — Development3 9,334 1,261 895 774 1,015 54 13,333 1,480 7 Total Costs Incurred4 $ 9,842 $ 1,444 $ 1,284 $ 906 $ 1,052 $ 54 $ 14,582 $ 1,480 $ 7 Year Ended December 31, 2023 Exploration Wells $ 280 $ 92 $ 36 $ 111 $ 11 $ — $ 530 $ — $ — Geological and geophysical 84 49 83 — — — 216 — — Other 50 104 57 15 32 4 262 — — Total exploration 414 245 176 126 43 4 1,008 — — Property acquisitions2 Proved - Other 10,123 — — — — — 10,123 — — Unproved - Other 504 1 — 3 — — 508 — — Total property acquisitions 10,627 1 — 3 — — 10,631 — — Development3 9,645 986 784 619 822 64 12,920 2,278 86 Total Costs Incurred4 $ 20,686 $ 1,232 $ 960 $ 748 $ 865 $ 68 $ 24,559 $ 2,278 $ 86 Year Ended December 31, 2022 Exploration Wells $ 239 $ 84 $ 78 $ 34 $ 4 $ — $ 439 $ — $ — Geological and geophysical 98 28 110 — 1 — 237 — — Other 53 72 75 30 27 2 259 — — Total exploration 390 184 263 64 32 2 935 — — Property acquisitions2 Proved - Other 18 — 63 13 — — 94 — — Unproved - Other 104 78 73 — — — 255 — — Total property acquisitions 122 78 136 13 — — 349 — — Development3 6,221 863 21 649 719 35 8,508 2,429 34 Total Costs Incurred4 $ 6,733 $ 1,125 $ 420 $ 726 $ 751 $ 37 $ 9,792 $ 2,429 $ 34 1 Includes costs incurred whether capitalized or expensed. Excludes general support equipment expenditures. Includes capitalized amounts related to asset retirement obligations. See Note 25 Asset Retirement Obligations. 2 Includes wells, equipment and facilities associated with proved reserves. Does not include properties acquired in nonmonetary transactions. 3 Includes $59, $208 and $186 of costs incurred on major capital projects prior to assignment of proved reserves for consolidated companies in 2024, 2023, and 2022, respectively. 4 Reconciliation of consolidated companies total cost incurred to Upstream Capex - $ billions: 2024 2023 2022 Total cost incurred by Consolidated Companies $ 14.6 $ 24.6 $ 9.8 PDC Energy, Inc. (PDC) acquisition — (10.5) — Expensed exploration costs (0.6) (0.5) (0.5) (Geological and geophysical and other exploration costs) Non-oil and gas activities 0.6 1.4 0.6 (Primarily LNG and transportation activities) ARO reduction/(build) (0.3) (1.3) (0.3) Upstream Capex $ 14.3 $ 13.7 $ 9.6 Reference page 40 Upstream Capex Supplemental Information on Oil and Gas Producing Activities - Unaudited Chevron Corporation 2024 Annual Report 94 proved reserves, and changes in estimated discounted future net cash flows. The amounts for consolidated companies are organized by geographic areas including the United States, Other Americas, Africa, Asia, Australia/Oceania and Europe. Amounts for affiliated companies include Chevron’s equity interests in Tengizchevroil (TCO) in the Republic of Kazakhstan and in other affiliates, principally in Angola. Refer to Note 15 Investments and Advances for a discussion of the company’s major equity affiliates. Table II - Capitalized Costs Related to Oil and Gas Producing Activities Consolidated Companies Affiliated Companies Other Millions of dollars U.S. Americas Africa Asia Australia Europe Total TCO Other At December 31, 2024 Unproved properties $ 2,473 $ 1,545 $ 287 $ 536 $ 1,882 $ — $ 6,723 $ 108 $ — Proved properties and related producing assets 109,147 15,739 48,391 29,265 24,310 2,283 229,135 35,374 1,612 Support equipment 2,075 213 1,565 698 19,134 — 23,685 733 — Deferred exploratory wells 17 69 204 179 1,119 74 1,662 — — Other uncompleted projects 8,918 650 1,756 1,040 1,814 69 14,247 4,634 — Gross Capitalized Costs 122,630 18,216 52,203 31,718 48,259 2,426 275,452 40,849 1,612 Unproved properties valuation 119 1,119 213 533 5 — 1,989 80 — Proved producing properties – Depreciation and depletion 69,545 10,314 41,485 18,251 14,038 956 154,589 11,441 1,014 Support equipment depreciation 1,265 152 1,231 556 6,375 — 9,579 535 — Accumulated provisions 70,929 11,585 42,929 19,340 20,418 956 166,157 12,056 1,014 Net Capitalized Costs $ 51,701 $ 6,631 $ 9,274 $ 12,378 $ 27,841 $ 1,470 $ 109,295 $ 28,793 $ 598 At December 31, 2023 Unproved properties $ 2,541 $ 1,666 $ 265 $ 536 $ 1,882 $ — $ 6,890 $ 108 $ — Proved properties and related producing assets 100,680 23,867 47,635 30,387 23,842 2,228 228,639 23,139 1,609 Support equipment 2,121 191 1,555 688 19,118 — 23,673 673 — Deferred exploratory wells — 73 205 178 1,119 74 1,649 — — Other uncompleted projects 10,872 734 1,271 1,121 1,469 52 15,519 15,438 130 Gross Capitalized Costs 116,214 26,531 50,931 32,910 47,430 2,354 276,370 39,358 1,739 Unproved properties valuation 168 1,214 183 533 5 — 2,103 77 — Proved producing properties – Depreciation and depletion 65,055 14,009 39,921 18,941 12,082 834 150,842 10,279 866 Support equipment depreciation 1,295 155 1,202 529 5,478 — 8,659 478 — Accumulated provisions 66,518 15,378 41,306 20,003 17,565 834 161,604 10,834 866 Net Capitalized Costs $ 49,696 $ 11,153 $ 9,625 $ 12,907 $ 29,865 $ 1,520 $ 114,766 $ 28,524 $ 873 At December 31, 2022 Unproved properties $ 2,541 $ 2,176 $ 265 $ 970 $ 1,987 $ — $ 7,939 $ 108 $ — Proved properties and related producing assets 83,525 22,867 46,950 31,179 22,926 2,186 209,633 15,793 1,552 Support equipment 2,146 194 1,543 696 19,107 — 23,686 646 — Deferred exploratory wells 43 56 116 40 1,119 74 1,448 — — Other uncompleted projects 8,213 610 1,095 914 1,869 30 12,731 20,590 54 Gross Capitalized Costs 96,468 25,903 49,969 33,799 47,008 2,290 255,437 37,137 1,606 Unproved properties valuation 178 1,589 146 969 110 — 2,992 74 — Proved producing properties – Depreciation and depletion 58,253 12,974 38,543 19,051 10,689 720 140,230 9,441 654 Support equipment depreciation 1,302 155 1,166 500 4,644 — 7,767 424 — Accumulated provisions 59,733 14,718 39,855 20,520 15,443 720 150,989 9,939 654 Net Capitalized Costs $ 36,735 $ 11,185 $ 10,114 $ 13,279 $ 31,565 $ 1,570 $ 104,448 $ 27,198 $ 952 Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 95 Consolidated Companies Affiliated Companies Other Millions of dollars U.S. Americas Africa Asia Australia Europe Total TCO Other Year Ended December 31, 2024 Revenues from net production Sales $ 6,657 $ 799 $ 622 $ 3,376 $ 5,856 $ 319 $ 17,629 $ 7,240 $ 700 Transfers 18,043 3,110 5,227 2,101 4,237 — 32,718 — — Total 24,700 3,909 5,849 5,477 10,093 319 50,347 7,240 700 Production expenses excluding taxes (5,472) (928) (1,662) (939) (540) (74) (9,615) (696) (46) Taxes other than on income (1,445) (67) (165) (24) (209) (3) (1,913) (1,117) — Proved producing properties: Depreciation and depletion (7,231) (981) (1,616) (1,236) (2,547) (103) (13,714) (1,222) (154) Accretion expense2 (205) (26) (127) (63) (104) (8) (533) (5) (3) Exploration expenses (352) (141) (308) (233) (33) (1) (1,068) — — Unproved properties valuation (68) (31) (30) (1) — — (130) — — Other income (loss)3 247 1,556 534 139 (8) (4) 2,464 (80) (150) Results before income taxes 10,174 3,291 2,475 3,120 6,652 126 25,838 4,120 347 Income tax (expense) benefit (2,238) (954) (1,240) (1,684) (2,010) (95) (8,221) (1,238) 12 Results of Producing Operations $ 7,936 $ 2,337 $ 1,235 $ 1,436 $ 4,642 $ 31 $ 17,617 $ 2,882 $ 359 Year Ended December 31, 2023 Revenues from net production Sales $ 6,658 $ 724 $ 515 $ 3,309 $ 6,780 $ 368 $ 18,354 $ 6,831 $ 891 Transfers 15,948 3,243 5,979 2,151 4,753 — 32,074 — — Total 22,606 3,967 6,494 5,460 11,533 368 50,428 6,831 891 Production expenses excluding taxes (5,459) (1,000) (1,619) (1,103) (556) (64) (9,801) (602) (44) Taxes other than on income (1,222) (69) (142) (27) (256) (4) (1,720) (675) — Proved producing properties: Depreciation and depletion (7,133) (1,042) (1,414) (1,114) (2,561) (115) (13,379) (895) (173) Accretion expense2 (176) (25) (126) (120) (92) (8) (547) (7) (3) Exploration expenses (439) (274) (151) (33) (32) (5) (934) — — Unproved properties valuation (71) (68) (44) — — — (183) — — Other income (loss)3 (2,673) (69) 45 89 (52) 4 (2,656) 32 (185) Results before income taxes 5,433 1,420 3,043 3,152 7,984 176 21,208 4,684 486 Income tax (expense) benefit (1,195) (389) (832) (1,576) (2,776) (196) (6,964) (1,408) 24 Results of Producing Operations $ 4,238 $ 1,031 $ 2,211 $ 1,576 $ 5,208 $ (20) $ 14,244 $ 3,276 $ 510 1 The value of owned production consumed in operations as fuel has been eliminated from revenues and production expenses, and the related volumes have been deducted from net production in calculating the unit average sales price and production cost. This has no effect on the results of producing operations. 2 Represents accretion of ARO liability. Refer to Note 25 Asset Retirement Obligations. 3 Includes foreign currency gains and losses, gains and losses on property dispositions and other miscellaneous income and expenses. 2023 also includes a loss related to decommissioning obligations from certain previously divested oil and gas production assets in the Gulf of America. Supplemental Information on Oil and Gas Producing Activities - Unaudited Table III - Results of Operations for Oil and Gas Producing Activities1 The company’s results of operations from oil and gas producing activities for the years 2024, 2023 and 2022 are shown in the following table. Net income (loss) from exploration and production activities as reported on page 71 reflects income taxes computed on an effective rate basis. Income taxes in Table III are based on statutory tax rates, reflecting allowable deductions and tax credits. Interest income and expense are excluded from the results reported in Table III and from the upstream net income amounts on page 71. Chevron Corporation 2024 Annual Report 96 Table III - Results of Operations for Oil and Gas Producing Activities1, continued Consolidated Companies Affiliated Companies Other Millions of dollars U.S. Americas Africa Asia Australia Europe Total TCO Other Year Ended December 31, 2022 Revenues from net production Sales $ 9,656 $ 1,172 $ 2,192 $ 3,963 $ 7,302 $ 564 $ 24,849 $ 8,304 $ 2,080 Transfers 18,494 3,801 6,829 2,477 7,535 — 39,136 — — Total 28,150 4,973 9,021 6,440 14,837 564 63,985 8,304 2,080 Production expenses excluding taxes (4,752) (1,071) (1,515) (1,316) (614) (60) (9,328) (485) (47) Taxes other than on income (1,286) (85) (170) (52) (352) (4) (1,949) (933) — Proved producing properties: Depreciation and depletion (4,612) (1,223) (1,943) (1,765) (2,520) (117) (12,180) (964) (164) Accretion expense2 (167) (22) (147) (87) (77) (11) (511) (6) (3) Exploration expenses (402) (169) (243) (92) (52) (2) (960) — — Unproved properties valuation (38) (250) (15) (124) — — (427) — — Other income (loss)3 92 21 300 180 51 105 749 195 (27) Results before income taxes 16,985 2,174 5,288 3,184 11,273 475 39,379 6,111 1,839 Income tax (expense) benefit (3,736) (670) (3,114) (1,742) (3,185) (193) (12,640) (1,835) 12 Results of Producing Operations $ 13,249 $ 1,504 $ 2,174 $ 1,442 $ 8,088 $ 282 $ 26,739 $ 4,276 $ 1,851 1 The value of owned production consumed in operations as fuel has been eliminated from revenues and production expenses, and the related volumes have been deducted from net production in calculating the unit average sales price and production cost. This has no effect on the results of producing operations. 2 Represents accretion of ARO liability. Refer to Note 25 Asset Retirement Obligations. 3 Includes foreign currency gains and losses, gains and losses on property dispositions and other miscellaneous income and expenses. Table IV - Results of Operations for Oil and Gas Producing Activities - Unit Prices and Costs1 Consolidated Companies Affiliated Companies Other U.S. Americas Africa Asia Australia Europe Total TCO Other Year Ended December 31, 2024 Average sales prices Crude, per barrel $ 73.47 $ 70.06 $ 75.69 $ 71.22 $ 74.20 $ 77.47 $ 73.27 $ 67.02 $ — Natural gas liquids, per barrel 19.88 26.53 32.13 — 59.48 — 20.51 12.09 47.61 Natural gas, per thousand cubic feet 1.03 1.03 4.14 4.21 10.24 9.10 4.99 1.57 7.75 Average production costs, per barrel2 9.41 14.28 18.07 6.80 3.37 16.43 9.23 5.44 2.89 Year Ended December 31, 2023 Average sales prices Crude, per barrel $ 74.36 $ 72.85 $ 72.86 $ 70.05 $ 78.93 $ 83.00 $ 73.76 $ 66.44 $ — Natural gas liquids, per barrel 20.01 29.00 27.80 — 51.00 — 20.79 9.43 45.33 Natural gas, per thousand cubic feet 1.65 2.63 3.95 4.10 11.43 12.00 6.01 1.31 10.34 Average production costs, per barrel2 11.19 16.13 16.35 7.82 3.41 12.80 10.23 4.47 2.94 Year Ended December 31, 2022 Average sales prices Crude, per barrel $ 91.88 $ 90.04 $ 100.82 $ 85.64 $ 98.00 $ 102.00 $ 92.92 $ 85.71 $ — Natural gas liquids, per barrel 33.76 34.33 35.43 — — — 34.31 20.83 65.33 Natural gas, per thousand cubic feet 5.53 5.15 9.00 4.02 15.34 27.00 8.85 0.95 29.44 Average production costs, per barrel2 11.10 17.00 14.43 8.49 3.79 12.00 10.16 3.85 3.36 1 The value of owned production consumed in operations as fuel has been eliminated from revenues and production expenses, and the related volumes have been deducted from net production in calculating the unit average sales price and production cost. This has no effect on the results of producing operations. 2 Natural gas converted to oil-equivalent gas (OEG) barrels at a rate of 6 MCF = 1 OEG barrel. Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 97 Table V Proved Reserve Quantity Information* Summary of Net Oil and Gas Reserves 2024 2023 2022 Liquids in Millions of Barrels Natural Gas in Billions of Cubic Feet Crude Oil Condensate Synthetic Oil NGL Natural Gas Crude Oil Condensate Synthetic Oil NGL Natural Gas Crude Oil Condensate Synthetic Oil NGL Natural Gas Proved Developed Consolidated Companies U.S. 1,207 — 615 4,420 1,221 — 611 4,543 1,198 — 450 3,288 Other Americas 181 — — 168 195 598 7 298 174 574 7 305 Africa 392 — 67 1,491 367 — 70 1,632 392 — 72 1,734 Asia 246 — — 6,560 240 — — 6,974 235 — — 6,578 Australia 72 — 1 6,517 85 — 2 6,951 99 — 3 7,898 Europe 23 — — 10 25 — — 9 26 — — 9 Total Consolidated 2,121 — 683 19,166 2,133 598 690 20,407 2,124 574 532 19,812 Affiliated Companies TCO 663 — 70 1,118 478 — 67 1,062 515 — 52 895 Other 2 — 12 670 3 — 13 323 3 — 13 349 Total Consolidated and Affiliated Companies 2,786 — 765 20,954 2,614 598 770 21,792 2,642 574 597 21,056 Proved Undeveloped Consolidated Companies U.S. 639 — 373 2,730 721 — 413 3,139 875 — 435 3,543 Other Americas 106 — — 146 129 — 8 276 121 — 10 240 Africa 63 — 19 703 78 — 27 625 62 — 25 756 Asia 52 — — 1,351 61 — — 1,419 58 — — 1,959 Australia 20 — — 2,422 22 — — 2,444 22 — — 2,444 Europe 26 — — 8 28 — — 8 32 — — 11 Total Consolidated 906 — 392 7,360 1,039 — 448 7,911 1,170 — 470 8,953 Affiliated Companies TCO 224 — 2 20 526 — 11 233 611 — 21 368 Other — — — 41 — — — 445 — — — 487 Total Consolidated and Affiliated Companies 1,130 — 394 7,421 1,565 — 459 8,589 1,781 — 491 9,808 Total Proved Reserves 3,916 — 1,159 28,375 4,179 598 1,229 30,381 4,423 574 1,088 30,864 * Reserve quantities include natural gas projected to be consumed in operations of 2,462, 2,655 and 2,737 billions of cubic feet and equivalent synthetic oil projected to be consumed in operations of 0, 27, and 28 millions of barrels as of December 31, 2024, 2023 and 2022, respectively. Reserves Governance The company has adopted a comprehensive reserves and resources classification system modeled after a system developed and approved by a number of organizations, including the Society of Petroleum Engineers, the World Petroleum Congress and the American Association of Petroleum Geologists. The company classifies discovered recoverable hydrocarbons into six categories based on their status at the time of reporting – three deemed commercial and three potentially recoverable. Within the commercial classification are proved reserves and two categories of unproved reserves: probable and possible. The potentially recoverable categories are also referred to as contingent resources. For reserves estimates to be classified as proved, they must meet all SEC and company standards. Proved oil and gas reserves are the estimated quantities that geoscience and engineering data demonstrate with reasonable certainty to be economically producible in the future from known reservoirs under existing economic conditions, operating methods and government regulations. Net proved reserves exclude royalties and interests owned by others and reflect contractual arrangements and royalty obligations in effect at the time of the estimate. Proved reserves are classified as either developed or undeveloped. Proved developed reserves are the quantities expected to be recovered through existing wells with existing equipment and operating methods, or in which the cost of the required equipment is relatively minor compared to the cost of a new well. Proved undeveloped reserves are the quantities expected to be recovered from new wells on undrilled acreage or from existing wells where a relatively major expenditure is required for recompletion. Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 98 Due to the inherent uncertainties and the limited nature of reservoir data, estimates of reserves are subject to change as additional information becomes available. Proved reserves are estimated by company asset teams composed of earth scientists and engineers. As part of the internal control process related to reserves estimation, the company maintains a Reserves Advisory Committee (RAC) that is chaired by the Manager of Global Reserves, an organization that is separate from the business units that estimate reserves. The Manager of Global Reserves has more than 35 years of experience working in the oil and gas industry and holds both undergraduate and graduate degrees in geoscience. His experience includes various technical and management roles in providing reserve and resource estimates in support of major capital and exploration projects, and more than 10 years of overseeing oil and gas reserves processes. He has been named a Distinguished Lecturer by the American Association of Petroleum Geologists and is an active member of the American Association of Petroleum Geologists, the SEPM Society of Sedimentary Geologists and the Society of Petroleum Engineers. All RAC members are degreed professionals, each with more than 10 years of experience in various aspects of reserves estimation relating to reservoir engineering, petroleum engineering, earth science or finance. The members are knowledgeable in SEC guidelines for proved reserves classification and receive annual training on the preparation of reserves estimates. The RAC has the following primary responsibilities: establish the policies and processes used within the business units to estimate reserves; provide independent reviews and oversight of the business units’ recommended reserves estimates and changes; confirm that proved reserves are recognized in accordance with SEC guidelines; determine that reserve quantities are calculated using consistent and appropriate standards, procedures and technology; and maintain the Chevron Corporation Reserves Manual, which provides standardized procedures used corporatewide for classifying and reporting hydrocarbon reserves. During the year, the RAC is represented in meetings with each of the company’s business units to review and discuss reserve changes recommended by the various asset teams. Major changes are also reviewed with the company’s senior leadership team including the Chief Executive Officer and the Chief Financial Officer. The company’s annual reserves activity is also reviewed with the company’s Audit Committee and Board of Directors. If major changes to reserves were to occur between the annual reviews, those matters would also be discussed with the Board. RAC sub-teams also conduct in-depth reviews during the year of many of the fields that have large proved reserves quantities. These reviews include an examination of the proved reserve records and documentation of their compliance with the Chevron Corporation Reserves Manual. Technologies Used in Establishing Proved Reserves Additions In 2024, additions to Chevron’s proved reserves were based on a wide range of geologic and engineering technologies. Information generated from wells, such as well logs, wire line sampling, production and pressure testing, fluid analysis, and core analysis, was integrated with seismic data, regional geologic studies, and information from analogous reservoirs to provide “reasonably certain” proved reserves estimates. Both proprietary and commercially available analytic tools, including reservoir simulation, geologic modeling and seismic processing, have been used in the interpretation of the subsurface data. These technologies have been utilized extensively by the company in the past, and the company believes that they provide a high degree of confidence in establishing reliable and consistent reserves estimates. Proved Undeveloped Reserves Noteworthy changes in proved undeveloped reserves are shown in the table below and discussed below. Proved Undeveloped Reserves (Millions of BOE) 2024 Quantity at January 1 3,456 Revisions (154) Improved recovery 3 Extension and discoveries 390 Purchases 70 Sales (54) Transfers to proved developed (950) Quantity at December 31 2,761 Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 99 Supplemental Information on Oil and Gas Producing Activities - Unaudited In 2024, revisions in the United States were primarily from the Denver-Julesburg (DJ) basin yielding a decrease of 98 million BOE mainly due to reservoir performance and portfolio optimization. A net decrease of 33 million BOE in the Midland and Delaware basins was due to reservoir performance. In 2024, extensions and discoveries of 316 million BOE in the United States were primarily due to planned development of new locations in shale and tight assets in the DJ basin of 171 million BOE, the Midland and Delaware basins of 123 million BOE, and deepwater assets in the Gulf of America of 22 million BOE. In Other Americas, 58 million BOE of extensions and discoveries were from shale and tight assets in Argentina. In 2024, purchases of 70 million BOE in the United States are primarily from newly identified proved undeveloped well locations associated with the acquisition of PDC. The difference in 2024 extensions and discoveries of 161 million BOE, between the net quantities of proved reserves of 551 million BOE as reflected on pages 102 to 104 and net quantities of proved undeveloped reserves of 390 million BOE, is primarily due to proved extensions and discoveries that were not recognized as proved undeveloped reserves in the prior year and were recognized directly as proved developed reserves in 2024. Transfers to proved developed reserves in 2024 include 464 million BOE in the United States, from 256 million BOE in the Midland and Delaware basins, 126 million BOE in the DJ basin, and 82 million BOE in the Gulf of America. Other significant transfers to proved developed were 329 million BOE in Kazakhstan, primarily at TCO, and 75 million BOE in Angola, primarily at Angola LNG. A combined 81 million BOE of transfers to proved developed were recorded in Argentina, Canada, Australia, Nigeria, China, and other international locations. These transfers are the consequence of development expenditures on completing wells and facilities. During 2024, the company’s investments totaled approximately $8.2 billion in oil and gas producing activities, and about $0.1 billion in non-oil and gas producing activities, to advance the development of proved undeveloped reserves. The United States accounted for about $5.5 billion primarily related to various development activities in the Midland and Delaware basins, the Gulf of America and the DJ basin. In Africa, about $0.8 billion was expended on various offshore development and natural gas projects in Nigeria and Angola. An additional $0.5 billion was spent on development activities in Australia. Development activities in other international locations were primarily responsible for about $1.4 billion of expenditures. The company’s equity affiliates investments in oil and gas producing activities to advance development of proved undeveloped reserves in 2024 was $1.3 billion primarily related to development projects for TCO in Kazakhstan. Reserves that remain proved undeveloped for five or more years are a result of several factors that affect optimal project development and execution. These factors may include the complex nature of the development project in adverse and remote locations, physical limitations of infrastructure or plant capacities that dictate project timing, compression projects that are pending reservoir pressure declines, and contractual limitations that dictate production levels. At year-end 2024, the company held approximately 624 million BOE of proved undeveloped reserves that have remained undeveloped for five years or more. The majority of these reserves are in locations where the company has a proven track record of developing major projects. In Australia, approximately 223 million BOE remain undeveloped for five years or more related to the Gorgon and Wheatstone Projects. Further field development to convert the remaining proved undeveloped reserves is scheduled to occur in line with operating constraints, reservoir depletion and infrastructure optimization. In Africa, approximately 138 million BOE have remained undeveloped for five years or more, due to facility constraints at various fields and infrastructure associated with the Escravos gas projects in Nigeria. Affiliates account for about 237 million BOE of proved undeveloped reserves with about 197 million BOE that have remained undeveloped for five years or more related to TCO. At TCO, further field development to convert the remaining proved undeveloped reserves is scheduled to occur in line with reservoir depletion and facility constraints. Annually, the company assesses whether any changes have occurred in facts or circumstances, such as changes to development plans, regulations, or government policies, that would warrant a revision to reserve estimates. In 2024, lower natural gas prices in North America were primarily responsible for the negative impact to the economic limits of oil and gas properties, resulting in a proved reserve decrease of approximately 58 million BOE. The year-end reserves quantities have been updated for these circumstances and significant changes are discussed in the appropriate reserves sections herein. Over the past three years, the ratio of proved undeveloped reserves to total proved reserves has ranged between 28 percent and 35 percent. Chevron Corporation 2024 Annual Report 100 Supplemental Information on Oil and Gas Producing Activities - Unaudited Proved Reserve Quantities For the three-year period ended December 31, 2024, the pattern of net reserve changes shown in the following tables is not necessarily indicative of future trends. Apart from acquisitions, the company’s ability to add proved reserves can be affected by events and circumstances that are outside the company’s control, such as delays in government permitting, partner approvals of development plans, changes in oil and gas prices, OPEC constraints, geopolitical uncertainties, civil unrest, events of war or military conflicts. At December 31, 2024, proved reserves for the company were 9.8 billion BOE. The company’s estimated net proved reserves of liquids, including crude oil, condensate and synthetic oil for the years 2022, 2023 and 2024, are shown in the table on page 102. The company’s estimated net proved reserves of natural gas liquids (NGLs) are shown on page 103, and the company’s estimated net proved reserves of natural gas are shown on page 104. Noteworthy changes in crude oil, condensate and synthetic oil proved reserves for 2022 through 2024 are discussed below and shown in the table on the following page: Revisions In 2022, entitlement effects primarily contributed to a decrease of 49 million barrels of synthetic oil at the Athabasca Oil Sands project in Canada. In TCO, entitlement effects and changes in operating assumptions were primarily responsible for the 35 million barrels decrease in Kazakhstan. In 2023, the 257 million barrels decrease in United States was primarily in the Midland and Delaware basins and California. Reservoir performance led to the decrease of 101 million barrels, and portfolio optimization led to a decrease of 59 million barrels in the Midland and Delaware basins. A reduction in planned development activities led to a decrease of 58 million barrels in California. In Other Americas, entitlement effects primarily contributed to an increase of 42 million barrels of synthetic oil at the Athabasca Oil Sands project in Canada. In Asia, reservoir performance, mainly in the Partitioned Zone between Saudi Arabia and Kuwait (the Partitioned Zone), was responsible for the 48 million barrels increase. Reservoir performance in Nigeria was mainly responsible for the 37 million barrels increase in Africa. In 2024, the 37 million barrels increase in Asia was due to reservoir performance, primarily in the Partitioned Zone. Extensions and Discoveries In 2022, extensions and discoveries in the Midland, Delaware and DJ basins, and approval of the Ballymore Project in the Gulf of America, were primarily responsible for the 264 million barrels increase in the United States. In Other Americas, the 32 million barrels of extensions and discoveries were from Argentina and Canada. In 2023, extensions and discoveries of 124 million barrels in the Midland and Delaware basins were primarily responsible for the 170 million barrels increase in the United States. In Other Americas, the 55 million barrels of extensions and discoveries increase was mainly from shale and tight assets in Argentina. In 2024, extensions and discoveries of 119 million barrels in the Midland and Delaware basins, and 45 million barrels in the DJ basin, were primarily responsible for the 185 million barrels increase in the United States. In Other Americas, the 52 million barrels of extensions and discoveries increase was mainly from shale and tight assets in Argentina. Purchases In 2022, the company exercised its option to acquire additional land acreage in the Athabasca Oil Sands project in Canada contributing 168 million barrels in synthetic oil. The extension of deepwater licenses in Nigeria and the Republic of Congo contributed 36 million barrels in Africa. In 2023, the acquisition of PDC in the DJ and Delaware basins was primarily responsible for the 207 million barrels increase in the United States. In 2024, the renewal of the Agbami field deepwater license in Nigeria increased reserves by 51 million barrels. Sales In 2024, sales of 593 million barrels in synthetic oil were from the Athabasca oil sand assets in Canada and the 46 million barrels in Other Americas were from the divestment of shale and tight assets in Canada. Chevron Corporation 2024 Annual Report 101 Net Proved Reserves of Crude Oil, Condensate and Synthetic Oil Consolidated Companies Affiliated Companies Total Consolidated Other Synthetic Synthetic and Affiliated Millions of barrels U.S. Americas1 Africa Asia Australia Europe Oil 2,5 Total TCO Oil Other3 Companies Reserves at January 1, 2022 2,064 288 480 322 134 62 471 3,821 1,250 — 4 5,075 Changes attributable to: Revisions (26) (9) 4 8 2 1 (49) (69) (35) — — (104) Improved recovery 2 15 4 5 — — — 26 — — — 26 Extensions and discoveries 264 32 6 — — — — 302 10 — — 312 Purchases 22 5 36 — — — 168 231 — — — 231 Sales (16) — (3) — — — — (19) — — — (19) Production (237) (36) (73) (42) (15) (5) (16) (424) (99) — (1) (524) Reserves at December 31, 2022 4, 5 2,073 295 454 293 121 58 574 3,868 1,126 — 3 4,997 Changes attributable to: Revisions (257) 9 37 48 1 (1) 42 (121) (20) — 1 (140) Improved recovery 9 — 2 — — — — 11 — — — 11 Extensions and discoveries 170 55 — — — — — 225 — — — 225 Purchases 207 — 24 — — — — 231 — — — 231 Sales (1) — — — — — — (1) — — — (1) Production (259) (35) (72) (40) (15) (4) (18) (443) (102) — (1) (546) Reserves at December 31, 2023 4, 5 1,942 324 445 301 107 53 598 3,770 1,004 — 3 4,777 Changes attributable to: Revisions 2 (7) 21 37 — — (4) 49 (13) — — 36 Improved recovery 9 1 1 — — — — 11 — — — 11 Extensions and discoveries 185 52 4 — — — — 241 — — — 241 Purchases 21 — 51 — — — 16 88 — — — 88 Sales (27) (46) — — — — (593) (666) — — — (666) Production (286) (37) (67) (40) (15) (4) (17) (466) (104) — (1) (571) Reserves at December 31, 2024 4, 5 1,846 287 455 298 92 49 — 3,027 887 — 2 3,916 1 Ending reserve balances in North America were 132, 188 and 185 and in South America were 155, 136 and 110 in 2024, 2023 and 2022, respectively. 2 Reserves associated with Canada. 3 Reserves associated with Africa. 4 Included are year-end reserve quantities related to production-sharing contracts (PSC) (refer to page E-8 for the definition of a PSC). PSC-related reserve quantities are 8 percent, 6 percent and 6 percent for consolidated companies for 2024, 2023 and 2022, respectively. 5 Reserve quantities include synthetic oil projected to be consumed in operations of 0, 27, and 28 millions of barrels as of December 31, 2024, 2023 and 2022, respectively. Noteworthy changes in NGLs proved reserves for 2022 through 2024 are discussed below and shown in the table on the following page: Revisions In 2023, the 110 million barrels decrease in the United States was primarily in the Midland and Delaware basins with a decrease of 49 million barrels due to portfolio optimization and a decrease of 29 million barrels due to reservoir performance. In 2024, the 41 million barrels decrease in the United States was primarily from a decrease of 65 million barrels in the DJ basin, which was partially offset by an increase of 31 million barrels from the Gulf of America. Extensions and Discoveries In 2022, extensions and discoveries in the Midland and Delaware basins were primarily responsible for the 163 million barrels increase in the United States. In 2023, extensions and discoveries in the Midland and Delaware basins were primarily responsible for the 92 million barrels increase in the United States. In 2024, extensions and discoveries in the Midland and Delaware basins of 72 million barrels, and in the DJ basin of 52 million barrels, were responsible for the 124 million barrels increase in the United States. Purchases In 2023, the acquisition of PDC in the DJ and Delaware basins was primarily responsible for the 262 million barrels increase in the United States. Sales In 2022, sales of 35 million barrels in the United States were primarily from the divestment of the Eagle Ford shale assets and some properties in the Midland and Delaware basins. Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 102 Net Proved Reserves of Natural Gas Liquids Consolidated Companies Affiliated Companies Total Consolidated Other and Affiliated Millions of barrels U.S. Americas1 Africa Asia Australia Europe Total TCO Other2 Companies Reserves at January 1, 2022 812 15 106 — 3 — 936 84 18 1,038 Changes attributable to: Revisions 18 — (3) — — — 15 (5) (3) 7 Improved recovery — — — — — — — — — — Extensions and discoveries 163 2 1 — — — 166 — — 166 Purchases 14 2 — — — — 16 — — 16 Sales (35) — — — — — (35) — — (35) Production (87) (2) (7) — — — (96) (6) (2) (104) Reserves at December 31, 20223 885 17 97 — 3 — 1,002 73 13 1,088 Changes attributable to: Revisions (110) — (6) — — — (116) 12 2 (102) Improved recovery — — — — — — — — — — Extensions and discoveries 92 — — — — — 92 — — 92 Purchases 262 — 11 — — — 273 — — 273 Sales — — — — — — — — — — Production (105) (2) (5) — (1) — (113) (7) (2) (122) Reserves at December 31, 20233 1,024 15 97 — 2 — 1,138 78 13 1,229 Changes attributable to: Revisions (41) — (7) — — — (48) 1 1 (46) Improved recovery — — — — — — — — — — Extensions and discoveries 124 — — — — — 124 — — 124 Purchases 20 — — — — — 20 — — 20 Sales (3) (13) — — — — (16) — — (16) Production (136) (2) (4) — (1) — (143) (7) (2) (152) Reserves at December 31, 20243 988 — 86 — 1 — 1,075 72 12 1,159 1 Reserves associated with North America. 2 Reserves associated with Africa. 3 Year-end reserve quantities related to PSC are not material for 2024, 2023 and 2022, respectively. Noteworthy changes in natural gas proved reserves for 2022 through 2024 are discussed below and shown in the table on the following page: Revisions In 2022, the performance of the Leviathan and Tamar fields in Israel and the Bibiyana and Jalalabad fields in Bangladesh were mainly responsible for the 1.8 TCF increase in Asia. In Australia, the 377 BCF decrease was mainly due to updated reservoir characterization of the Wheatstone field. In TCO, entitlement effects and changes in operating assumptions were primarily responsible for the 285 BCF decrease. In 2023, portfolio optimization decrease of 276 BCF and a reservoir performance decrease of 186 BCF in the Midland and Delaware basins along with a reduction in planned development activities leading to a decrease of 485 BCF in the Haynesville shale formation of east Texas, were mainly responsible for the 1.2 TCF decrease in the United States. In Asia, final investment decision on a new gas pipeline project in Israel and reservoir performance in Bangladesh were mainly responsible for the 481 BCF increase. In 2024, a decrease of 425 BCF in the DJ basin, primarily related to reservoir performance, was mainly responsible for the 572 BCF decrease in the United States. The 504 BCF increase in Australia was mainly due to reservoir performance of the Jansz Io field. Extensions and Discoveries In 2022, extensions and discoveries of 1.6 TCF in the United States were primarily in the Midland and Delaware basins. In 2023, extensions and discoveries of 660 BCF in the United States were primarily in the Midland and Delaware basins. In 2024, extensions and discoveries of 912 BCF in the United States were primarily in the DJ basin with 476 BCF, and the Midland and Delaware basins with 432 BCF. Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 103 Purchases In 2023, the acquisition of PDC in the DJ basin was primarily responsible for the 2.2 TCF in the United States. In 2024, the 177 BCF in the United States was primarily associated with the acquisition of PDC in the DJ basin. Sales In 2022, sales of 243 BCF in the United States were primarily in the Eagle Ford shale and Midland and Delaware basins. In 2024, sales of 260 BCF in Other Americas were from the divestment of shale and tight assets in Canada. Net Proved Reserves of Natural Gas Consolidated Companies Affiliated Companies Total Consolidated Other and Affiliated Billions of cubic feet (BCF) U.S. Americas1 Africa Asia Australia Europe Total TCO Other2 Companies Reserves at January 1, 2022 5,885 455 2,796 7,473 11,684 21 28,314 1,701 893 30,908 Changes attributable to: Revisions 171 62 (118) 1,765 (377) 2 1,505 (285) 3 1,223 Improved recovery 1 — — — — — 1 — — 1 Extensions and discoveries 1,573 64 — — — — 1,637 — 17 1,654 Purchases 85 25 30 — — — 140 — — 140 Sales (243) — (11) — — — (254) — — (254) Production3 (641) (61) (207) (701) (965) (3) (2,578) (153) (77) (2,808) Reserves at December 31, 2022 4, 5 6,831 545 2,490 8,537 10,342 20 28,765 1,263 836 30,864 Changes attributable to: Revisions (1,198) (1) (154) 481 31 1 (840) 166 18 (656) Improved recovery 2 — — — — — 2 — — 2 Extensions and discoveries 660 83 — — — — 743 — — 743 Purchases 2,161 — 97 — — — 2,258 — — 2,258 Sales (3) — — — — — (3) — — (3) Production3 (771) (53) (176) (625) (978) (4) (2,607) (134) (86) (2,827) Reserves at December 31, 2023 4, 5 7,682 574 2,257 8,393 9,395 17 28,318 1,295 768 30,381 Changes attributable to: Revisions (572) (54) (19) 118 504 3 (20) (21) 30 (11) Improved recovery 2 — — — — — 2 — — 2 Extensions and discoveries 912 119 83 — — — 1,114 — — 1,114 Purchases 177 — 32 — — — 209 — — 209 Sales (70) (260) — — — — (330) — — (330) Production3 (981) (65) (159) (600) (960) (2) (2,767) (136) (87) (2,990) Reserves at December 31, 2024 4, 5 7,150 314 2,194 7,911 8,939 18 26,526 1,138 711 28,375 1 Ending reserve balances in North America and South America were 49, 363 and 407 and 265, 211 and 138 in 2024, 2023 and 2022, respectively. 2 Reserves associated with Africa. 3 Total “as sold” volumes were 2,768, 2,609 and 2,600 for 2024, 2023 and 2022, respectively. 4 Includes reserve quantities related to PSC. PSC-related reserve quantities were 6 percent, 7 percent and 8 percent for consolidated companies for 2024, 2023 and 2022, respectively. 5 Reserve quantities include natural gas projected to be consumed in operations of 2,462, 2,655 and 2,737 billions of cubic feet as of December 31, 2024, 2023 and 2022, respectively. Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 104 Table VI - Standardized Measure of Discounted Future Net Cash Flows Related to Proved Oil and Gas Reserves The standardized measure of discounted future net cash flows is calculated in accordance with SEC and FASB requirements. This includes using the unweighted arithmetic average of the first-day-of-the-month oil and gas prices for the 12-month period prior to the end of the reporting period, estimated future development and production costs assuming the continuation of existing economic conditions, estimated costs for asset retirement obligations (includes costs to retire existing wells and facilities in addition to those future wells and facilities necessary to produce proved undeveloped reserves), and estimated future income taxes based on appropriate statutory tax rates. Discounted future net cash flows are calculated using 10 percent mid-period discount factors. Estimates of proved reserve quantities are imprecise and change over time as new information becomes available. Probable and possible reserves, which may become proved in the future, are excluded from the calculations. The valuation requires assumptions as to the timing and amount of future development and production costs, which could change over time as new information becomes available. The calculations are made as of December 31 each year and do not represent management’s estimate of the company’s future cash flows or value of its oil and gas reserves. In the following table, the caption “Standardized Measure Net Cash Flows” refers to the standardized measure of discounted future net cash flows. Consolidated Companies Affiliated Companies Total Consolidated Other and Affiliated Millions of dollars U.S. Americas Africa Asia Australia Europe Total TCO Other Companies At December 31, 2024 Future cash inflows from production $ 163,846 $ 21,827 $ 43,539 $ 58,245 $ 84,026 $ 3,999 $ 375,482 $ 65,221 $ 5,308 $ 446,011 Future production costs (52,680) (5,896) (17,996) (13,355) (10,964) (1,188) (102,079) (19,945) (392) (122,416) Future development costs (15,377) (2,131) (3,554) (2,290) (6,333) (420) (30,105) (1,560) (30) (31,695) Future income taxes (18,919) (4,443) (12,345) (25,354) (25,891) (1,004) (87,956) (13,115) (1,710) (102,781) Undiscounted future net cash flows 76,870 9,357 9,644 17,246 40,838 1,387 155,342 30,601 3,176 189,119 10 percent midyear annual discount for timing of estimated cash flows (28,615) (3,492) (3,573) (8,157) (15,114) (503) (59,454) (8,722) (1,003) (69,179) Standardized Measure Net Cash Flows $ 48,255 $ 5,865 $ 6,071 $ 9,089 $ 25,724 $ 884 $ 95,888 $ 21,879 $ 2,173 $ 119,940 At December 31, 2023 Future cash inflows from production $ 181,152 $ 65,265 $ 42,786 $ 62,094 $ 99,003 $ 4,395 $ 454,695 $ 74,758 $ 7,324 $ 536,777 Future production costs (48,784) (22,549) (16,502) (13,000) (11,534) (1,194) (113,563) (21,467) (484) (135,514) Future development costs (16,938) (3,538) (4,474) (2,845) (5,804) (438) (34,037) (3,617) (67) (37,721) Future income taxes (21,089) (10,337) (12,446) (27,415) (24,499) (1,160) (96,946) (14,902) (2,371) (114,219) Undiscounted future net cash flows 94,341 28,841 9,364 18,834 57,166 1,603 210,149 34,772 4,402 249,323 10 percent midyear annual discount for timing of estimated cash flows (39,553) (16,623) (3,262) (9,343) (22,011) (600) (91,392) (11,283) (1,640) (104,315) Standardized Measure Net Cash Flows $ 54,788 $ 12,218 $ 6,102 $ 9,491 $ 35,155 $ 1,003 $ 118,757 $ 23,489 $ 2,762 $ 145,008 At December 31, 2022 Future cash inflows from production $ 257,478 $ 76,940 $ 55,865 $ 67,188 $ 147,839 $ 5,920 $ 611,230 $ 106,114 $ 22,630 $ 739,974 Future production costs (51,022) (22,744) (16,373) (12,261) (13,313) (1,069) (116,782) (28,046) (574) (145,402) Future development costs (20,907) (3,233) (2,657) (2,879) (5,030) (502) (35,208) (4,127) (8) (39,343) Future income taxes (40,096) (13,207) (26,160) (30,674) (38,861) (2,827) (151,825) (22,182) (7,707) (181,714) Undiscounted future net cash flows 145,453 37,756 10,675 21,374 90,635 1,522 307,415 51,759 14,341 373,515 10 percent midyear annual discount for timing of estimated cash flows (62,918) (22,165) (3,001) (10,769) (37,519) (571) (136,943) (18,810) (5,824) (161,577) Standardized Measure Net Cash Flows $ 82,535 $ 15,591 $ 7,674 $ 10,605 $ 53,116 $ 951 $ 170,472 $ 32,949 $ 8,517 $ 211,938 Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 105 Table VII - Changes in the Standardized Measure of Discounted Future Net Cash Flows From Proved Reserves The changes in present values between years, which can be significant, reflect changes in estimated proved reserve quantities and prices and assumptions used in forecasting production volumes and costs. Changes in the timing of production are included with “Revisions of previous quantity estimates.” Total Consolidated and Millions of dollars Consolidated Companies Affiliated Companies Affiliated Companies Present Value at January 1, 2022 $ 103,884 $ 24,991 $ 128,875 Sales and transfers of oil and gas produced net of production costs (53,356) (9,127) (62,483) Development costs incurred 7,962 2,430 10,392 Purchases of reserves 2,248 — 2,248 Sales of reserves (1,807) — (1,807) Extensions, discoveries and improved recovery less related costs 16,054 823 16,877 Revisions of previous quantity estimates 5,281 (1,481) 3,800 Net changes in prices, development and production costs 110,467 28,052 138,519 Accretion of discount 14,075 3,429 17,504 Net change in income tax (34,336) (7,651) (41,987) Net Change for 2022 66,588 16,475 83,063 Present Value at December 31, 2022 $ 170,472 $ 41,466 $ 211,938 Sales and transfers of oil and gas produced net of production costs (38,638) (6,350) (44,988) Development costs incurred 11,381 2,281 13,662 Purchases of reserves 9,628 — 9,628 Sales of reserves (51) — (51) Extensions, discoveries and improved recovery less related costs 7,262 — 7,262 Revisions of previous quantity estimates (14,389) (493) (14,882) Net changes in prices, development and production costs (80,284) (23,517) (103,801) Accretion of discount 23,306 5,722 29,028 Net change in income tax 30,070 7,142 37,212 Net Change for 2023 (51,715) (15,215) (66,930) Present Value at December 31, 2023 $ 118,757 $ 26,251 $ 145,008 Sales and transfers of oil and gas produced net of production costs (38,457) (6,242) (44,699) Development costs incurred 12,809 1,487 14,296 Purchases of reserves 1,607 — 1,607 Sales of reserves (8,904) — (8,904) Extensions, discoveries and improved recovery less related costs 7,328 — 7,328 Revisions of previous quantity estimates 2,897 (154) 2,743 Net changes in prices, development and production costs (17,755) (1,898) (19,653) Accretion of discount 15,867 3,601 19,468 Net change in income tax 1,739 1,007 2,746 Net Change for 2024 (22,869) (2,199) (25,068) Present Value at December 31, 2024 $ 95,888 $ 24,052 $ 119,940 Supplemental Information on Oil and Gas Producing Activities - Unaudited Financial Table of Contents Chevron Corporation 2024 Annual Report 106 chevron history 1879 Incorporated in San Francisco, California, as the Pacific Coast Oil Company. 1900 Acquired by the West Coast operations of John D. Rockefeller’s original Standard Oil Company. 1911 Emerged as an autonomous entity – Standard Oil Company (California) – following U.S. Supreme Court decision to divide the Standard Oil conglomerate into 34 independent companies. 1926 Acquired Pacific Oil Company to become Standard Oil Company of California (Socal). 1936 Formed the Caltex Group of Companies, jointly owned by Socal and The Texas Company (later became Texaco), to combine Socal’s exploration and production interests in the Middle East and Indonesia and provide an outlet for crude oil through The Texas Company’s marketing network in Africa and Asia. 1947 Acquired Signal Oil Company, obtaining the Signal brand name and adding 2,000 retail stations in the western United States. 1961 Acquired Standard Oil Company (Kentucky), a major petroleum products marketer in five southeastern states, to provide outlets for crude oil from southern Louisiana and the Gulf of America, where the company was a major producer. 1984 Acquired Gulf Corporation – nearly doubling the company’s crude oil and natural gas activities – and gained a significant presence in industrial chemicals, natural gas liquids and coal. Changed name to Chevron Corporation to identify with the name under which most products were marketed. 1988 Purchased Tenneco Inc.’s Gulf of America crude oil and natural gas properties, becoming one of the largest U.S. natural gas producers. 1993 Formed Tengizchevroil, a joint venture with the Republic of Kazakhstan, to develop and produce the giant Tengiz Field, becoming the first major western oil company to enter newly independent Kazakhstan. 1999 Acquired Rutherford-Moran Oil Corporation. This acquisition provided inroads to Asian natural gas markets. 2001 Merged with Texaco Inc. and changed name to ChevronTexaco Corporation. Became the second-largest U.S.-based energy company. 2002 Relocated corporate headquarters from San Francisco, California, to San Ramon, California. 2005 Acquired Unocal Corporation, an independent crude oil and natural gas exploration and production company. Unocal’s upstream assets bolstered Chevron’s already strong position in the Asia-Pacific, Gulf of America and Caspian regions. Changed name to Chevron Corporation to convey a clearer, stronger and more unified presence in the global marketplace. 2020 Acquired Noble Energy, Inc., providing Chevron with low-cost proved reserves and attractive undeveloped resources, cash-generating offshore assets in Israel, and acreage in the DJ and Permian basins in the U.S. 2022 Acquired Renewable Energy Group, Inc., becoming the second-largest producer of bio-based diesel in the U.S. 2023 Acquired PDC Energy, Inc., enhancing the company’s presence in the DJ and Permian basins in the U.S. 2025 Relocated corporate headquarters from San Ramon, California, to Houston, Texas. Chevron Corporation 2024 Annual Report 107 Learn more about our history: chevron.co/history glossary of energy and financial terms energy terms Acreage Land leased for oil and gas exploration and production. Additives Specialty chemicals incorporated into fuels and lubricants that enhance the performance of the finished product. Barrels of oil-equivalent (BOE) A unit of measure to quantify crude oil, natural gas liquids and natural gas amounts using the same basis. Natural gas volumes are converted to barrels on the basis of energy content. See oil-equivalent gas and production. Carbon capture, utilization and storage (CCUS) The process of capturing carbon dioxide emissions and either using them as a feedstock (utilization) or permanently storing them in geological formations deep underground (storage). Carbon efficiency The extent to which a given level of output is produced with fewer carbon emissions relative to average output. Carbon intensity The amount of carbon dioxide or carbon dioxide equivalent (CO2e) per unit of measure. Condensate Hydrocarbons that are in a gaseous state at reservoir conditions, but when produced are in liquid state at surface conditions. Development Drilling, construction and related activities following discovery that are necessary to begin production and transportation of crude oil and/or natural gas. Exploration Searching for crude oil and/or natural gas by utilizing geological and topographical studies, geophysical and seismic surveys, and drilling of wells. Gas-to-liquids (GTL) A process that converts natural gas into high‑quality liquid transportation fuels and other products. Liquefied natural gas (LNG) Natural gas that is liquefied under extremely cold temperatures to facilitate storage or transportation in specially designed vessels. Liquefied petroleum gas (LPG) Light gases, such as butane and propane, that can be maintained as liquids while under pressure. Lower carbon A term describing environments, technologies, business sectors, markets, energy sources and mixes of energy sources, including oil and natural gas, among other things, characterized by or enabling the reduction of carbon emissions or carbon intensities. Lower carbon energy Energy sources and mixes of energy sources, including oil and natural gas, that, in their production and use, emit less carbon emissions or have lower carbon intensity than other forms. Lower carbon intensity hydrogen Includes specified hydrogen production pathways like steam methane reforming with carbon capture and storage and electrolysis with lower carbon power. Lower carbon intensity oil, products and natural gas Oil, natural gas and hydrocarbon-based products that are produced and sold to customers with a carbon intensity below that of traditional oil, natural gas and hydrocarbon-based products. Natural gas liquids (NGLs) Separated from natural gas, these include ethane, propane, butane and natural gasoline. Net reserves and resources Chevron’s interest share of oil and gas after removing royalty share and overriding royalties paid to others. Net includes any applicable Chevron-owned overriding royalties. Net zero upstream aspiration (Scope 1 and 2) Chevron aspires to achieve net zero for upstream production Scope 1 and 2 GHG emissions on an equity basis by 2050. Chevron’s ability to achieve any aspiration, target or goal depends on, among other things: (1) sufficient and substantial advances in technology, including the continuing progress of commercially viable technologies and low- or non-carbon-based energy sources; (2) laws, governmental regulation, policies and other enabling actions, including those regarding subsidies, tax and other incentives as well as the granting of necessary permits by governing authorities; (3) the availability and acceptability of cost-effective, verifiable carbon credits; (4) the availability of suppliers that can meet our sustainability-related standards; (5) evolving regulatory requirements, including changes to IPCC’s Global Warming Potentials and the U.S. EPA Greenhouse Gas Reporting Program, affecting ESG standards or disclosures; (6) evolving standards for tracking and reporting on emissions and emission reductions and removals; (7) customers’ and consumers’ preferences and use of the company’s products or substitute products; (8) actions taken by the company’s competitors in response to legislation and regulations; and (9) successful negotiations for carbon capture and storage and nature-based solutions with customers, suppliers, partners and governments. Oil-equivalent gas (OEG) The volume of natural gas needed to generate the equivalent amount of heat as a barrel of crude oil. Approximately 6,000 cubic feet of natural gas is equivalent to one barrel of crude oil. Oil sands Naturally occurring mixture of bitumen (a heavy, viscous form of crude oil), water, sand and clay. Using hydroprocessing technology, bitumen can be refined to yield synthetic oil. Petrochemicals Compounds derived from petroleum. These include: aromatics, which are used to make plastics, adhesives, synthetic fibers and household detergents; and olefins, which are used to make packaging, plastic pipes, tires, batteries, household detergents and synthetic motor oils. Portfolio carbon intensity (PCI) Representation of the estimated energy-weighted average greenhouse gas emissions intensity from a simplified value chain from the production, refinement, distribution and end use of marketed energy products per unit of energy delivered. Production Total production refers to all the crude oil (including synthetic oil), NGLs and natural gas produced from a property. Net production is the company’s share of total production after deducting both royalties paid to landowners and a government’s agreed-upon share of production under a production-sharing contract. Liquids production refers to crude oil, condensate, NGLs and synthetic oil volumes. Oil-equivalent production is the sum of the barrels of liquids and the oil-equivalent barrels of natural gas produced. See barrels of oil equivalent, oil-equivalent gas and production-sharing contract. Chevron Corporation 2024 Annual Report 108 Production-sharing contract (PSC) An agreement between a government and a contractor (generally an oil and gas company) whereby production is shared between the parties in a prearranged manner. The contractor typically incurs all exploration, development and production costs, which are subsequently recoverable out of an agreed-upon share of any future PSC production, referred to as cost recovery oil and/or gas. Any remaining production, referred to as profit oil and/or gas, is shared between the parties on an agreed- upon basis as stipulated in the PSC. The government may also retain a share of PSC production as a royalty payment, and the contractor typically owes income tax on its portion of the profit oil and/or gas. The contractor’s share of PSC oil and/or gas production and reserves varies over time, as it is dependent on prices, costs and specific PSC terms. Refinery crude unit distillation utilization Average feedstocks consumed in the crude unit in refineries for the year, expressed as a percentage of the refineries average annual crude unit capacity. Reserves Crude oil, NGLs and natural gas contained in underground rock formations called reservoirs and saleable hydrocarbons extracted from oil sands, shale, coalbeds and other nonrenewable natural resources that are intended to be upgraded into synthetic oil or gas. Net proved reserves are the estimated quantities that geoscience and engineering data demonstrate with reasonable certainty to be economically producible in the future from known reservoirs under existing economic conditions, operating methods and government regulations and exclude royalties and interests owned by others. Estimates change as additional information becomes available. Oil-equivalent reserves are the sum of the liquids reserves and the oil-equivalent gas reserves. See barrels of oil-equivalent and oil-equivalent gas. The company discloses only net proved reserves in its filings with the U.S. Securities and Exchange Commission. Investors should refer to proved reserves disclosures in Chevron’s Annual Report on Form 10-K for the year ended December 31, 2024. Resources Estimated quantities of oil and gas resources are recorded under Chevron’s 6P system, which is modeled after the Society of Petroleum Engineers’ Petroleum Resources Management System, and include quantities classified as proved, probable and possible reserves, plus those that remain contingent on commerciality. Unrisked resources, unrisked resource base and similar terms represent the arithmetic sum of the amounts recorded under each of these classifications. Recoverable resources, potentially recoverable volumes and other similar terms represent estimated remaining quantities that are forecast to be ultimately recoverable and produced in the future, adjusted to reflect the relative uncertainty represented by the various classifications. These estimates may change significantly as development work provides additional information. All of these measures are considered by management in making capital investment and operating decisions and may provide some indication to stockholders of the resource potential of oil and gas properties in which the company has an interest. Shale gas Natural gas produced from shale rock formations where the gas was sourced from within the shale itself. Shale is very fine-grained rock, characterized by low porosity and extremely low permeability. Production of shale gas normally requires formation stimulation such as the use of hydraulic fracturing (pumping a fluid-sand mixture into the formation under high pressure) to help produce the gas. Synthetic oil A marketable and transportable hydrocarbon liquid, resembling crude oil, that is produced by upgrading highly viscous or solid hydrocarbons, such as extra-heavy crude oil or oil sands. Tight oil Liquid hydrocarbons produced from shale (also referred to as shale oil) and other rock formations with extremely low permeability. As with shale gas, production from tight oil reservoirs normally requires formation stimulation such as hydraulic fracturing. Unconventional oil and gas resources Hydrocarbons contained in formations over very large areas with extremely low permeability that are not influenced by buoyancy. In contrast, conventional resources are contained within geologic structures/stratigraphy and float buoyantly over water. Unconventional resources include shale gas, coalbed methane, crude oil and natural gas from tight rock formations, tar sands, kerogen from oil shale, and gas hydrates that cannot commercially flow without well stimulation. Wells Oil and gas wells are classified as either exploration or development wells. Exploration wells are wells drilled to find a new field or to find a new reservoir in a field previously found to be productive of oil and gas in another reservoir. Appraisal wells are exploration wells drilled to confirm the results of a discovery well. Delineation wells are exploration wells drilled to determine the boundaries of a productive formation or to delineate the extent of a find. Development wells are wells drilled in an existing reservoir in a proved oil- or gas-producing area. Completed wells are wells for which drilling work has been completed and that are capable of producing. Dry wells are wells completed as dry holes, that is, wells not capable of producing in commercial quantities. financial terms Capital employed The sum of Chevron Corporation stockholders’ equity, total debt and noncontrolling interests. Average capital employed is computed by averaging the sum of capital employed at the beginning and end of the year. Cash flow from operating activities Cash generated from the company’s businesses; an indicator of a company’s ability to fund capital programs and stockholder distributions. Excludes cash flows related to the company’s financing and investing activities. Current ratio Current assets divided by current liabilities. Debt ratio Total debt, including finance lease liabilities, divided by total debt plus Chevron Corporation stockholders’ equity. Earnings Net income attributable to Chevron Corporation as presented on the Consolidated Statement of Income. Free cash flow The cash provided by operating activities less capital expenditures. Goodwill An asset representing the future economic benefits arising from the other assets acquired in a business combination that are not individually identified and separately recognized. Interest coverage ratio Income before income tax expense, plus interest and debt expense and amortization of capitalized interest, less net income attributable to noncontrolling interests, divided by before-tax interest costs. Margin The difference between the cost of purchasing, producing and/or marketing a product and its sales price. Net debt ratio Total debt less the sum of cash and cash equivalents, time deposits and marketable securities, as a percentage of total debt less the sum of cash and cash equivalents, time deposits and marketable securities plus Chevron Corporation’s Stockholders’ Equity. Return on capital employed (ROCE) This is calculated by dividing earnings (adjusted for after-tax interest expense and noncontrolling interests) by average capital employed. Return on stockholders’ equity (ROSE) This is calculated by dividing earnings by average Chevron Corporation Stockholders’ Equity. Average Chevron Corporation Stockholders’ Equity is computed by averaging the sum of the beginning-of-year and end-of-year balances. Return on total assets This is calculated by dividing earnings by average total assets. Average total assets is computed by averaging the sum of the beginning-of-year and end-of- year balances. Total stockholder return The return to stockholders as measured by stock price appreciation and reinvested dividends for a period of time. Chevron Corporation 2024 Annual Report 109 stockholder and investor information stock exchange listing Chevron common stock is listed on the New York Stock Exchange. The symbol is “CVX.” stockholder information As of February 7, 2025, stockholders of record numbered approximately 95,000. For questions about stock ownership, changes of address and dividend reinvestment programs, please contact Chevron’s stock transfer agent: Computershare P.O. Box 505000 Louisville, KY 40233-5000 800 368 8357 (U.S. and Canada) 201 680 6578 (outside the U.S. and Canada) www.computershare.com/investor Overnight correspondence should be sent to: Computershare 462 South 4th Street Suite 1600 Louisville, KY 40202 The Computershare Investment Plan is a direct stock purchase and dividend reinvestment plan. dividend payment dates Quarterly dividends on common stock are paid, generally, following declaration by the Board of Directors, on or about the 10th day of March, June, September and December. Direct deposit of dividends is available to stockholders. For information, contact Computershare. (See “stockholder information” section.) annual meeting The Annual Meeting of Stockholders will be held online via live audio webcast at 10 a.m. CDT, Wednesday, May 28, 2025. www.virtualshareholdermeeting.com/CVX2025 electronic access In an effort to conserve natural resources and reduce the cost of printing and mailing proxy materials, we encourage stockholders to register to receive these documents by email and vote their shares on the internet. Stockholders of record may sign up for electronic access (and beneficial stockholders may be able to request electronic access by contacting their broker or bank or Broadridge Financial Solutions) on this website: www.icsdelivery.com/cvx. Enrollment is revocable until each year’s Annual Meeting record date. Chevron Corporation 2024 Annual Report 110 investor information Securities analysts, portfolio managers and representatives of financial institutions may contact: Investor Relations Chevron Corporation 1400 Smith Street Houston, TX 77002-7327 713 372 5000 Email: invest@chevron.com notice As used in this report, the term “Chevron” and such terms as “the company,” “the corporation,” “our,” “we,” “us” and “its” may refer to one or more of Chevron’s consolidated subsidiaries or to all of them taken as a whole. All of these terms are used for convenience only and are not intended as a precise description of any of the separate companies, each of which manages its own affairs. corporate headquarters 1400 Smith Street Houston, TX 77002-7327 832 854 1000Photo of young employees in the Houston office a legacy of hispanic STEM empowerment The Society of Hispanic Professional Engineers (SHPE) celebrated its 50th Anniversary in 2024. It’s the largest organization in the United States dedicated to empowering the Hispanic community to succeed in STEM education, careers and leadership. And it’s helped aspiring engineers like Paula Diaz Luengo, pictured above, bridge the gap between education and employment. Now she is a data analyst at Chevron – and serves as the director of the Chevron Hispanic Recruitment Team. Chevron’s work with SHPE began in 1990. In recent years, this collaboration has been powered by Somos, Chevron’s internal network for Hispanic and Latino employees. The 35-year partnership has included Chevron’s sponsorship of SHPE’s national and regional conferences, mentorship programs and scholarships. It has also included outreach initiatives that empower Hispanic students and professionals to achieve academic and career success. Learn more about our approach at chevron.co/talent publications and other news sources The Annual Report, distributed in April, summarizes the company’s financial performance in the preceding year and provides an overview of the company’s major activities. Chevron’s Annual Report on Form 10-K, filed with the U.S. Securities and Exchange Commission, and the Supplement to the Annual Report, containing additional financial and operating data, are available on the company’s website, www.chevron.com, or copies may be requested by contacting: Investor Relations Chevron Corporation 1400 Smith Street Houston, TX 77002-7327 713 372 5000 Email: invest@chevron.com We strive to protect the environment, empower people and get results the right way. Our approach to sustainability is integrated throughout our business. To learn more, visit chevron.com/sustainability. Details of the company’s political contributions for 2024 are available on the company’s website, www.chevron.com, or by writing to: Corporate Affairs Chevron Corporation 1400 Smith Street Houston, TX 77002-7327 832 854 1000 For additional information about the company and the energy industry, visit Chevron’s website, www.chevron.com. It includes articles, news releases, event transcripts and presentations, quarterly earnings information, the Proxy Statement, and the complete text of this Annual Report. Chevron also publishes a “Sensitivities and Forward Guidance” document with consolidated guidance and sensitivities that is updated quarterly and posted to the Chevron website the month prior to earnings calls. connect with us @chevron Chevron Corporation 2024 Annual Report 112 partners in innovation: chevron, microsoft and SLB 2024 marked the fifth anniversary of Chevron’s partnership with Microsoft and SLB to leverage AI and cloud‑based platforms to transform enterprise strategic planning, petrotechnical workflows and operational efficiency. We have established a robust global digital foundation that enhances innovation, reduces costs and accelerates workflows with over 1,200 users across multiple business units. This three-way partnership is poised to deliver transformational value through scalable and rapidly deployable innovations. Learn more at: chevron.co/digitalfoundation driller well planner geologist The statements and images in this Annual Report, including without limitation those relating to the action areas of Chevron’s strategy, are forward-looking based on management’s current expectations, estimates and projections and, accordingly, involve risks and uncertainties that could cause actual outcomes and results to differ materially from those expressed or forecasted herein. Words or phrases such as “anticipates,” “expects,” “intends,” “plans,” “targets,” “advances,” “commits,” “drives,” “aims,” “forecasts,” “projects,” “believes,” “approaches,” “seeks,” “schedules,” “estimates,” “positions,” “pursues,” “progress,” “design,” “enable,” “may,” “can,” “could,” “should,” “will,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on track,” “trajectory,” “goals,” “objectives,” “strategies,” “opportunities,” “poised,” “potential,” “ambitions,” “future,” “aspires” and similar expressions, and variations or negatives of these words, are intended to identify such forward-looking statements, but not all forward-looking statements include such words. These statements are not guarantees of future performance and are subject to numerous risks, uncertainties and other factors, many of which are beyond the company’s control and are difficult to predict. Please see “Cautionary Statements Relevant to Forward-Looking Information for the Purpose of ‘Safe Harbor’ Provisions of the Private Securities Litigation Reform Act of 1995” on page 24 for a discussion of some of the factors that could cause actual results to differ materially. We believe in the power of human ingenuity to produce and deliver energy more efficiently, and to help build a resilient, lower carbon energy system that can continue to meet growing energy demand and advance human progress. Permian Basin United States Shale and tight Production averaged 921,000 net boepd in 2024, an increase of nearly 18% from 2023 Chevron Corporation 1400 Smith Street Houston, TX 77002-7327 www.chevron.com © 2025 Chevron Corporation. All Rights Reserved. 912-0993 Printed on Rolland Enviro® Print 80lb. cover and Rolland Enviro® Satin 80lb. and 50lb. text. This paper contains 100% sustainable recycled fiber and is processed chlorine free. It is FSC® certified and designated Ancient Forest Friendly™.