• Reported earnings of $3.2 billion; adjusted earnings of $3.6 billion
• Returned record $27 billion cash to shareholders in 2024
• Increased 2024 worldwide and U.S. production by 7 and 19 percent to record levels
• Delivered key project start-ups and milestones in the U.S. and Kazakhstan
• Announced a 5 percent increase in quarterly dividend to $1.71 per share

Chevron Corporation reported earnings of $3.2 billion ($1.84 per share - diluted) for fourth quarter 2024, compared with $2.3 billion ($1.22 per share - diluted) in fourth quarter 2023. Included in the quarter were severance charges of $715 million and impairment charges of $400 million. Foreign currency effects increased earnings by $722 million. Adjusted earnings of $3.6 billion ($2.06 per share - diluted) in fourth quarter 2024 compared to adjusted earnings of $6.5 billion ($3.45 per share - diluted) in fourth quarter 2023. 

“In 2024, we delivered record production, returned record cash to shareholders and started up key growth projects,” said Mike Wirth, Chevron’s chairman and chief executive officer.

Worldwide and U.S. net oil-equivalent production increased 7 and 19 percent, respectively, from last year.

The company started up several key projects in the Gulf of America, including the industry-first, high-pressure Anchor project. In Kazakhstan, Tengizchevroil completed the Wellhead Pressure Management Project and recently started up the Future Growth Project. Chevron also repurchased over $15 billion of its shares in 2024, extending its track record of repurchasing shares in 17 out of the last 21 years.

“We strengthened our portfolio and committed to reduce costs and maintain capital discipline, positioning us for significant free cash flow growth,” Wirth concluded.

The company recently closed asset sales in Canada, the Republic of Congo and Alaska, progressed the acquisition of Hess Corporation, and announced a target of $2-3 billion of structural cost reductions by the end of 2026.

2024 Financial Highlights

• Reported earnings decreased compared to last year primarily due to lower margins on refined product sales, lower realizations, and severance charges, partially offset by the absence of charges for decommissioning obligations for previously sold assets, higher sales volumes and lower impairment charges.
• Worldwide and U.S. net oil-equivalent production set annual records. Worldwide production increased 7 percent from a year ago primarily due to nearly 18 percent growth in the Permian Basin and a full year of legacy PDC Energy, Inc. (PDC) production.
• Year-end 2024 proved reserves were approximately 9.8 billion barrels of net oil-equivalent, subject to final reviews. The largest reductions were from production and the sale of oil sands and shale and tight assets in Canada, and the largest additions were from extensions and discoveries in the Permian and Denver-Julesburg (DJ) Basins.
• Capex was slightly higher than 2023, primarily due to higher upstream investments. Affiliate capex was down $1.1 billion, primarily due to lower spend at the company’s Tengizchevroil (TCO) affiliate in Kazakhstan.
• Cash flow from operations was lower than a year ago mainly due to lower earnings and higher payments related to asset retirement obligations, partially offset by favorable working capital effects.
• Cash flow from investing improved from last year driven by $7.7 billion of proceeds from asset sales in Canada and the U.S.
• The company returned a record $27.0 billion of cash to shareholders during the year, including share repurchases of $15.2 billion and dividends of $11.8 billion. Over the past three years, the company has returned over $75 billion to shareholders.
• The company’s Board of Directors declared a 5 percent increase in the quarterly dividend to one dollar and seventy-one cents ($1.71) per share, payable March 10, 2025, to all holders of common stock as shown on the transfer records of the corporation at the close of business on February 14, 2025.

Business Highlights and Milestones

• Started production at the industry-first 20,000 psi deepwater Anchor project, began water injection to boost production from the Jack/St. Malo and Tahiti fields, and started production from the Whale semi-submersible platform in the Gulf of America.
• Started production at the Future Growth Project in January 2025, which is expected to ramp up total output to around one million barrels of oil-equivalent per day, and completed the Wellhead Pressure Management Project at TCO.
• Recently 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.
• Achieved first gas on the Sanha Lean Gas Connection project, securing incremental natural gas supply to the Angola Liquefied Natural Gas facility.
• Extended the Meji field offshore Nigeria with a near-field discovery and added 20 years to the deepwater Agbami concession through 2044.
• Upgraded the Pasadena Refinery to increase product flexibility and expand the processing capacity of lighter crude oil by nearly 15 percent to 125,000 barrels per day.
• Increased the company’s exploration acreage position in the Gulf of America, Angola, Brazil, Equatorial Guinea, Uruguay and Namibia (subject to government approval).
• Completed the sale of the company’s interest in the Athabasca Oil Sands Project and Duvernay shale assets in Canada, certain assets in Alaska, and in 2025, the Republic of Congo.
• Progressed the company’s pending merger with Hess Corporation by securing Hess stockholder approval and clearing Federal Trade Commission antitrust review.
• Completed projects and operational changes designed to abate 700,000 tonnes of carbon dioxide-equivalent from the company’s operations.
• Drilled onshore and offshore stratigraphic wells to delineate carbon dioxide storage potential through the company’s joint venture, Bayou Bend CCS LLC.
• 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.

2025 CapEx

Upstream spending is expected to be about $13 billion, of which roughly two-thirds is allocated to develop Chevron’s U.S. portfolio. Permian Basin spend is lower than the 2024 budget and anticipated to be between $4.5 and $5.0 billion as production growth is reduced in favor of free cash flow. The remaining U.S. investment is split between the DJ Basin and the Gulf of Mexico, where deepwater growth projects continue to ramp and are expected to deliver offshore production of 300 mboed in 2026. In International, about $1.0 billion is allocated to Australia, which include Gorgon backfill investments.

Downstream capex is expected to be approximately $1.2 billion, with two-thirds allocated to the U.S. Within total upstream and downstream budgets, about $1.5 billion of capex is dedicated to lowering the carbon intensity of our operations and growing New Energies businesses. Corporate and other capex is expected to be around $0.7 billion.

Tengizchevroil LLP’s budget is less than half of the affiliate capex as the Future Growth Project is projected to achieve first oil in the first half of 2025. The remaining affiliate spend primarily supports Chevron Phillips Chemical Company LLC, which includes the Golden Triangle Polymers and Ras Laffan Petrochemical Projects.

 KeyFacts Energy: Chevron US country profile