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UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2025
or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
Commission file number 001-00368
Chevron Corporation
(Exact name of registrant as specified in its charter)

|  |  |  | 1400 Smith Street
Delaware |  | 94-0890210 |  | Houston, | TX | 77002-7327 |
(State or other jurisdiction of incorporation or organization) |  | (I.R.S. Employer Identification No.) |  | (Address of principal executive offices) (Zip Code) |

Registrant’s telephone number, including area code: (832) 854-1000

|  | NONE |  |
| (Former name, former address and former fiscal year, if changed since last report.) |

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

Title of each class |  | Trading Symbol |  | Name of each exchange on which registered
Common stock, par value $.75 per share |  | CVX |  | New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☑ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☑ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer | ☑ |  | Accelerated filer | ☐
Non-accelerated filer | ☐ |  | Smaller reporting company | ☐
|  |  | Emerging growth company | ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑
There were 2,013,521,597 shares of the company’s common stock outstanding on September 30, 2025.

Table of Contents
TABLE OF CONTENTS

|  | Page No.
| Cautionary Statements Relevant to Forward-Looking Information for the Purpose of “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995 | 2
PART I FINANCIAL INFORMATION
Item 1. | Consolidated Financial Statements — |
| Consolidated Statement of Income for the Three and Nine Months Ended September 30, 2025 and 2024 | 3
| Consolidated Statement of Comprehensive Income for the Three and Nine Months Ended September 30, 2025 and 2024 | 4
| Consolidated Balance Sheet at September 30, 2025 and December 31, 2024 | 5
| Consolidated Statement of Cash Flows for the Nine Months Ended September 30, 2025 and 2024 | 6
| Consolidated Statement of Equity for the Three and Nine Months Ended September 30, 2025 and 2024 | 7
| Notes to Consolidated Financial Statements | 8
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 28
Item 3. | Quantitative and Qualitative Disclosures About Market Risk | 45
Item 4. | Controls and Procedures | 46
PART II OTHER INFORMATION
Item 1. | Legal Proceedings | 46
Item 1A. | Risk Factors | 46
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 47
Item 5. | Other Information | 47
Item 6. | Exhibits | 48
Signature | 49

1

Table of Contents
CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION
FOR THE PURPOSE OF “SAFE HARBOR” PROVISIONS OF THE
PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995
This quarterly report on Form 10-Q 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 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 company’s ability to successfully integrate the operations of the company and Hess Corporation and achieve the anticipated benefits and projected synergies from the transaction; 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 of the company’s 2024 Annual Report on Form 10-K and in subsequent filings with the U.S. Securities and Exchange Commission. Other unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.
2

Table of Contents
PART I.
FINANCIAL INFORMATION
Item 1.Consolidated Financial Statements
CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF INCOME
(Unaudited)

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars, except per-share amounts)
Revenues and Other Income |  |  |  |  |  |  |
Sales and other operating revenues | $ | 48,169 |  |  | $ | 48,926 |  |  | $ | 138,645 |  |  | $ | 145,080 |
Income (loss) from equity affiliates | 981 |  |  | 1,261 |  |  | 2,337 |  |  | 3,908 |
Other income (loss) | 576 |  |  | 482 |  |  | 1,176 |  |  | 1,578 |
Total Revenues and Other Income | 49,726 |  |  | 50,669 |  |  | 142,158 |  |  | 150,566 |
Costs and Other Deductions |  |  |  |  |  |  |
Purchased crude oil and products | 27,398 |  |  | 30,450 |  |  | 82,866 |  |  | 89,058 |
Operating expenses | 7,534 |  |  | 6,695 |  |  | 20,616 |  |  | 19,842 |
Selling, general and administrative expenses | 1,524 |  |  | 1,191 |  |  | 3,634 |  |  | 3,249 |
Exploration expenses | 288 |  |  | 154 |  |  | 727 |  |  | 546 |
Depreciation, depletion and amortization | 5,781 |  |  | 4,214 |  |  | 14,248 |  |  | 12,309 |
Taxes other than on income | 1,347 |  |  | 1,263 |  |  | 3,903 |  |  | 3,575 |
Interest and debt expense | 370 |  |  | 164 |  |  | 856 |  |  | 395 |
Other components of net periodic benefit costs | 70 |  |  | 49 |  |  | 164 |  |  | 145 |
Total Costs and Other Deductions | 44,312 |  |  | 44,180 |  |  | 127,014 |  |  | 129,119 |
Income (Loss) Before Income Tax Expense | 5,414 |  |  | 6,489 |  |  | 15,144 |  |  | 21,447 |
Income Tax Expense (Benefit) | 1,801 |  |  | 1,993 |  |  | 5,504 |  |  | 6,957 |
Net Income (Loss) | 3,613 |  |  | 4,496 |  |  | 9,640 |  |  | 14,490 |
Less: Net income (loss) attributable to noncontrolling interests | 74 |  |  | 9 |  |  | 111 |  |  | 68 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 3,539 |  |  | $ | 4,487 |  |  | $ | 9,529 |  |  | $ | 14,422 |
Per Share of Common Stock |  |  |  |  |  |  |
Net Income (Loss) Attributable to Chevron Corporation |  |  |  |  |  |  |
- Basic | $ | 1.83 |  |  | $ | 2.49 |  |  | $ | 5.29 |  |  | $ | 7.91 |
- Diluted | $ | 1.82 |  |  | $ | 2.48 |  |  | $ | 5.27 |  |  | $ | 7.88 |
Weighted Average Number of Shares Outstanding (000s) |  |  |  |  |  |  |
- Basic | 1,938,922 |  |  | 1,800,336 |  |  | 1,801,623 |  |  | 1,822,770 |
- Diluted | 1,946,035 |  |  | 1,807,030 |  |  | 1,808,004 |  |  | 1,829,776 |

See accompanying notes to consolidated financial statements.
3

Table of Contents
CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(Unaudited)

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Net Income (Loss) | $ | 3,613 |  |  | $ | 4,496 |  |  | $ | 9,640 |  |  | $ | 14,490 |
Currency translation adjustment | (9) |  |  | 23 |  |  | 61 |  |  | (9) |
Unrealized holding gain (loss) on securities |  |  |  |  |  |  |
Net gain (loss) arising during period | (2) |  |  | 4 |  |  | 16 |  |  | (5) |
Derivatives |  |  |  |  |  |  |
Net derivatives gain (loss) on hedge transactions | 7 |  |  | 18 |  |  | (10) |  |  | (33) |
Reclassification to net income | (6) |  |  | 16 |  |  | 34 |  |  | 43 |
Income taxes on derivatives transactions | (1) |  |  | (8) |  |  | (5) |  |  | (3) |
Total | — |  |  | 26 |  |  | 19 |  |  | 7 |
Defined benefit plans |  |  |  |  |  |  |
Actuarial gain (loss) |  |  |  |  |  |  |
Amortization to net income of net actuarial loss and settlements | 43 |  |  | 61 |  |  | 118 |  |  | 185 |
Actuarial gain (loss) arising during period | (80) |  |  | 1 |  |  | (46) |  |  | 1 |
Prior service credits (cost) |  |  |  |  |  |  |
Amortization to net income of net prior service costs and curtailments | (4) |  |  | (3) |  |  | (7) |  |  | (8) |
Prior service (costs) credits arising during period | 24 |  |  | — |  |  | 24 |  |  | — |
Defined benefit plans sponsored by equity affiliates - benefit (cost) | 3 |  |  | 1 |  |  | 12 |  |  | 3 |
Income (taxes) benefit on defined benefit plans | 1 |  |  | (14) |  |  | (28) |  |  | (39) |
Total | (13) |  |  | 46 |  |  | 73 |  |  | 142 |
Other Comprehensive Gain (Loss), Net of Tax | (24) |  |  | 99 |  |  | 169 |  |  | 135 |
Comprehensive Income (Loss) | 3,589 |  |  | 4,595 |  |  | 9,809 |  |  | 14,625 |
Comprehensive loss (income) attributable to noncontrolling interests | (74) |  |  | (9) |  |  | (111) |  |  | (68) |
Comprehensive Income (Loss) Attributable to Chevron Corporation | $ | 3,515 |  |  | $ | 4,586 |  |  | $ | 9,698 |  |  | $ | 14,557 |

See accompanying notes to consolidated financial statements.
4

Table of Contents
CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)

|  | At September 30, 2025 |  | At December 31, 2024
|  | (Millions of dollars)
Assets |  |  |  |
Cash and cash equivalents |  | $ | 7,725 |  |  | $ | 6,781 |
Time deposits |  | 2 |  |  | 4 |
Accounts and notes receivable (less allowance: 2025 - $191; 2024 - $259) |  | 17,887 |  |  | 20,684 |
Inventories: |  |  |  |
Crude oil and products |  | 7,416 |  |  | 6,490 |
Chemicals |  | 509 |  |  | 502 |
Materials, supplies and other |  | 2,511 |  |  | 2,082 |
Total inventories |  | 10,436 |  |  | 9,074 |
Prepaid expenses and other current assets |  | 4,816 |  |  | 4,368 |
Total Current Assets |  | 40,866 |  |  | 40,911 |
Long-term receivables (less allowance: 2025 - $216; 2024 - $352) |  | 987 |  |  | 877 |
Investments and advances |  | 44,398 |  |  | 47,438 |
Properties, plant and equipment, at cost |  | 429,269 |  |  | 345,933 |
Less: Accumulated depreciation, depletion and amortization |  | 209,775 |  |  | 198,134 |
Properties, plant and equipment, net |  | 219,494 |  |  | 147,799 |
Deferred charges and other assets |  | 16,162 |  |  | 14,854 |
Goodwill |  | 4,568 |  |  | 4,578 |
Assets held for sale |  | 26 |  |  | 481 |
Total Assets |  | $ | 326,501 |  |  | $ | 256,938 |
Liabilities and Equity |  |  |  |
Short-term debt |  | $ | 3,591 |  |  | $ | 4,406 |
Accounts payable |  | 19,073 |  |  | 22,079 |
Accrued liabilities |  | 10,541 |  |  | 8,486 |
Federal and other taxes on income |  | 914 |  |  | 1,872 |
Other taxes payable |  | 1,353 |  |  | 1,715 |
Total Current Liabilities |  | 35,472 |  |  | 38,558 |
Long-term debt |  | 37,953 |  |  | 20,135 |
Deferred credits and other noncurrent obligations |  | 23,592 |  |  | 22,094 |
Noncurrent deferred income taxes |  | 29,796 |  |  | 19,137 |
Noncurrent employee benefit plans |  | 4,088 |  |  | 3,857 |
Total Liabilities* |  | $ | 130,901 |  |  | $ | 103,781 |
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 September 30, 2025 and December 31, 2024) |  | 1,832 |  |  | 1,832 |
Capital in excess of par value |  | 33,812 |  |  | 21,671 |
Retained earnings |  | 206,006 |  |  | 205,852 |
Accumulated other comprehensive losses |  | (2,591) |  |  | (2,760) |
Deferred compensation and benefit plan trust |  | (240) |  |  | (240) |
Treasury stock, at cost (429,154,983 and 673,664,306 shares at September 30, 2025 and December 31, 2024, respectively) |  | (48,976) |  |  | (74,037) |
Total Chevron Corporation Stockholders’ Equity |  | 189,843 |  |  | 152,318 |
Noncontrolling interests |  | 5,757 |  |  | 839 |
Total Equity |  | 195,600 |  |  | 153,157 |
Total Liabilities and Equity |  | $ | 326,501 |  |  | $ | 256,938 |
* Refer to Note 12 Other Contingencies and Commitments.

See accompanying notes to consolidated financial statements.
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CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited)

| Nine Months Ended September 30
| 2025 |  | 2024
| (Millions of dollars)
Operating Activities |  |  |
Net Income (Loss) | $ | 9,640 |  |  | $ | 14,490 |
Adjustments |  |  |
Depreciation, depletion and amortization | 14,248 |  |  | 12,309 |
Dry hole expense | 245 |  |  | 225 |
Distributions more (less) than income from equity affiliates | 1,802 |  |  | (485) |
Net before-tax losses (gains) on asset retirements and sales | (302) |  |  | (236) |
Net foreign currency effects | 444 |  |  | 104 |
Deferred income tax provision | 709 |  |  | 1,545 |
Net decrease (increase) in operating working capital | (2,685) |  |  | (2,172) |
Decrease (increase) in long-term receivables | (85) |  |  | 54 |
Net decrease (increase) in other deferred charges | (380) |  |  | (765) |
Cash contributions to employee pension plans | (538) |  |  | (658) |
Other | 52 |  |  | (1,614) |
Net Cash Provided by Operating Activities | 23,150 |  |  | 22,797 |
Investing Activities |  |  |
Acquisition of businesses, net of cash received | 1,056 |  |  | — |
Acquisition of Hess Corporation common stock | (2,225) |  |  | — |
Capital expenditures | (12,083) |  |  | (12,110) |
Proceeds and deposits related to asset sales and returns of investment | 1,473 |  |  | 620 |
Net maturities of (investments in) time deposits | 2 |  |  | (4) |
Net sales (purchases) of marketable securities | — |  |  | 45 |
Net repayment (borrowing) of loans by equity affiliates | 798 |  |  | (157) |
Net Cash Used for Investing Activities | (10,979) |  |  | (11,606) |
Financing Activities |  |  |
Net borrowings (repayments) of short-term obligations | (819) |  |  | 5,615 |
Proceeds from issuances of long-term debt | 11,166 |  |  | 403 |
Repayments of long-term debt and other financing obligations | (3,557) |  |  | (1,062) |
Cash dividends - common stock | (9,347) |  |  | (8,914) |
Net contributions from (distributions to) noncontrolling interests | (220) |  |  | (197) |
Net sales (purchases) of treasury shares | (8,914) |  |  | (10,535) |
Net Cash Provided by (Used for) Financing Activities | (11,691) |  |  | (14,690) |
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash | 41 |  |  | (12) |
Net Change in Cash, Cash Equivalents and Restricted Cash | 521 |  |  | (3,511) |
Cash, Cash Equivalents and Restricted Cash at January 1 | 8,262 |  |  | 9,275 |
Cash, Cash Equivalents and Restricted Cash at September 30 | $ | 8,783 |  |  | $ | 5,764 |

See accompanying notes to consolidated financial statements.
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CHEVRON CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF EQUITY
(Unaudited)

(Millions of dollars) |  |  | Accumulated | Treasury | Chevron Corp. | Non- |
| Common | Retained | Other Comp. | Stock | Stockholders’ | Controlling | Total
Three Months Ended September 30 | Stock(1) | Earnings | Income (Loss) | (at cost) | Equity | Interests | Equity
Balance at June 30, 2024 | $ | 23,087 |  | $ | 203,960 |  | $ | (2,924) |  | $ | (64,890) |  | $ | 159,233 |  | $ | 1,030 |  | $ | 160,263 |
Treasury stock transactions | 86 |  | — |  | — |  | — |  | 86 |  | — |  | 86 |
Net income (loss) | — |  | 4,487 |  | — |  | — |  | 4,487 |  | 9 |  | 4,496 |
Cash dividends ($1.63 per share) | — |  | (2,933) |  | — |  | — |  | (2,933) |  | (203) |  | (3,136) |
Stock dividends | — |  | (6) |  | — |  | — |  | (6) |  | — |  | (6) |
Other comprehensive income | — |  | — |  | 99 |  | — |  | 99 |  | — |  | 99 |
Purchases of treasury shares(2) | — |  | — |  | — |  | (4,797) |  | (4,797) |  | — |  | (4,797) |
Issuances of treasury shares | (3) |  | — |  | — |  | 41 |  | 38 |  | — |  | 38 |
Other changes, net | — |  | (5) |  | — |  | — |  | (5) |  | (8) |  | (13) |
Balance at September 30, 2024 | $ | 23,170 |  | $ | 205,503 |  | $ | (2,825) |  | $ | (69,646) |  | $ | 156,202 |  | $ | 828 |  | $ | 157,030 |
Balance at June 30, 2025 | $ | 23,395 |  | $ | 205,905 |  | $ | (2,567) |  | $ | (80,316) |  | $ | 146,417 |  | $ | 841 |  | $ | 147,258 |
Treasury stock transactions | 251 |  | — |  | — |  | — |  | 251 |  | — |  | 251 |
Hess Corporation acquisition | 11,775 |  | — |  | — |  | 33,828 |  | 45,603 |  | 5,035 |  | 50,638 |
Net income (loss) | — |  | 3,539 |  | — |  | — |  | 3,539 |  | 74 |  | 3,613 |
Cash dividends ($1.71 per share) | — |  | (3,429) |  | — |  | — |  | (3,429) |  | (193) |  | (3,622) |
Stock dividends | — |  | (9) |  | — |  | — |  | (9) |  | — |  | (9) |
Other comprehensive income | — |  | — |  | (24) |  | — |  | (24) |  | — |  | (24) |
Purchases of treasury shares(2) | — |  | — |  | — |  | (2,590) |  | (2,590) |  | — |  | (2,590) |
Issuances of treasury shares | (17) |  | — |  | — |  | 102 |  | 85 |  | — |  | 85 |
Other changes, net | — |  | — |  | — |  | — |  | — |  | — |  | — |
Balance at September 30, 2025 | $ | 35,404 |  | $ | 206,006 |  | $ | (2,591) |  | $ | (48,976) |  | $ | 189,843 |  | $ | 5,757 |  | $ | 195,600 |
Nine Months Ended September 30 |  |  |  |  |  |  |
Balance at December 31, 2023 | $ | 22,957 |  | $ | 200,025 |  | $ | (2,960) |  | $ | (59,065) |  | $ | 160,957 |  | $ | 972 |  | $ | 161,929 |
Treasury stock transactions | 251 |  | — |  | — |  | — |  | 251 |  | — |  | 251 |
Net income (loss) | — |  | 14,422 |  | — |  | — |  | 14,422 |  | 68 |  | 14,490 |
Cash dividends ($4.89 per share) | — |  | (8,914) |  | — |  | — |  | (8,914) |  | (210) |  | (9,124) |
Stock dividends | — |  | (17) |  | — |  | — |  | (17) |  | — |  | (17) |
Other comprehensive income | — |  | — |  | 135 |  | — |  | 135 |  | — |  | 135 |
Purchases of treasury shares | — |  | — |  | — |  | (10,833) |  | (10,833) |  | — |  | (10,833) |
Issuances of treasury shares | (38) |  | — |  | — |  | 252 |  | 214 |  | — |  | 214 |
Other changes, net | — |  | (13) |  | — |  | — |  | (13) |  | (2) |  | (15) |
Balance at September 30, 2024 | $ | 23,170 |  | $ | 205,503 |  | $ | (2,825) |  | $ | (69,646) |  | $ | 156,202 |  | $ | 828 |  | $ | 157,030 |
Balance at December 31, 2024 | $ | 23,263 |  | $ | 205,852 |  | $ | (2,760) |  | $ | (74,037) |  | $ | 152,318 |  | $ | 839 |  | $ | 153,157 |
Treasury stock transactions | 450 |  | — |  | — |  | — |  | 450 |  | — |  | 450 |
Hess Corporation acquisition | 11,775 |  | — |  | — |  | 33,828 |  | 45,603 |  | 5,035 |  | 50,638 |
Net income (loss) | — |  | 9,529 |  | — |  | — |  | 9,529 |  | 111 |  | 9,640 |
Cash dividends ($5.13 per share) | — |  | (9,347) |  | — |  | — |  | (9,347) |  | (228) |  | (9,575) |
Stock dividends | — |  | (27) |  | — |  | — |  | (27) |  | — |  | (27) |
Other comprehensive income | — |  | — |  | 169 |  | — |  | 169 |  | — |  | 169 |
Purchases of treasury shares(2) | — |  | — |  | — |  | (9,312) |  | (9,312) |  | — |  | (9,312) |
Issuances of treasury shares | (84) |  | — |  | — |  | 545 |  | 461 |  | — |  | 461 |
Other changes, net | — |  | (1) |  | — |  | — |  | (1) |  | — |  | (1) |
Balance at September 30, 2025 | $ | 35,404 |  | $ | 206,006 |  | $ | (2,591) |  | $ | (48,976) |  | $ | 189,843 |  | $ | 5,757 |  | $ | 195,600 |
(Number of Shares) | Common Stock - 2025 |  | Common Stock - 2024
Three Months Ended September 30 | Issued(3) | Treasury | Outstanding |  | Issued(3) | Treasury | Outstanding
Balance at June 30 | 2,442,676,580 |  | (714,686,204) |  | 1,727,990,376 |  |  | 2,442,676,580 |  | (613,759,467) |  | 1,828,917,113 |
Purchases | — |  | (16,623,281) |  | (16,623,281) |  |  | — |  | (32,209,398) |  | (32,209,398) |
Issuances | — |  | 302,154,502 |  | 302,154,502 |  |  | — |  | 383,610 |  | 383,610 |
Balance at September 30 | 2,442,676,580 |  | (429,154,983) |  | 2,013,521,597 |  |  | 2,442,676,580 |  | (645,585,255) |  | 1,797,091,325 |
Nine Months Ended September 30 |  |  |  |  |  |  |
Balance at December 31 | 2,442,676,580 |  | (673,664,306) |  | 1,769,012,274 |  |  | 2,442,676,580 |  | (577,028,776) |  | 1,865,647,804 |
Purchases | — |  | (60,331,630) |  | (60,331,630) |  |  | — |  | (70,981,509) |  | (70,981,509) |
Issuances | — |  | 304,840,953 |  | 304,840,953 |  |  | — |  | 2,425,030 |  | 2,425,030 |
Balance at September 30 | 2,442,676,580 |  | (429,154,983) |  | 2,013,521,597 |  |  | 2,442,676,580 |  | (645,585,255) |  | 1,797,091,325 |

(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 for all periods.
See accompanying notes to consolidated financial statements.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1. General
Basis of Presentation The accompanying consolidated financial statements of Chevron Corporation and its subsidiaries (together, Chevron or the company) have not been audited by an independent registered public accounting firm. In the opinion of the company’s management, the interim data includes all adjustments necessary for a fair statement of the results for the interim periods. These adjustments were of a normal recurring nature. The results for the three- and nine-month periods ended September 30, 2025, are not necessarily indicative of future financial results. The term “earnings” is defined as net income attributable to Chevron.
Certain notes and other information have been condensed or omitted from the interim financial statements presented in this Quarterly Report on Form 10-Q. Therefore, these financial statements should be read in conjunction with the company’s 2024 Annual Report on Form 10-K.
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 nine months ended September 30, 2025 and 2024, are reflected in the table below.
Changes in Accumulated Other Comprehensive Income (Loss) by Component(1)

|  | Currency Translation Adjustment |  | Unrealized Holding Gains (Losses) on Securities |  | Derivatives |  | Defined Benefit Plans |  | Total
|  | (Millions of dollars)
Balance at December 31, 2023 |  | $ | (192) |  |  | $ | (11) |  |  | $ | 5 |  |  | $ | (2,762) |  |  | $ | (2,960) |
Components of Other Comprehensive Income (Loss): |  |  |  |  |  |  |
Before Reclassifications |  | (9) |  |  | (5) |  |  | (36) |  |  | 13 |  |  | (37) |
Reclassifications(2) (3) |  | — |  |  | — |  |  | 43 |  |  | 129 |  |  | 172 |
Net Other Comprehensive Income (Loss) |  | (9) |  |  | (5) |  |  | 7 |  |  | 142 |  |  | 135 |
Balance at September 30, 2024 |  | $ | (201) |  |  | $ | (16) |  |  | $ | 12 |  |  | $ | (2,620) |  |  | $ | (2,825) |
Balance at December 31, 2024 |  | $ | (259) |  |  | $ | (19) |  |  | $ | (14) |  |  | $ | (2,468) |  |  | $ | (2,760) |
Components of Other Comprehensive Income (Loss): |  |  |  |  |  |
Before Reclassifications |  | 61 |  |  | 16 |  |  | (15) |  |  | (10) |  |  | 52 |
Reclassifications(2) (3) |  | — |  |  | — |  |  | 34 |  |  | 83 |  |  | 117 |
Net Other Comprehensive Income (Loss) |  | 61 |  |  | 16 |  |  | 19 |  |  | 73 |  |  | 169 |
Balance at September 30, 2025 |  | $ | (198) |  |  | $ | (3) |  |  | $ | 5 |  |  | $ | (2,395) |  |  | $ | (2,591) |

(1)All amounts are net of tax.
(2)Refer to Note 14 Financial and Derivative Instruments for reclassified components of cash flow hedging.
(3)Refer to Note 8 Employee Benefits for reclassified components, including amortization of actuarial gains or losses, amortization of prior service costs, and special events, including settlements, totaling $111 that are included in employee benefit costs for the nine months ended September 30, 2025. Related income taxes for the same period, totaling $28, are reflected in “Income Tax Expense (Benefit)” on the Consolidated Statement of Income. All other reclassified amounts were insignificant.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Note 3. Information Relating to the Consolidated Statement of Cash Flows

| Nine Months Ended September 30
| 2025 |  | 2024
| (Millions of dollars)
Distributions more (less) than income from equity affiliates included the following: |  |
Distributions from equity affiliates | $ | 4,139 |  |  | $ | 3,423 |
(Income) loss from equity affiliates | (2,337) |  |  | (3,908) |
Distributions more (less) than income from equity affiliates | $ | 1,802 |  |  | $ | (485) |
Net decrease (increase) in operating working capital was composed of the following:
Decrease (increase) in accounts and notes receivable | $ | 4,018 |  |  | $ | 286 |
Decrease (increase) in inventories | (767) |  |  | (1,113) |
Decrease (increase) in prepaid expenses and other current assets | (375) |  |  | 96 |
Increase (decrease) in accounts payable and accrued liabilities | (4,193) |  |  | (121) |
Increase (decrease) in income and other taxes payable | (1,368) |  |  | (1,320) |
Net decrease (increase) in operating working capital | $ | (2,685) |  |  | $ | (2,172) |
Net cash provided by operating activities included the following cash payments:
Interest on debt (net of capitalized interest) | $ | 573 |  |  | $ | 326 |
Income taxes | 5,524 |  |  | 6,586 |
Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts:
Proceeds and deposits related to asset sales | $ | 1,380 |  |  | $ | 497 |
Returns of investment from equity affiliates | 93 |  |  | 123 |
Proceeds and deposits related to asset sales and returns of investment | $ | 1,473 |  |  | $ | 620 |
Net maturities of (investments in) time deposits consisted of the following gross amounts:
Investments in time deposits | $ | (12) |  |  | $ | (4) |
Maturities of time deposits | 14 |  |  | — |
Net maturities of (investments in) time deposits | $ | 2 |  |  | $ | (4) |
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased | $ | — |  |  | $ | — |
Marketable securities sold | — |  |  | 45 |
Net sales (purchases) of marketable securities | $ | — |  |  | $ | 45 |
Net repayment (borrowing) of loans by equity affiliates consisted of the following gross amounts:
Borrowing of loans by equity affiliates | $ | (263) |  |  | $ | (211) |
Repayment of loans by equity affiliates | 1,061 |  |  | 54 |
Net repayment (borrowing) of loans by equity affiliates | $ | 798 |  |  | $ | (157) |
Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term debt obligations | $ | 6,779 |  |  | $ | 829 |
Repayments of short-term debt obligations | (5,944) |  |  | — |
Net borrowings (repayments) of short-term debt obligations with three months or less maturity | (1,654) |  |  | 4,786 |
Net borrowings (repayments) of short-term obligations | $ | (819) |  |  | $ | 5,615 |
Net contributions from (distributions to) noncontrolling interests consisted of the following gross amounts:
Distributions to noncontrolling interests | $ | (228) |  |  | $ | (210) |
Contributions from noncontrolling interests | 8 |  |  | 13 |
Net contributions from (distributions to) noncontrolling interests | $ | (220) |  |  | $ | (197) |
Net sales (purchases) of treasury shares consisted of the following gross and net amounts:
Shares issued for share-based compensation plans | $ | 313 |  |  | $ | 194 |
Shares purchased under share repurchase and executive compensation plans | (9,081) |  |  | (10,729) |
Share repurchase excise tax payment | (146) |  |  | — |
Net sales (purchases) of treasury shares | $ | (8,914) |  |  | $ | (10,535) |

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
The Consolidated Statement of Cash Flows excludes changes to the Consolidated Balance Sheet that did not affect cash.
The “Other” line in the Operating Activities section includes changes in asset retirement obligations, abandonment and decommissioning obligations associated with previously sold assets, postretirement benefits obligations, and other long-term liabilities.
The company paid dividends of $1.71 per share of common stock in third quarter 2025. This compares to dividends of $1.63 per share paid in the year-ago corresponding period.
The components of “Capital expenditures” are presented in the following table:

| Nine Months Ended September 30
| 2025 |  | 2024
| (Millions of dollars)
Additions to properties, plant and equipment | $ | 11,715 |  |  | $ | 11,590 |
Additions to investments | 150 |  |  | 392 |
Current-year dry hole expenditures | 218 |  |  | $ | 128 |
Capital expenditures | $ | 12,083 |  |  | $ | 12,110 |

The table below quantifies the beginning and ending balances of restricted cash and restricted cash equivalents in the Consolidated Balance Sheet:

| At September 30 |  | At December 31
| 2025 |  | 2024 |  | 2024 |  | 2023
| (Millions of dollars) |  | (Millions of dollars)
Cash and cash equivalents | $ | 7,725 |  |  | $ | 4,699 |  |  | $ | 6,781 |  |  | $ | 8,178 |
Restricted cash included in “Prepaid expenses and other current assets” | 247 |  |  | 240 |  |  | 281 |  |  | 275 |
Restricted cash included in “Deferred charges and other assets” | 811 |  |  | 825 |  |  | 1,200 |  |  | 822 |
Total cash, cash equivalents and restricted cash | $ | 8,783 |  |  | $ | 5,764 |  |  | $ | 8,262 |  |  | $ | 9,275 |

Additional information related to restricted cash is included in Note 13 Fair Value Measurements under the heading “Restricted Cash.”
Note 4. New Accounting Standards
Income Taxes (Topic 740) Improvements to Income Tax Disclosures In December 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standard Update (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 is evaluating 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.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Note 5. Summarized Financial Data — Tengizchevroil LLP
Chevron has a 50 percent equity ownership interest in Tengizchevroil LLP (TCO). Summarized financial information for 100 percent of TCO is presented in the following table:

| Nine Months Ended September 30
| 2025 |  | 2024
| (Millions of dollars)
Sales and other operating revenues | $ | 17,101 |  |  | $ | 14,857 |
Costs and other deductions | 14,101 |  |  | 8,200 |
Net income attributable to TCO | $ | 2,209 |  |  | $ | 4,727 |

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 liquids and natural gas and those associated with refining, marketing, and 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 LLC (CPChem) joint venture, which is accounted for using the equity method.
The summarized financial information for CUSA and its consolidated subsidiaries is as follows:

| Nine Months Ended September 30
| 2025 |  | 2024
| (Millions of dollars)
Sales and other operating revenues | $ | 107,295 |  |  | $ | 112,708 |
Costs and other deductions | 102,605 |  |  | 107,834 |
Net income (loss) attributable to CUSA | $ | 4,148 |  |  | $ | 4,491 |

| At September 30, 2025 |  | At December 31, 2024
| (Millions of dollars)
Current assets | $ | 20,670 |  |  | $ | 20,153 |
Other assets | 58,926 |  |  | 58,485 |
Current liabilities | 19,380 |  |  | 25,825 |
Other liabilities | 31,616 |  |  | 21,455 |
Total CUSA net equity | $ | 28,600 |  |  | $ | 31,358 |
Memo: Total debt | $ | 19,230 |  |  | $ | 8,917 |

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Note 7. 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 liquified natural gas (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 under “Item 10. Directors, Executive Officers and Corporate Governance” on page 32 of the company’s 2024 Annual Report on Form 10-K.
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).
The acquisition of Hess Corporation (Hess) and the company’s new organizational structure did not result in any change to the company’s reportable or operating segments. Hess results have been fully incorporated into the upstream segment.
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 natural gas liquids (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.
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 net 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 three- and nine-month periods ended September 30, 2025 and 2024 are presented in the following tables:
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| Upstream | Downstream | Segment Total | All Other | Total
Three months ended September 30, 2025 | U.S. | Int’l. | U.S. | Int’l.
Sales and other operating revenues before elimination | $ | 12,161 |  | $ | 12,118 |  | $ | 18,234 |  | $ | 17,483 |  | $ | 59,996 |  | $ | 136 |  | $ | 60,132 |
Intersegment revenue elimination | (6,538) |  | (2,576) |  | (1,647) |  | (1,090) |  | (11,851) |  | (112) |  | (11,963) |
Sales and Other Operating Revenues | 5,623 |  | 9,542 |  | 16,587 |  | 16,393 |  | 48,145 |  | 24 |  | 48,169 |
Income (loss) from equity affiliates | (8) |  | 707 |  | 212 |  | 71 |  | 982 |  | (1) |  | 981 |
Other income (loss)(1) | 145 |  | 110 |  | 39 |  | 19 |  | 313 |  | 263 |  | 576 |
Total Revenues and Other Income | 5,760 |  | 10,359 |  | 16,838 |  | 16,483 |  | 49,440 |  | 286 |  | 49,726 |
Intersegment product transfers(2) | 6,179 |  | 1,008 |  | (6,687) |  | (278) |  | 222 |  | (222) |  | — |
Less expenses: |  |  |  |  |  |  |
Purchased crude oil and products | 3,768 |  | 3,437 |  | 6,794 |  | 13,399 |  | 27,398 |  | — |  | 27,398 |
Operating and SG&A expenses | 3,276 |  | 1,580 |  | 2,148 |  | 1,489 |  | 8,493 |  | 635 |  | 9,128 |
Depreciation, depletion and amortization | 2,782 |  | 2,583 |  | 280 |  | 74 |  | 5,719 |  | 62 |  | 5,781 |
Other costs and deductions(3) | 466 |  | 356 |  | 169 |  | 624 |  | 1,615 |  | 390 |  | 2,005 |
Total Costs and Other Deductions | 10,292 |  | 7,956 |  | 9,391 |  | 15,586 |  | 43,225 |  | 1,087 |  | 44,312 |
Income Tax Expense (Benefit) | 310 |  | 1,389 |  | 122 |  | 103 |  | 1,924 |  | (123) |  | 1,801 |
Less: Net income (loss) attributable to non-controlling interests | 55 |  | 2 |  | — |  | 17 |  | 74 |  | — |  | 74 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 1,282 |  | $ | 2,020 |  | $ | 638 |  | $ | 499 |  | $ | 4,439 |  | $ | (900) |  | $ | 3,539 |
Values have been adjusted for eliminations, unless otherwise specified.
(1) Includes interest income of $61 in “All Other.”
(2) Valuation of product transfers between operating segments.
(3) Includes interest expense of $329 in “All Other.”

| Upstream | Downstream | Segment Total | All Other | Total
Three months ended September 30, 2024 | U.S. | Int’l. | U.S. | Int’l.
Sales and other operating revenues before elimination | $ | 10,730 |  | $ | 11,330 |  | $ | 20,167 |  | $ | 19,488 |  | $ | 61,715 |  | $ | 139 |  | $ | 61,854 |
Intersegment revenue elimination | (7,432) |  | (2,745) |  | (2,432) |  | (207) |  | (12,816) |  | (112) |  | (12,928) |
Sales and Other Operating Revenues | 3,298 |  | 8,585 |  | 17,735 |  | 19,281 |  | 48,899 |  | 27 |  | 48,926 |
Income (loss) from equity affiliates | (12) |  | 903 |  | 368 |  | 2 |  | 1,261 |  | — |  | 1,261 |
Other income (loss)(1) | 86 |  | 183 |  | 82 |  | 10 |  | 361 |  | 121 |  | 482 |
Total Revenues and Other Income | 3,372 |  | 9,671 |  | 18,185 |  | 19,293 |  | 50,521 |  | 148 |  | 50,669 |
Intersegment product transfers(2) | 6,292 |  | 1,043 |  | (6,477) |  | (930) |  | (72) |  | 72 |  | — |
Less expenses: |  |  |  |  |  |  |
Purchased crude oil and products | 3,066 |  | 2,903 |  | 8,892 |  | 15,589 |  | 30,450 |  | — |  | 30,450 |
Operating and SG&A expenses | 1,837 |  | 1,524 |  | 2,315 |  | 1,536 |  | 7,212 |  | 723 |  | 7,935 |
Depreciation, depletion and amortization | 1,815 |  | 2,025 |  | 229 |  | 90 |  | 4,159 |  | 55 |  | 4,214 |
Other costs and deductions(3) | 433 |  | 245 |  | 138 |  | 574 |  | 1,390 |  | 191 |  | 1,581 |
Total Costs and Other Deductions | 7,151 |  | 6,697 |  | 11,574 |  | 17,789 |  | 43,211 |  | 969 |  | 44,180 |
Income Tax Expense (Benefit) | 561 |  | 1,373 |  | (12) |  | 123 |  | 2,045 |  | (52) |  | 1,993 |
Less: Net income (loss) attributable to non-controlling interests | 6 |  | 1 |  | — |  | 2 |  | 9 |  | — |  | 9 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 1,946 |  | $ | 2,643 |  | $ | 146 |  | $ | 449 |  | $ | 5,184 |  | $ | (697) |  | $ | 4,487 |
Values have been adjusted for eliminations, unless otherwise specified.
(1) Includes interest income of $64 in “All Other.”
(2) Valuation of product transfers between operating segments.
(3) Includes interest expense of $146 in “All Other.”

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| Upstream | Downstream | Segment Total | All Other | Total
Nine Months Ended September 30, 2025 | U.S. | Int'l. | U.S. | Int'l.
Sales and other operating revenues before elimination | $ | 34,061 |  | $ | 31,271 |  | $ | 55,647 |  | $ | 53,023 |  | $ | 174,002 |  | $ | 405 |  | $ | 174,407 |
Intersegment revenue elimination | (19,971) |  | (6,707) |  | (5,436) |  | (3,316) |  | (35,430) |  | (332) |  | (35,762) |
Sales and Other Operating Revenues | 14,090 |  | 24,564 |  | 50,211 |  | 49,707 |  | 138,572 |  | 73 |  | 138,645 |
Income (loss) from equity affiliates | (29) |  | 1,859 |  | 417 |  | 98 |  | 2,345 |  | (8) |  | 2,337 |
Other income (loss)(1) | 429 |  | 185 |  | 116 |  | 3 |  | 733 |  | 443 |  | 1,176 |
Total Revenues and Other Income | 14,490 |  | 26,608 |  | 50,744 |  | 49,808 |  | 141,650 |  | 508 |  | 142,158 |
Intersegment product transfers(2) | 18,055 |  | 2,159 |  | (19,736) |  | (349) |  | 129 |  | (129) |  | — |
Less expenses: |  |  |  |  |  |  |
Purchased crude oil and products | 10,961 |  | 8,412 |  | 21,843 |  | 41,650 |  | 82,866 |  | — |  | 82,866 |
Operating and SG&A expenses | 7,481 |  | 4,137 |  | 6,540 |  | 4,259 |  | 22,417 |  | 1,997 |  | 24,414 |
Depreciation, depletion and amortization | 6,947 |  | 6,104 |  | 765 |  | 223 |  | 14,039 |  | 209 |  | 14,248 |
Other costs and deductions(3) | 1,214 |  | 976 |  | 518 |  | 1,805 |  | 4,513 |  | 973 |  | 5,486 |
Total Costs and Other Deductions | 26,603 |  | 19,629 |  | 29,666 |  | 47,937 |  | 123,835 |  | 3,179 |  | 127,014 |
Income Tax Expense (Benefit) | 1,319 |  | 3,902 |  | 197 |  | 429 |  | 5,847 |  | (343) |  | 5,504 |
Less: Net income (loss) attributable to non-controlling interests | 65 |  | 7 |  | — |  | 39 |  | 111 |  | — |  | 111 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 4,558 |  | $ | 5,229 |  | $ | 1,145 |  | $ | 1,054 |  | $ | 11,986 |  | $ | (2,457) |  | $ | 9,529 |
Values have been adjusted for eliminations, unless otherwise specified.
(1) Includes interest income of $193 in “All Other.”
(2) Valuation of product transfers between operating segments.
(3) Includes interest expense of $771 in “All Other.”

| Upstream | Downstream | Segment Total | All Other | Total
Nine Months Ended September 30, 2024 | U.S. | Int’l. | U.S. | Int’l.
Sales and other operating revenues before elimination | $ | 33,184 |  | $ | 32,334 |  | $ | 61,889 |  | $ | 58,210 |  | $ | 185,617 |  | $ | 413 |  | $ | 186,030 |
Intersegment revenue elimination | (22,911) |  | (8,742) |  | (7,725) |  | (1,246) |  | (40,624) |  | (326) |  | (40,950) |
Sales and Other Operating Revenues | 10,273 |  | 23,592 |  | 54,164 |  | 56,964 |  | 144,993 |  | 87 |  | 145,080 |
Income (loss) from equity affiliates | (47) |  | 2,998 |  | 863 |  | 95 |  | 3,909 |  | (1) |  | 3,908 |
Other income (loss)(1) | 159 |  | 720 |  | 270 |  | 22 |  | 1,171 |  | 407 |  | 1,578 |
Total Revenues and Other Income | 10,385 |  | 27,310 |  | 55,297 |  | 57,081 |  | 150,073 |  | 493 |  | 150,566 |
Intersegment product transfers(2) | 19,214 |  | 3,393 |  | (20,322) |  | (2,405) |  | (120) |  | 120 |  | — |
Less expenses: |  |  |  |  |  |  |
Purchased crude oil and products | 9,492 |  | 6,748 |  | 25,992 |  | 46,826 |  | 89,058 |  | — |  | 89,058 |
Operating and SG&A expenses | 5,403 |  | 4,568 |  | 6,816 |  | 4,579 |  | 21,366 |  | 1,870 |  | 23,236 |
Depreciation, depletion and amortization | 5,447 |  | 5,757 |  | 673 |  | 242 |  | 12,119 |  | 190 |  | 12,309 |
Other costs and deductions(3) | 1,265 |  | 776 |  | 423 |  | 1,531 |  | 3,995 |  | 521 |  | 4,516 |
Total Costs and Other Deductions | 21,607 |  | 17,849 |  | 33,904 |  | 53,178 |  | 126,538 |  | 2,581 |  | 129,119 |
Income Tax Expense (Benefit) | 1,790 |  | 4,733 |  | 192 |  | 359 |  | 7,074 |  | (117) |  | 6,957 |
Less: Net income (loss) attributable to non-controlling interests | 20 |  | 5 |  | — |  | 43 |  | 68 |  | — |  | 68 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 6,182 |  | $ | 8,116 |  | $ | 879 |  | $ | 1,096 |  | $ | 16,273 |  | $ | (1,851) |  | $ | 14,422 |
Values have been adjusted for eliminations, unless otherwise specified.
(1) Includes interest income of $215 in “All Other.”
(2) Valuation of product transfers between operating segments.
(3) Includes interest expense of $358 in “All Other.”

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Segment Assets Segment assets do not include intercompany investments or intercompany receivables. Segment assets at September 30, 2025, and December 31, 2024, are as follows:

| At September 30, 2025 |  | At December 31, 2024
Segment Assets | (Millions of dollars)
Upstream |  |  |
United States | $ | 88,074 |  |  | $ | 60,914 |
International | 168,746 |  |  | 123,343 |
Goodwill | 4,216 |  |  | 4,226 |
Total Upstream | 261,036 |  |  | 188,483 |
Downstream |  |  |
United States | 34,224 |  |  | 34,253 |
International | 21,346 |  |  | 22,165 |
Goodwill | 352 |  |  | 352 |
Total Downstream | 55,922 |  |  | 56,770 |
Total Segment Assets | 316,958 |  |  | 245,253 |
All Other |  |  |
United States | 8,138 |  |  | 8,382 |
International | 1,405 |  |  | 3,303 |
Total All Other | 9,543 |  |  | 11,685 |
Total Assets — United States | 130,436 |  |  | 103,549 |
Total Assets — International | 191,497 |  |  | 148,811 |
Goodwill | 4,568 |  |  | 4,578 |
Total Assets | $ | 326,501 |  |  | $ | 256,938 |

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Note 8. Employee Benefits
Chevron 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 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. Hess’s employee benefit plans have been incorporated into this note post-acquisition.
The company also sponsors other postretirement employee benefit (OPEB) plans that provide medical and dental benefits, as well as life insurance for qualifying retired employees. The plans are unfunded, and the company and the 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 four percent each year. Certain life insurance benefits are paid by the company.
The components of net periodic benefit costs for 2025 and 2024 are as follows:

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars) | (Millions of dollars)
Pension Benefits |  |  |  |  |  |  |
United States |  |  |  |  |  |  |
Service cost | $ | 92 |  |  | $ | 90 |  |  | $ | 271 |  |  | $ | 268 |
Interest cost | 132 |  |  | 116 |  |  | 379 |  |  | 348 |
Expected return on plan assets | (197) |  |  | (149) |  |  | (544) |  |  | (447) |
Amortization of prior service costs (credits) | 1 |  |  | 1 |  |  | 3 |  |  | 3 |
Amortization of actuarial losses (gains) | 38 |  |  | 60 |  |  | 98 |  |  | 182 |
Curtailment losses (gains)(1) | 56 |  |  | — |  |  | 127 |  |  | — |
Total United States | 122 |  |  | 118 |  |  | 334 |  |  | 354 |
International |  |  |  |  |  |  |
Service cost | 13 |  |  | 14 |  |  | 42 |  |  | 41 |
Interest cost | 55 |  |  | 48 |  |  | 151 |  |  | 143 |
Expected return on plan assets | (53) |  |  | (51) |  |  | (148) |  |  | (148) |
Amortization of prior service costs (credits) | 2 |  |  | 3 |  |  | 8 |  |  | 8 |
Amortization of actuarial losses (gains) | 9 |  |  | 5 |  |  | 33 |  |  | 14 |
Total International | 26 |  |  | 19 |  |  | 86 |  |  | 58 |
Net Periodic Pension Benefit Costs | $ | 148 |  |  | $ | 137 |  |  | $ | 420 |  |  | $ | 412 |
Other Benefits(2) |  |  |  |  |  |  |
Service cost | $ | 7 |  |  | $ | 8 |  |  | $ | 22 |  |  | $ | 25 |
Interest cost | 25 |  |  | 24 |  |  | 75 |  |  | 74 |
Amortization of prior service costs (credits) | (6) |  |  | (7) |  |  | (17) |  |  | (19) |
Amortization of actuarial losses (gains) | (4) |  |  | (4) |  |  | (13) |  |  | (11) |
Curtailment losses (gains) | (1) |  |  | — |  |  | (1) |  |  | — |
Net Periodic Other Benefit Costs | $ | 21 |  |  | $ | 21 |  |  | $ | 66 |  |  | $ | 69 |

(1) Includes special termination benefits of $26 associated with Hess pension plans.
(2) Includes costs for U.S. and international OPEB plans. Obligations for plans outside the United States are not significant relative to the company’s total OPEB obligation.
Through September 30, 2025, a total of $538 million was contributed to employee pension plans (including $453 million to the U.S. plans). Contribution amounts are dependent upon plan investment returns, changes in
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pension obligations, regulatory requirements, and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.
During the first nine months of 2025, the company contributed $112 million to its OPEB plans.
Note 9. Assets Held For Sale
At September 30, 2025, the company classified $26 million of net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with downstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2024 and the first nine months of 2025 were not material.
Note 10. Income Taxes
The income tax expense decreased $192 million between quarterly periods from $2.0 billion in 2024 to $1.8 billion in 2025. The company’s income before income tax expense decreased $1.1 billion from $6.5 billion in 2024 to $5.4 billion in 2025, primarily due to lower upstream realizations, lower affiliate earnings and higher interest costs, partially offset by higher downstream margins and the impacts from higher upstream sales volumes. The company’s effective tax rate increased between quarterly periods from 31 percent in 2024 to 33 percent in 2025. The change in effective tax rate was primarily due to current period unfavorable tax items and mix effects, resulting from the absolute level of earnings or losses and whether they arose in higher or lower tax rate jurisdictions.
The income tax expense decreased $1.5 billion between the nine-month periods from $7.0 billion in 2024 to $5.5 billion in 2025. The company’s income before income tax decreased $6.3 billion from $21.4 billion in 2024 to $15.1 billion in 2025, primarily due to lower upstream realizations and lower affiliate earnings, partially offset by the impacts from higher upstream sales volumes and higher downstream margins. The company’s effective tax rate increased between nine-month periods from 32 percent in 2024 to 36 percent in 2025. The change in effective tax rate was primarily due to current period unfavorable tax items and mix effects, resulting from the absolute level of earnings or losses and whether they arose in higher or lower tax rate jurisdictions.
The company engages in ongoing discussions with tax authorities regarding the resolution of tax matters in various jurisdictions. Both the outcome of these tax matters and the timing of resolution and/or closure of the tax audits are highly uncertain. 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.
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Note 11. 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 33 separate lawsuits filed by various U.S. cities and counties, six 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.1 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.
1 The cases are: Municipality of Bayamon et al. v. Exxon Mobil Corp., et al., No. 22-cv-1550 (D.P.R.) (dismissed on the merits; Plaintiff’s appeal pending); 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.) (dismissed on the merits; Plaintiff’s appeal pending); City of Charleston v. Brabham Oil Co., et al., No. 2020-CP-10-3975 (S.C. Ct. of Com. Pl.) (dismissed on the merits and for lack of personal jurisdiction); 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.) (dismissed on the merits in substantial part); 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.) (dismissed on the merits; Plaintiff’s appeal pending); 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; Plaintiff’s appeal pending); 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.] (voluntarily dismissed); 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.); State of Hawaii v. BP P.L.C., et al., 1CCV-25-0000717 (Haw. Cir. Ct.).
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
Louisiana
Seven coastal parishes and the State of Louisiana have filed lawsuits in Louisiana against numerous oil and gas companies seeking remediation 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.2 The lawsuits allege that the defendants’ historical operations were conducted without necessary permits or failed to comply with permits obtained and seek remediation 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. Most of these cases have been remanded to Louisiana state court. In April 2025, a jury in a Louisiana state court awarded Plaquemines Parish $744.6 million in a trial against Chevron entities. However, the United States Supreme Court subsequently granted a petition for writ of certiorari in a related case and will determine if certain of these cases belong in federal, rather than state, court. A state court judge then continued a hearing on Plaquemines Parish’s motion for entry of judgment on the trial verdict and stayed that case pending a decision by the United States Supreme Court. The company denies this liability and plans to appeal any judgment based on the jury verdict. The jury’s decision was unique to the facts and circumstances of the case and may not be representative of future outcomes for other claims brought against Chevron entities under the SLCRMA. In accordance with guidance on the evaluation of loss contingencies, the company has recorded an accrual of $131 million, which the company believes to be a reasonably estimable loss in light of the available defenses. It is reasonably possible that the estimate of the loss could change based on the progression of the case, including the appeals process. However, because of the uncertainties associated with ongoing litigation, we are unable to estimate the range of reasonably possible loss that may be attributable to liabilities, if any, in excess of the amount accrued. While the company believes the jury verdict is not legally or factually supported and intends to appeal and vigorously pursue post-judgment remedies, there can be no assurances that such defense efforts will be successful. To the extent the company is required to pay remediation damages in these cases, it may have a material adverse effect on our financial position and results of operations. Management believes that the claims in these lawsuits lack legal and factual merit and will continue to vigorously defend against such proceedings.
2 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.).
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Note 12. 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.
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 provision has been made for income taxes for all years under examination or subject to future examination.
Guarantees The company and its subsidiaries have certain contingent liabilities with respect to guarantees, direct or indirect, of debt of affiliated companies or third parties. Under the terms of the guarantee arrangements, the company would generally be required to perform should the affiliated company or third party fail to fulfill its obligations under the arrangements. In some cases, the guarantee arrangements may have recourse provisions that would enable the company to recover any payments made under the terms of the guarantees from assets provided as collateral.
Indemnification 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.
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.
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.
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. 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 nature and amount of the loss is disclosed when it is reasonably possible that the loss could be material. The company accrues a liability when management determines the obligation to be both probable and reasonably estimable. The company could have additional significant obligations revert, primarily in the United States, but is not currently aware of any such obligations that are reasonably possible to be material. The liability balance at the end of third quarter 2025 is $2.2 billion.
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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 13. 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 liability are described as follows:
Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.
Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.
Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair value measurements. Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities.
The fair value hierarchy for assets and liabilities measured at fair value at September 30, 2025, and December 31, 2024, is as follows:
Assets and Liabilities Measured at Fair Value on a Recurring Basis

| At September 30, 2025 |  | At December 31, 2024
| (Millions of dollars)
| Total |  | Level 1 |  | Level 2 |  | Level 3 |  | Total |  | Level 1 |  | Level 2 |  | Level 3
Derivatives - not designated | $ | 178 |  |  | $ | 136 |  |  | $ | 42 |  |  | $ | — |  |  | $ | 137 |  |  | $ | 127 |  |  | $ | 10 |  |  | $ | — |
Derivatives - designated | 7 |  |  | 7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Assets at Fair Value | $ | 185 |  |  | $ | 143 |  |  | $ | 42 |  |  | $ | — |  |  | $ | 137 |  |  | $ | 127 |  |  | $ | 10 |  |  | $ | — |
Derivatives - not designated | 158 |  |  | 127 |  |  | 31 |  |  | — |  |  | 136 |  |  | 47 |  |  | 89 |  |  | — |
Derivatives - designated | — |  |  | — |  |  | — |  |  | — |  |  | 17 |  |  | 17 |  |  | — |  |  | — |
Total Liabilities at Fair Value | $ | 158 |  |  | $ | 127 |  |  | $ | 31 |  |  | $ | — |  |  | $ | 153 |  |  | $ | 64 |  |  | $ | 89 |  |  | $ | — |

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 that, if applicable, are reflected in the table above. 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.
Assets and liabilities carried at fair value at September 30, 2025, and December 31, 2024, are as follows:
Cash and Cash Equivalents The company holds cash equivalents in U.S. and non-U.S. portfolios. The instruments classified as cash equivalents are primarily bank deposits with maturities of 90 days or less, and money market funds. “Cash and cash equivalents” had carrying/fair values of $7.7 billion and $6.8 billion at
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September 30, 2025, and December 31, 2024, 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 September 30, 2025.
Restricted Cash had a carrying/fair value of $1.1 billion and $1.5 billion at September 30, 2025, and December 31, 2024, respectively. At September 30, 2025, restricted cash is classified as Level 1 and includes primarily restricted funds related to certain upstream decommissioning activities and financing programs that are reported in “Prepaid expenses and other current assets” and “Deferred charges and other assets” on the Consolidated Balance Sheet.
Long-Term Debt excluding amounts reclassified from short-term debt and finance lease obligations had a net carrying value of $28.6 billion and $10.8 billion at September 30, 2025, and December 31, 2024, respectively. Long-term debt primarily includes corporate-issued bonds. The fair value of these obligations was $28.6 billion and $9.8 billion at September 30, 2025, and December 31, 2024, respectively. At September 30, 2025, the fair value of these obligations classified as Level 1 was $24.3 billion and Level 2 was $4.3 billion.
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 September 30, 2025, and December 31, 2024, were not material.
Properties, plant and equipment The company did not have any individually material impairments of long- lived assets measured at fair value on a nonrecurring basis to report in third quarter 2025.
Investments and advances The company did not have any individually material impairments of investments and advances measured at fair value on a nonrecurring basis to report in third quarter 2025.
Note 14. Financial and Derivative Instruments
The company’s commodity derivative 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 consolidated 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 commodities and other derivatives activities.
The company uses commodity derivative 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.
Derivative instruments measured at fair value at September 30, 2025, and December 31, 2024, and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are as follows:

Consolidated Balance Sheet: Fair Value of Derivatives
Type of |  |  |  | At September 30, 2025 |  | At December 31, 2024
Contract |  | Balance Sheet Classification |  | (Millions of dollars)
Commodity |  | Accounts and notes receivable, net |  | $ | 91 |  |  | $ | 122 |
Commodity |  | Long-term receivables, net |  | 94 |  |  | 15 |
Total Assets at Fair Value |  | $ | 185 |  |  | $ | 137 |
Commodity |  | Accounts payable |  | $ | 155 |  |  | $ | 127 |
Commodity |  | Deferred credits and other noncurrent obligations |  | 3 |  |  | 26 |
Total Liabilities at Fair Value |  | $ | 158 |  |  | $ | 153 |

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Consolidated Statement of Income: The Effect of Derivatives
|  |  |  | Gain / (Loss) Three Months Ended September 30 |  | Gain / (Loss) Nine Months Ended September 30
Type of |  |  |  | 2025 |  | 2024 |  | 2025 |  | 2024
Contract |  | Statement of Income Classification |  | (Millions of dollars)
Commodity |  | Sales and other operating revenues |  | $ | (71) |  |  | $ | 258 |  |  | $ | (129) |  |  | $ | 18 |
Commodity |  | Purchased crude oil and products |  | 35 |  |  | 55 |  |  | (28) |  |  | 16 |
Commodity |  | Other income (loss) |  | (2) |  |  | (8) |  |  | (9) |  |  | 13 |
Total |  | $ | (38) |  |  | $ | 305 |  |  | $ | (166) |  |  | $ | 47 |

The amount reclassified from AOCL to “Sales and other operating revenues” from designated hedges for the first nine months of 2025 was a loss of $34 million compared with a loss of $43 million in the same period of the prior year. At September 30, 2025, before-tax deferred gains in AOCL related to outstanding crude oil price hedging contracts were $7 million, of which all is expected to be reclassified into earnings during the next 12 months as the hedged crude oil sales are recognized in earnings.
The following table represents gross and net derivative assets and liabilities subject to netting agreements on the Consolidated Balance Sheet at September 30, 2025, and December 31, 2024.

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 Amount
At September 30, 2025 |  | (Millions of dollars)
Derivative Assets - not designated |  | $ | 2,222 |  |  | $ | 2,044 |  |  | $ | 178 |  |  | $ | 5 |  |  | $ | 173 |
Derivative Assets - designated |  | $ | 8 |  |  | $ | 1 |  |  | $ | 7 |  |  | $ | — |  |  | $ | 7 |
Derivative Liabilities - not designated |  | $ | 2,202 |  |  | $ | 2,044 |  |  | $ | 158 |  |  | $ | 5 |  |  | $ | 153 |
Derivative Liabilities - designated |  | $ | 1 |  |  | $ | 1 |  |  | $ | — |  |  | $ | — |  |  | $ | — |
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 |

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.”
Note 15. Revenue
“Sales and other operating revenues” on the Consolidated Statement of Income primarily arise from contracts with customers. Related receivables are included in “Accounts and notes receivable” on the Consolidated Balance Sheet, net of the current expected credit losses. The net balance of these receivables was $12.8 billion and $14.2 billion a t September 30, 2025, and December 31, 2024, 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 Accounting Standard Codification (ASC) 606.
Note 16. Financial Instruments - Credit Losses
Chevron’s expected credit loss allowance balance was $407 million and $611 million at September 30, 2025, and December 31, 2024, respectively, with a majority of the allowance relating to non-trade receivable balances.
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
The majority of the company’s receivable balance is concentrated in trade receivables, with a balance of $16.0 billion at September 30, 2025, 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 $3.3 billion at September 30, 2025, which includes receivables from certain governments in their capacity as joint venture partners. Joint venture partner balances that are paid per contract terms or are 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.
Note 17. Long-Term Debt
The company issued $11.0 billion in aggregate principal amount of floating and fixed rate notes in 2025 as detailed in the table below.

| Principal
| (Millions of dollars)
4.405% notes due 2027 | $ | 750 |
Floating rate notes due 2027 | 750 |
4.475% notes due 2028 | 1,000 |
Floating rate notes due 2028 | 500 |
4.687% notes due 2030 | 1,100 |
4.819% notes due 2032 | 650 |
4.980% notes due 2035 | 750 |
Total Long-Term Debt Issued in February 2025 | $ | 5,500 |

| Principal
| (Millions of dollars)
3.950% notes due 2027 | $ | 500 |
4.050% notes due 2028 | 650 |
Floating rate notes due 2028 | 600 |
4.300% notes due 2030 | 1,200 |
Floating rate notes due 2030 | 400 |
4.500% notes due 2032 | 1,250 |
4.850% notes due 2035 | 900 |
Total Long-Term Debt Issued in August 2025 | $ | 5,500 |

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Note 18. Acquisition of Hess Corporation
On July 18, 2025, the company acquired Hess Corporation (Hess), an independent oil and gas exploration and production company. Hess’s principal upstream operations are in the United States, Guyana and Malaysia. Hess’s operations also include an approximate 38 percent ownership interest in Hess Midstream LP, with operations primarily in the Bakken shale in the Williston Basin area of North Dakota.
The aggregate purchase price of Hess was approximately $48 billion, including 15.38 million shares of Hess common stock purchased in open market transactions in the first quarter of 2025 and 301.25 million shares of Chevron common stock issued as closing consideration in July. As part of the transaction, the company assumed debt with an aggregate outstanding principal value of $8.8 billion. The shares issued represented approximately 15 percent of the shares of Chevron common stock outstanding immediately after the transaction closed on July 18, 2025.
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. Provisional fair value measurements were made for acquired assets and liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the date of acquisition, as information necessary to complete the analysis is obtained. 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 Hess’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.

|  |  | At July 18, 2025
|  |  | (Billions of dollars)
Current assets |  |  | $ | 3.3 |
Properties, plant and equipment |  |  | 73.7 |
Other assets |  |  | 2.5 |
Total assets acquired |  |  | 79.5 |
Current liabilities |  |  | 3.1 |
Long-term debt(1) |  |  | 10.0 |
Deferred income taxes |  |  | 11.0 |
Other liabilities |  |  | 2.4 |
Total liabilities assumed |  |  | 26.5 |
Noncontrolling interest(2) |  |  | 5.0 |
Net assets acquired / purchase price |  |  | $ | 48.0 |

(1) Includes finance leases
(2) Related to Hess Midstream LP
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The long-term debt assumed in the transaction is detailed in the table below:

| Principal
Hess Corporation | (Millions of dollars)
4.300% due 2027 | $ | 1,000 |
7.875% due 2029 | 467 |
7.300% due 2031 | 631 |
7.125% due 2033 | 540 |
6.000% due 2040 | 750 |
5.600% due 2041 | 1,250 |
5.800% due 2047 | 500 |
Total Hess Corporation Debt | $ | 5,138 |
Hess Midstream Operations LP |
5.125% due 2028 | $ | 550 |
5.875% due 2028 | 800 |
6.500% due 2029 | 600 |
4.250% due 2030 | 750 |
5.500% due 2030 | 400 |
Term loan and credit facility borrowings | 646 |
Total Hess Midstream Operations LP Debt | $ | 3,746 |
Unamortized discounts and debt issuance costs | (61) |
Total Long-Term Debt Assumed | $ | 8,823 |
Fair market value adjustment for debt acquired in the acquisition | 247 |
Fair Market Value of Long-Term Debt Assumed | $ | 9,070 |

The following table presents revenue and earnings for Hess since the acquisition date (July 18, 2025), for the periods presented. In addition to the loss quantified in the table, Chevron incurred incremental costs associated with the transaction, resulting in a total Hess-related impact of a loss of approximately $250 million in third quarter 2025. Excluding severance and other transaction related costs, Hess-related earnings were approximately $150 million in the quarter.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2025
| (Millions of dollars)
Sales and other operating revenue | $ | 2,906 |  |  | $ | 2,906 |
Net Income (Loss) Attributable to Chevron Corporation | $ | (129) |  |  | $ | (129) |

The following unaudited pro forma information presents the results of operations as if the acquisition of Hess had occurred January 1, 2024:

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 | 2024 |  | 2025 | 2024
| (Millions of dollars)
Sales and other operating revenue | $ | 48,169 |  | $ | 51,668 |  |  | $ | 146,536 |  | $ | 153,234 |
Net Income (Loss) Attributable to Chevron Corporation | $ | 3,539 |  | $ | 4,749 |  |  | $ | 9,617 |  | $ | 15,597 |

The unaudited pro forma information uses estimates and assumptions based on information available at the time. Management believes the estimates and assumptions to be reasonable; however, actual results may differ significantly from this pro forma financial information. The pro forma information does not reflect any synergistic savings that might be achieved from combining the operations and is not intended to reflect the actual results that would have occurred had the companies actually been combined during the periods presented. The pro forma results reflect pro forma adjustments primarily related to conforming Hess
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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
accounting policies to Chevron’s, additional depreciation expense related to the fair value adjustment of the acquired property, plant and equipment, elimination of intercompany transactions and applicable income tax impacts.
See Item 1A. Risk Factors for a discussion of risks related to the Hess acquisition.
Note 19. Restructuring and Reorganization Costs
The following table summarizes the accrued severance liability on the Consolidated Balance Sheet, which include a third quarter increase of $166 million related to the Hess acquisition, with $114 million reported as “Selling, general and administrative expenses” and $52 million reported as “Operating expenses” on the Consolidated Statement of Income within the upstream segment. The balance is expected to be substantially settled by the end of 2026.

| Amounts Before Tax
| (Millions of dollars)
Balance at January 1, 2025 | $ | 990 |
Accruals/Adjustments | 178 |
Payments | (307) |
Balance at September 30, 2025 | $ | 861 |

Note 20. 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 a 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.
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 for the nine months ended September 30, 2025 and 2024:

| 2025 |  | 2024
| (Millions of dollars)
Balance at January 1 | $ | 12,667 |  |  | $ | 13,833 |
Liabilities assumed in the Hess Corporation acquisition | 1,682 |  |  | — |
Liabilities incurred | 149 |  |  | 38 |
Liabilities settled | (902) |  |  | (1,795) |
Reduction due to asset sales | (456) |  |  | (8) |
Accretion expense | 453 |  |  | 441 |
Revisions in estimated cash flows | 296 |  |  | (63) |
Balance at September 30 | $ | 13,889 |  |  | $ | 12,446 |

The long-term portion of the $13.9 billion balance at September 30, 2025, was $12.6 billion.
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Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations
Third Quarter 2025 Compared with Third Quarter 2024
Key Financial Results

Earnings by Business Segment
| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars) |  | (Millions of dollars)
Upstream |  |  |  |  |  |  |
United States | $ | 1,282 |  |  | $ | 1,946 |  |  | $ | 4,558 |  |  | $ | 6,182 |
International | 2,020 |  |  | 2,643 |  |  | 5,229 |  |  | 8,116 |
Total Upstream | 3,302 |  |  | 4,589 |  |  | 9,787 |  |  | 14,298 |
Downstream |  |  |  |  |  |  |
United States | 638 |  |  | 146 |  |  | 1,145 |  |  | 879 |
International | 499 |  |  | 449 |  |  | 1,054 |  |  | 1,096 |
Total Downstream | 1,137 |  |  | 595 |  |  | 2,199 |  |  | 1,975 |
Total Segment Earnings | 4,439 |  |  | 5,184 |  |  | 11,986 |  |  | 16,273 |
All Other | (900) |  |  | (697) |  |  | (2,457) |  |  | (1,851) |
Net Income (Loss) Attributable to Chevron Corporation (1) (2) | $ | 3,539 |  |  | $ | 4,487 |  |  | $ | 9,529 |  |  | $ | 14,422 |
(1) Includes foreign currency effects. | $ | 147 |  |  | $ | (44) |  |  | $ | (339) |  |  | $ | (202) |
(2) Income (loss) net of tax; also referred to as “earnings” in the discussions that follow. |  |  |

Net income attributable to Chevron Corporation for third quarter 2025 was $3.5 billion ($1.82 per share — diluted), compared with $4.5 billion ($2.48 per share — diluted) in third quarter 2024. The net income attributable to Chevron Corporation for the first nine months of 2025 was $9.5 billion ($5.27 per share —diluted), compared with $14.4 billion ($7.88 per share — diluted) in the first nine months of 2024.
Upstream earnings in third quarter 2025 were $3.3 billion compared with $4.6 billion in the corresponding 2024 period. The decrease was mainly due to lower liquids realizations and lower affiliate earnings. Earnings for the first nine months of 2025 were $9.8 billion compared with $14.3 billion a year earlier. The decrease was mainly due to lower liquids realizations and lower affiliate earnings.
Downstream earnings in third quarter 2025 were $1.1 billion compared with $595 million in the corresponding 2024 period. The increase was mainly due to higher margins on refined product sales and lower operating expenses, partly offset by lower earnings from the 50 percent-owned Chevron Phillips Chemical Company. Earnings for the first nine months of 2025 were $2.2 billion compared with $2.0 billion a year earlier. The increase was mainly due to higher margins on refined product sales and lower operating expenses, partly offset by lower earnings from the 50 percent-owned Chevron Phillips Chemical Company.
Refer to “Results of Operations” for additional discussion of results by business segment and “All Other” activities for the third quarter and first nine months of 2025 versus the same period in 2024.
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Business Environment and Outlook
Chevron Corporation 3 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, Guyana, 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 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 emissions reductions and removals.
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. 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 a 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 emissions 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
3 Incorporated in Delaware in 1926 as Standard Oil Company of California, the company adopted the name Chevron Corporation in 1984 and ChevronTexaco Corporation in 2001. In 2005, ChevronTexaco Corporation changed its name to Chevron Corporation. As used in this report, the term “Chevron” and such terms as “the company,” “the corporation,” “our,” “we,” “us” and “its” may refer to Chevron Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole, but unless stated otherwise they do not include “affiliates” of Chevron — i.e., those companies generally owned 50 percent or less. 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.
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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 energies businesses. To grow its new energies businesses, Chevron plans to leverage 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.
Chevron’s previously disclosed 2050 net zero upstream aspiration and GHG intensity targets through 2028 can be found on pages 36 through 37 of the company’s 2024 Annual Report on Form 10-K. In 2021, the company provided guidance on planned capital spend through 2028 to advance its lower carbon ambitions. From September 2021 through September 30, 2025, Chevron has spent approximately $8.2 billion on these efforts. Due to evolving market conditions, the company has determined that it will no longer provide forward-looking guidance with respect to planned lower carbon capital spend.
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 and persist. Examples of such risks and contingencies include: (1) sufficient and substantial advances in technology, including 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 emissions 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 the risk factors regarding our strategy, aspirations, targets, and disclosures related to environmental, social, and governance matters included on pages 23 through 27 of the company’s 2024 Annual Report on Form 10-K.
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 10 Income Taxes to the Consolidated Financial Statements.
On July 4, 2025, the United States enacted the One Big Beautiful Bill Act (the “OBBBA”), which made significant changes to U.S. tax law. We do not expect that the tax provisions in the OBBBA will have a material impact on our results of operations, but we expect that the OBBBA will have a positive impact on Chevron’s cash flows.
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. Chevron has applied inflation mitigation strategies to temper cost increases, including fixed price and index-based contracts. Lead times for key capital
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equipment remain long due to strong demand levels. Chevron has addressed equipment cost increases and long lead times by partnering with suppliers on demand planning, volume commitments, standardization, and scope optimization. The offshore market remains competitive for vessels and subsea equipment. In the United States, cost pressures for onshore drilling and completion equipment continue to ease.
In 2025, the U.S. announced the imposition of various changing tariffs on imports from our trade partners. The tariff impact in 2025 is currently estimated at less than one percent of the company’s third party spend and is not expected to be material to the company’s financial results. The company continues to work with partners across its supply chain to identify alternative sourcing options and mitigate the impact of the tariffs. However, there is significant uncertainty as to the duration and magnitude of these and any future tariffs that may be imposed and, accordingly, as to the resultant impacts these tariffs could have on the company and its suppliers and the company’s future results of operations.
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. Asset dispositions and restructurings may result in significant gains or losses in future periods. In addition, some assets are sold along with their related liabilities, such as abandonment and decommissioning obligations. In certain instances, such transferred obligations have reverted, and may in the future revert, to the company and result in losses that could be significant. The company has historically recognized losses and could have additional significant obligations revert, primarily in the United States, but is not currently aware of any such obligations that are reasonably possible to be material. Refer to Note 12 Other Contingencies and Commitments for additional information.
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 commodity prices and downstream margins. Management takes these developments into account in the conduct of daily operations and for business planning.
The company has 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 in fourth quarter 2024.
Comments related to earnings trends for the company’s major business areas are as follows:
Upstream Earnings for the upstream segment are closely aligned with industry prices for crude oil, natural gas and natural gas liquids (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.
Chevron has interests in Venezuelan assets operated by independent affiliates. Chevron has been conducting limited activities in Venezuela consistent with the authorization issued by the United States government. The financial results for Chevron’s business in Venezuela have been recorded as non-equity investments since 2020, where income is only recognized when cash is received, and production and reserves are not included
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in the company’s results. Crude oil liftings in Venezuela started in first quarter 2023, which positively impacted the company’s results. Between March 4, 2025, and July 21, 2025, Chevron activities were restricted under applicable general licenses. During this time and since July 21, 2025, Chevron has maintained its presence in Venezuela consistent with the U.S. government sanctions policy, and pursuant to this policy, expects to continue delivering a limited amount of crude oil to the U.S. from these affiliates during 2025. Further, current geopolitical tensions relating to Venezuela could have an impact on the company’s operations in Venezuela and, as a result, impact the company’s future results of operations.
Chevron maintains an equity interest in the Caspian Pipeline Consortium (CPC) that 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 remain uncertain.
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. The conflict between Israel and various regional adversaries has not significantly impacted the company’s operations, with the company continuing to maintain safe and reliable operations while meeting its contractual commitments. The company continues to monitor the potential for further conflict in the region, and any future impacts on the company’s results of operations and financial condition remain uncertain.
Sources: Platts (crude) & Energy Intelligence (natural gas)
The chart above 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 $71 per barrel for the first nine months of 2025, compared with $83 per barrel during the first nine months of 2024, and ended October at about $65 per barrel. For every dollar change in Brent crude oil prices, the company’s annual after-tax earnings and cash flow sensitivity is approximately $450 million. The WTI price averaged $67 per barrel for the first nine months of 2025, compared to $78 per barrel in the first nine months of 2024, and ended October at about $61 per barrel. Crude oil prices weakened slightly in the third quarter as OPEC+ countries increased production, while production from non-OPEC+ countries also continued to grow.
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The U.S. Henry Hub natural gas price averaged $3.49 per thousand cubic feet (MCF) for the first nine months of 2025, compared with $2.20 per MCF during the first nine months of 2024, and ended October at about $3.44 per MCF. In the U.S., mild summer weather and strong production resulted in natural gas storage levels remaining at the upper end of the five-year range during third quarter 2025, leading to lower U.S. Henry Hub prices relative to second quarter 2025.
Outside the United States, prices for natural gas also depend on regional supply and demand, regulatory circumstances and infrastructure conditions in local markets. The company’s long-term contract prices for liquified natural gas (LNG) are typically linked to crude oil prices. Most of the equity LNG offtake from the operated Australian LNG assets is committed under binding long-term contracts, with some sold in the Asian spot LNG market.
See page 41 for the company’s U.S. and international average realizations for the first nine months of 2025 and the same period last year.
Production The company’s worldwide net oil-equivalent production in the first nine months of 2025 averaged 3.61 million barrels per day, up 8 percent from a year ago as growth in TCO, the Permian Basin, and the Gulf of America, as well as the acquisition of Hess, was partly offset by the impacts of asset sales. About 22 percent of the company’s net oil-equivalent production in the first nine months of 2025 occurred in the OPEC+ member countries of Equatorial Guinea, Kazakhstan, Nigeria, and the Partitioned Zone between Saudi Arabia and Kuwait.
Refer to the “Results of Operations” section on page 35 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.
Refer to the “Results of Operations” section beginning on page 36 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.
Refer to “Cautionary Statements Relevant to Forward-Looking Information” on page 2 and to “Risk Factors” on pages 20 through 27 of the company’s 2024 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.
Noteworthy Developments
Certain noteworthy developments in recent months included the following:
•Guinea-Bissau - Entered agreement to explore two frontier exploration blocks.
•Guyana - Achieved first oil at Yellowtail, the fourth development in the offshore Stabroek Block.
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•Guyana - Sanctioned the Hammerhead project, the seventh Stabroek Block development.
•Israel - Extended agreement to increase export of natural gas from Leviathan field in Israel to Egypt.
•Malaysia/Thailand JDA - Sold the company’s interest in Block A-18 at the joint development area.
•Peru - Entered agreement to explore three offshore blocks in Trujillo Basin.
•United States - Announced second long-term agreement to sell liquefied natural gas (LNG) to ENN Global Trading Pte. Ltd. in China, further strengthening the company’s LNG value chain.
•United States - Secured interest in Rome pipeline, connecting crude oil from the Gulf of America to the company’s U.S. Gulf Coast value chain.
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Results of Operations
Business Segments 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.” (Refer to Note 7 Operating Segments and Geographic Data for a discussion of the company’s “reportable segments,” as defined under the accounting standards for segment reporting.)
Upstream

|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit (1) | 2025 |  | 2024 |  | 2025 |  | 2024
U.S. Upstream |  |  |  |  |  |  |  |
Earnings | $MM | $ | 1,282 |  |  | $ | 1,946 |  |  | $ | 4,558 |  |  | $ | 6,182 |
Net Oil-Equivalent Production | MBOED | 2,040 |  |  | 1,605 |  |  | 1,792 |  |  | 1,584 |
Liquids Production | MBD | 1,496 |  |  | 1,156 |  |  | 1,292 |  |  | 1,139 |
Natural Gas Production | MMCFD | 3,265 |  |  | 2,694 |  |  | 2,997 |  |  | 2,665 |
Liquids Realization | $/BBL | $ | 48.12 |  |  | $ | 54.86 |  |  | $ | 50.12 |  |  | $ | 57.33 |
Natural Gas Realization | $/MCF | $ | 1.77 |  |  | $ | 0.55 |  |  | $ | 1.99 |  |  | $ | 0.85 |
(1) 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.

Three Month Periods Ended September 30, 2025 and 2024
U.S. upstream earnings decreased by $664 million primarily due to lower liquids realizations of $600 million and severance and other transaction costs related to the Hess acquisition of $245 million, partly offset by impacts from higher sales volumes of $250 million.
Net oil-equivalent production was up 435,000 barrels per day, or 27 percent. The increase was primarily due to the acquisition of Hess and higher production in the Permian Basin and Gulf of America.
Nine Month Periods Ended September 30, 2025 and 2024
U.S. upstream earnings decreased by $1.6 billion primarily due to lower liquids realizations of $1.7 billion, higher depreciation, depletion and amortization of $770 million, higher operating expenses of $730 million, and severance and other transaction costs related to the Hess acquisition of $245 million, partly offset by higher sales volumes of $1.0 billion, and higher natural gas realizations of $670 million.
Net oil-equivalent production was up 208,000 barrels per day, or 13 percent. The increase was primarily due to higher production in the Permian Basin and Gulf of America, and the acquisition of Hess, partly offset by lower production in the Rockies.

|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit (2) | 2025 |  | 2024 |  | 2025 |  | 2024
International Upstream |  |  |  |  |  |  |  |
Earnings (1) | $MM | $ | 2,020 |  |  | $ | 2,643 |  |  | $ | 5,229 |  |  | $ | 8,116 |
Net Oil-Equivalent Production | MBOED | 2,046 |  |  | 1,759 |  |  | 1,822 |  |  | 1,750 |
Liquids Production | MBD | 1,099 |  |  | 834 |  |  | 925 |  |  | 832 |
Natural Gas Production | MMCFD | 5,674 |  |  | 5,550 |  |  | 5,382 |  |  | 5,513 |
Liquids Realization | $/BBL | $ | 63.16 |  |  | $ | 70.59 |  |  | $ | 63.14 |  |  | $ | 72.70 |
Natural Gas Realization | $/MCF | $ | 6.88 |  |  | $ | 7.46 |  |  | $ | 7.06 |  |  | $ | 7.20 |
(1) Includes foreign currency effects | $MM | $ | 89 |  |  | $ | 13 |  |  | $ | (283) |  |  | $ | (202) |
(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.

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Three Month Periods Ended September 30, 2025 and 2024
International upstream earnings decreased by $623 million primarily due to lower affiliate earnings of $450 million, lower realizations of $370 million, and asset sales of $120 million, partly offset by earnings from legacy Hess of $330 million, primarily in Guyana.
Net oil-equivalent production was up 287,000 barrels per day, or 16 percent. The increase was primarily due to the acquisition of Hess and higher production in Kazakhstan as the Future Growth Project (FGP) at TCO maintained nameplate capacity, partly offset by impacts from asset sales in Canada and Republic of Congo.
Nine Month Periods Ended September 30, 2025 and 2024
International upstream earnings decreased by $2.9 billion primarily due to lower affiliate earnings of $1.6 billion, lower realizations of $760 million, and asset sales of $470 million. Foreign currency effects had an unfavorable impact on earnings of $81 million between periods. These items are partly offset by higher earnings from legacy Hess of $330 million, primarily in Guyana.
Net oil-equivalent production was up 72,000 barrels per day, or 4 percent. The increase was primarily due to higher production in Kazakhstan as FGP at TCO reached nameplate capacity, and the acquisition of Hess, partly offset by asset sales in Canada and Republic of Congo.
Downstream

|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit * | 2025 |  | 2024 |  | 2025 |  | 2024
U.S. Downstream |  |  |  |  |  |  |  |
Earnings | $MM | $ | 638 |  |  | $ | 146 |  |  | $ | 1,145 |  |  | $ | 879 |
Refinery Crude Unit Inputs | MBD | 1,064 |  |  | 995 |  |  | 1,043 |  |  | 925 |
Refined Product Sales | MBD | 1,303 |  |  | 1,312 |  |  | 1,325 |  |  | 1,296 |
* MBD — thousands of barrels per day.

Three Month Periods Ended September 30, 2025 and 2024
U.S. downstream earnings increased by $492 million primarily due to higher margins on refined product sales of $500 million and lower operating expenses of $150 million, partly offset by lower earnings from the 50 percent-owned Chevron Phillips Chemical Company (CPChem) of $130 million.
Refinery crude unit inputs were up 69,000 barrels per day, or 7 percent, primarily due to increased capacity at the Pasadena, Texas refinery upon completion of the Light Tight Oil project.
Refined product sales were down 9,000 barrels per day, or 1 percent, compared to the year-ago period.
Nine Month Periods Ended September 30, 2025 and 2024
U.S. downstream earnings increased by $266 million primarily due to higher margins on refined product sales of $390 million and lower operating expenses of $240 million, partly offset by lower earnings from CPChem of $350 million.
Refinery crude unit inputs were up 118,000 barrels per day, or 13 percent, primarily due to improved operational availability at the El Segundo, California refinery and increased capacity at the Pasadena, Texas refinery upon completion of the Light Tight Oil project.
Refined product sales were up 29,000 barrels per day, or 2 percent, compared to the year-ago period primarily due to higher demand for gasoline and jet fuel.
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|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit (2) | 2025 |  | 2024 |  | 2025 |  | 2024
International Downstream |  |  |  |  |  |  |  |
Earnings (1) | $MM | $ | 499 |  |  | $ | 449 |  |  | $ | 1,054 |  |  | $ | 1,096 |
Refinery Crude Unit Inputs | MBD | 663 |  |  | 628 |  |  | 648 |  |  | 643 |
Refined Product Sales | MBD | 1,517 |  |  | 1,507 |  |  | 1,463 |  |  | 1,473 |
(1) Includes foreign currency effects | $MM | $ | 42 |  |  | $ | (55) |  |  | $ | (57) |  |  | $ | — |
(2) MBD — thousands of barrels per day.

Three Month Periods Ended September 30, 2025 and 2024
International downstream earnings increased by $50 million primarily due to favorable foreign currency effects of $97 million, partly offset by lower margins on refined product sales of $80 million.
Refinery crude unit inputs were up 35,000 barrels per day, or 6 percent, from the year-ago period primarily due to lower turnaround activity at our affiliate refinery in Singapore.
Refined product sales were up 10,000 barrels per day, or 1 percent, from the year-ago period.
Nine Month Periods Ended September 30, 2025 and 2024
International downstream earnings decreased by $42 million primarily due to unfavorable foreign currency effects of $57 million.
Refinery crude unit inputs were up 5,000 barrels per day, or 1 percent.
Refined product sales were down 10,000 barrels per day, or 1 percent.
All Other

|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit | 2025 |  | 2024 |  | 2025 |  | 2024
All Other |  |  |  |  |  |  |  |
Earnings/(Charges)* | $MM | $ | (900) |  |  | $ | (697) |  |  | $ | (2,457) |  |  | $ | (1,851) |
* Includes foreign currency effects |  | $ | 16 |  |  | $ | (2) |  |  | $ | 1 |  |  | $ | — |

Three Month Periods Ended September 30, 2025 and 2024
Net charges increased by $203 million primarily due to higher interest expense, transaction costs related to the Hess acquisition and pension curtailment costs, partly offset by a favorable fair market valuation adjustment for the investment in Hess common stock of $160 million.
Nine Month Periods Ended September 30, 2025 and 2024
Net charges increased by $606 million primarily due to higher interest expense and transaction costs related to the Hess acquisition.
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Consolidated Statement of Income
Explanations of variations between periods for selected income statement categories are provided below:

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Sales and other operating revenues | $ | 48,169 |  |  | $ | 48,926 |  |  | $ | 138,645 |  |  | $ | 145,080 |

Sales and other operating revenues in third quarter and the nine-month period 2025 decreased slightly mainly due to lower crude oil and refined product prices, partially offset by higher crude oil and refined product sales volumes and higher natural gas prices and volumes.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Income from equity affiliates | $ | 981 |  |  | $ | 1,261 |  |  | $ | 2,337 |  |  | $ | 3,908 |

Income from equity affiliates in third quarter and the nine-month period 2025 decreased mainly due to lower upstream-related earnings from TCO in Kazakhstan as higher liftings from the FGP project were more than offset by higher depreciation, depletion and amortization and lower realizations, and lower downstream-related earnings from CPChem primarily due to lower chemicals margins.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Other income (loss) | $ | 576 |  |  | $ | 482 |  |  | $ | 1,176 |  |  | $ | 1,578 |

Other income (loss) in third quarter 2025 increased primarily due to a favorable swing in foreign currency effects and a favorable fair value adjustment for the investment in Hess common stock, partially offset by lower income from Venezuela. Other income (loss) in the nine-month period 2025 decreased mainly due to an unfavorable swing in foreign currency effects and lower income from Venezuela.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Purchased crude oil and products | $ | 27,398 |  |  | $ | 30,450 |  |  | $ | 82,866 |  |  | $ | 89,058 |

Purchased crude oil and products decreased in third quarter 2025 primarily due to lower crude oil and refined product prices and lower refined product volumes, partially offset by higher crude oil and natural gas volumes. Purchased crude oil and products decreased in the nine-month period primarily due to lower crude oil and refined product prices and lower refined product volumes, partially offset by higher crude oil volumes and higher natural gas prices and volumes.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Operating, selling, general and administrative expenses | $ | 9,058 |  |  | $ | 7,886 |  |  | $ | 24,250 |  |  | $ | 23,091 |

Operating, selling, general and administrative expenses in third quarter and for the nine-month period 2025 increased primarily due to the addition of Hess in the quarter and higher professional service fees.
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| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Exploration expenses | $ | 288 |  |  | $ | 154 |  |  | $ | 727 |  |  | $ | 546 |

Exploration expenses in third quarter and the nine-month period 2025 increased primarily due to higher geological and geophysical engineering costs and higher dry hole expenses.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Depreciation, depletion and amortization | $ | 5,781 |  |  | $ | 4,214 |  |  | $ | 14,248 |  |  | $ | 12,309 |

Depreciation, depletion and amortization expenses in third quarter and the nine-month period 2025 increased primarily due to higher production and higher rates.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Taxes other than on income | $ | 1,347 |  |  | $ | 1,263 |  |  | $ | 3,903 |  |  | $ | 3,575 |

Taxes other than on income in third quarter and the nine-month period 2025 increased primarily due to higher excise taxes related to downstream activities.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Interest and debt expense | $ | 370 |  |  | $ | 164 |  |  | $ | 856 |  |  | $ | 395 |

Interest and debt expenses in third quarter and the nine-month period 2025 increased mainly due to a higher debt balance compared to last year, including the debt assumed from the Hess acquisition.

| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Other components of net periodic benefit costs | $ | 70 |  |  | $ | 49 |  |  | $ | 164 |  |  | $ | 145 |

Other components of net periodic benefit costs in third quarter and the nine-month period 2025 were higher mainly due to higher pension curtailment charges.
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| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
| (Millions of dollars)
Income tax expense/(benefit) | $ | 1,801 |  |  | $ | 1,993 |  |  | $ | 5,504 |  |  | $ | 6,957 |

The company’s decrease in income tax expense for third quarter 2025 of $192 million was primarily due to the decrease in total income before tax of $1.1 billion.
U.S. income before tax decreased from $1.8 billion in third quarter 2024 to $1.3 billion in third quarter 2025. This $538 million decrease in income was primarily driven by a loss related to legacy Hess, due in part from severance and transaction costs, and lower upstream realizations, partially offset by the impacts from higher upstream sales volumes and higher downstream margins. The decrease in income had a direct impact on the company’s U.S. income tax, resulting in a decrease in income tax expense of $226 million between year-over-year periods, from $460 million in 2024 to $234 million in 2025.
International income before tax decreased from $4.7 billion in third quarter 2024 to $4.1 billion in third quarter 2025. This $537 million decrease in income was primarily driven by lower upstream realizations, asset sale impacts and lower affiliate income, partially offset by legacy Hess earnings, primarily in Guyana. Despite the decrease in income, the company’s international income tax expense increased by $34 million between year-over-year periods, from $1.5 billion in 2024 to $1.6 billion in 2025, primarily due to current period unfavorable tax items.
The company’s decrease in income tax expense for the first nine months of 2025 of $1.5 billion was primarily due to the decrease in the total income before tax of $6.3 billion.
U.S. income before tax decreased between the nine-month periods, from $6.9 billion in 2024 to $4.3 billion in 2025. This $2.6 billion decrease in income was primarily driven by lower upstream realizations, lower affiliate income and legacy Hess severance and transaction costs, partially offset by the impacts of higher upstream sales volumes and higher downstream sales margins. The decrease in income had a direct impact on the company’s U.S. income tax, resulting in a decrease in income tax expense of $737 million between the nine-month periods, from $1.8 billion in 2024 to $1.0 billion in 2025.
International income before tax decreased between the nine-month periods, from $14.5 billion in 2024 to $10.9 billion in 2025. This $3.7 billion decrease in income was primarily driven by lower affiliate income, asset sale impacts, and lower upstream realizations. The decrease in income had a direct impact on the company’s international income tax, resulting in a decrease in income tax expense of $716 million between year-over-year periods, from $5.2 billion in 2024 to $4.5 billion in 2025.
Additional information related to the company’s effective income tax rate is included in Note 10 Income Taxes to the Consolidated Financial Statements.
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Selected Operating Data
The following table presents a comparison of selected operating data:

Selected Operating Data (1) (2)
|  | Three Months Ended September 30 |  | Nine Months Ended September 30
| Unit | 2025 |  | 2024 |  | 2025 |  | 2024
U.S. Upstream |  |  |  |  |  |  |  |
Net crude oil and natural gas liquids production | MBD | 1,496 |  |  | 1,156 |  |  | 1,292 |  |  | 1,139 |
Net natural gas production(3) | MMCFD | 3,265 |  |  | 2,694 |  |  | 2,997 |  |  | 2,665 |
Net oil-equivalent production | MBOED | 2,040 |  |  | 1,605 |  |  | 1,792 |  |  | 1,584 |
Sales of natural gas | MMCFD | 6,031 |  |  | 5,378 |  |  | 5,683 |  |  | 5,253 |
Sales of natural gas liquids | MBD | 516 |  |  | 481 |  |  | 513 |  |  | 460 |
Revenue from net production |  |  |  |  |  |  |  |
Crude | $/BBL | $ | 62.93 |  |  | $ | 73.04 |  |  | $ | 64.52 |  |  | $ | 75.30 |
NGLs | $/BBL | $ | 18.06 |  |  | $ | 18.34 |  |  | $ | 19.67 |  |  | $ | 19.33 |
Liquids (weighted average of Crude and NGLs) | $/BBL | $ | 48.12 |  |  | $ | 54.86 |  |  | $ | 50.12 |  |  | $ | 57.33 |
Natural gas | $/MCF | $ | 1.77 |  |  | $ | 0.55 |  |  | $ | 1.99 |  |  | $ | 0.85 |
International Upstream |  |  |  |  |  |  |  |
Net crude oil and natural gas liquids production(4) | MBD | 1,099 |  |  | 834 |  |  | 925 |  |  | 832 |
Net natural gas production(3) | MMCFD | 5,674 |  |  | 5,550 |  |  | 5,382 |  |  | 5,513 |
Net oil-equivalent production(4) | MBOED | 2,046 |  |  | 1,759 |  |  | 1,822 |  |  | 1,750 |
Sales of natural gas | MMCFD | 5,682 |  |  | 5,576 |  |  | 5,523 |  |  | 5,579 |
Sales of natural gas liquids | MBD | 127 |  |  | 147 |  |  | 124 |  |  | 132 |
Revenue from liftings |  |  |  |  |  |  |  |
Crude | $/BBL | $ | 64.84 |  |  | $ | 72.82 |  |  | $ | 64.96 |  |  | $ | 75.09 |
NGLs | $/BBL | $ | 18.67 |  |  | $ | 27.44 |  |  | $ | 22.07 |  |  | $ | 23.95 |
Liquids (weighted average of Crude and NGLs) | $/BBL | $ | 63.16 |  |  | $ | 70.59 |  |  | $ | 63.14 |  |  | $ | 72.70 |
Natural gas | $/MCF | $ | 6.88 |  |  | $ | 7.46 |  |  | $ | 7.06 |  |  | $ | 7.20 |
U.S. and International Upstream |  |  |  |  |  |  |  |
Total net oil-equivalent production(4) | MBOED | 4,086 |  |  | 3,364 |  |  | 3,614 |  |  | 3,334 |
U.S. Downstream |  |  |  |  |  |  |  |
Gasoline sales(5) | MBD | 676 |  |  | 684 |  |  | 688 |  |  | 666 |
Other refined product sales | MBD | 627 |  |  | 628 |  |  | 637 |  |  | 630 |
Total refined product sales | MBD | 1,303 |  |  | 1,312 |  |  | 1,325 |  |  | 1,296 |
Sales of natural gas | MMCFD | 26 |  |  | 37 |  |  | 32 |  |  | 31 |
Sales of natural gas liquids | MBD | 29 |  |  | 21 |  |  | 25 |  |  | 22 |
Refinery crude unit inputs | MBD | 1,064 |  |  | 995 |  |  | 1,043 |  |  | 925 |
International Downstream |  |  |  |  |  |  |  |
Gasoline sales(5) | MBD | 336 |  |  | 335 |  |  | 351 |  |  | 335 |
Other refined product sales | MBD | 793 |  |  | 782 |  |  | 735 |  |  | 747 |
Share of affiliate sales | MBD | 388 |  |  | 390 |  |  | 377 |  |  | 391 |
Total refined product sales | MBD | 1,517 |  |  | 1,507 |  |  | 1,463 |  |  | 1,473 |
Sales of natural gas | MMCFD | — |  |  | — |  |  | 1 |  |  | — |
Sales of natural gas liquids | MBD | 109 |  |  | 152 |  |  | 119 |  |  | 136 |
Refinery crude unit inputs | MBD | 663 |  |  | 628 |  |  | 648 |  |  | 643 |
(1) Includes company share of equity affiliates. |  |  |  |  |  |  |  |
(2) MBD — thousands of barrels per day; MMCFD — millions of cubic feet per day; BBL — Barrel; MCF — thousands of cubic feet; oil-equivalent gas 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 (MMCFD):
United States |  | 77 |  |  | 66 |  |  | 62 |  |  | 61 |
International |  | 592 |  |  | 551 |  |  | 575 |  |  | 542 |
(4) Includes net production of synthetic oil: |  |  |  |  |  |  |  |
Canada |  | — |  |  | 48 |  |  | — |  |  | 49 |
(5) Includes branded and unbranded gasoline. |  |  |  |  |  |  |  |

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Liquidity and Capital Resources
Cash, cash equivalents and marketable securities totaled $7.7 billion at September 30, 2025, and $6.8 billion at year-end 2024. The company holds its cash with a diverse group of major financial institutions and has processes and safeguards in place to manage its cash balances and mitigate the risk of loss. Cash provided by operating activities in the first nine months of 2025 was $23.2 billion, compared with $22.8 billion in the year-ago period. Between January and March 2025, Chevron purchased 15.38 million shares of Hess common stock in open market transactions for approximately $2.2 billion. Capital expenditures totaled $12.1 billion in the first nine months of 2025, in line with the year-ago period. Proceeds and deposits related to asset sales and returns of investment totaled $1.5 billion in the first nine months of 2025, compared to $620 million in the year-ago period. Net repayment (borrowing) of loans by equity affiliates included an inflow of $798 million in the first nine months of 2025 due to a loan repayment from TCO, compared with an outflow of $157 million in the year-ago period.
Dividends The company paid dividends of $9.3 billion to common stockholders during the first nine months of 2025. In October 2025, the company declared a quarterly dividend of $1.71 per common share, payable in December 2025.
Debt and Finance Lease Liabilities Chevron’s total debt and finance lease liabilities were $41.5 billion at September 30, 2025, up from $24.5 billion at December 31, 2024. The company issued $11.0 billion of public bonds and retired $3.3 billion of public bonds at maturity while reducing commercial paper balances. In third quarter 2025, the company also assumed $10.0 billion of debt and finance lease liabilities as part of the Hess acquisition, including approximately $3.7 billion related to Hess Midstream Operations LP that is non-recourse to Chevron Corporation.
The company’s primary source for working capital needs is its commercial paper program. The outstanding balance for the company’s commercial paper program at September 30, 2025, was $4.8 billion, compared with $5.4 billion at December 31, 2024. The company’s debt and finance lease liabilities due within one year, consisting primarily of commercial paper, the current portion of long-term debt and redeemable long-term obligations, totaled $11.8 billion at September 30, 2025, and $12.7 billion at December 31, 2024. Of these amounts, $8.25 billion was reclassified to long-term at both September 30, 2025, and December 31, 2024. At September 30, 2025, 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 continually refinance them.
At September 30, 2025, the company had $8.25 billion 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 the 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 September 30, 2025. In addition, 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 CUSA.
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 bonds issued by Chevron Corporation, CUSA, Texaco Capital Inc., Noble Energy, Inc., and Hess Corporation. The securities that are the obligations of, or guaranteed by, Chevron Corporation carry an AA- rating by Standard and Poor’s Corporation (S&P) and an Aa2 rating by Moody’s Investors Service (Moody’s). The company’s U.S. commercial paper is rated A-1+ by S&P and P-1 by Moody’s. All of these ratings denote high-quality, investment-grade securities.
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The company’s future debt level is dependent primarily on results of operations, cash that may be generated from asset dispositions, the capital program, lending commitments to affiliates, loan repayments from affiliates, and shareholder distributions. 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 flexibility to modify capital spending plans, discontinue or curtail the stock repurchase program, sell assets, and increase borrowings to continue paying the common stock dividend. The company remains committed to retaining high-quality debt ratings.
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.

| Nine Months Ended September 30, 2025 |  | Year Ended December 31, 2024
| (Millions of dollars) (unaudited)
Sales and other operating revenues | $ | 70,569 |  |  | $ | 96,035 |
Sales and other operating revenues - related party | 27,137 |  |  | 43,562 |
Total costs and other deductions | 70,405 |  |  | 102,116 |
Total costs and other deductions - related party | 24,459 |  |  | 35,454 |
Net income (loss) | $ | 28,784 |  |  | $ | 73,119 |

| At September 30, 2025 |  | At December 31, 2024
| (Millions of dollars) (unaudited)
Current assets | $ | 19,066 |  |  | $ | 16,918 |
Current assets - related party | 7,586 |  |  | 2,626 |
Other assets | 55,324 |  |  | 57,921 |
Current liabilities | 26,668 |  |  | 30,563 |
Current liabilities - related party | 24,078 |  |  | 22,997 |
Other liabilities | 29,223 |  |  | 23,719 |
Total net equity (deficit) | $ | 2,007 |  |  | $ | 186 |

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. In the aggregate, the company has repurchased 231.1 million shares for $35.5 billion under the 2023 Program, including 16.6 million shares repurchased for $2.6 billion in third quarter 2025. This excludes 15.38 million shares of Hess that were purchased for $2.2 billion in first quarter 2025 and cancelled in connection with the closing of the company’s acquisition of Hess. In addition, the company paid $146 million in excise taxes related to 2024 buybacks in second quarter 2025. Chevron expects share repurchases in the fourth quarter 2025 to be between $2.5-$3.0 billion.
Repurchases 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 and any forward guidance as to expected repurchases do not obligate the company to acquire any particular amount of common stock, and the program may be discontinued or resumed at any time.
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Noncontrolling Interests The company had noncontrolling interests of $5.8 billion at September 30, 2025, and $839 million at December 31, 2024, including non-controlling interest in Hess Midstream LP post-acquisition.
Financial Ratios and Metrics

| At September 30, 2025 |  |  | At December 31, 2024
Current Ratio (1) | 1.2 |  |  |  | 1.1 |
Debt Ratio | 18.0 |  | % |  |  | 13.9 |  | %
Net Debt Ratio (2) | 15.1 |  | % |  |  | 10.4 |  | %

(1) At September 30, 2025, the book value of inventory was lower than replacement cost.
(2) Net Debt Ratio for September 30, 2025, is calculated as short-term debt of $3.6 billion plus long-term debt of $38.0 billion (together, “total debt”) less cash and cash equivalents, time deposits, and marketable securities of $7.7 billion as a percentage of total debt less cash and cash equivalents, time deposits, and marketable securities, plus Chevron Corporation Stockholders’ Equity of $189.8 billion. For the December 31, 2024, calculation, please refer to page 53 of Chevron’s 2024 Annual Report on Form 10-K.

|  |  | Nine Months Ended September 30
|  |  |  |  | 2025 |  | 2024
|  |  | (Millions of dollars)
Net cash provided by operating activities |  |  |  |  | $ | 23,150 |  |  | $ | 22,797 |
Less: Capital expenditures |  |  |  |  | (12,083) |  |  | (12,110) |
Free Cash Flow |  |  |  |  | $ | 11,067 |  |  | $ | 10,687 |

Pension Obligations Information related to pension plan contributions is included in Note 8 Employee Benefits to the Consolidated Financial Statements.
Capital Expenditures The company’s capital expenditures (capex) primarily includes additions to fixed assets or investments for the company’s consolidated subsidiaries and is disclosed in the Consolidated Statement of Cash Flows. Capex was $12.1 billion in the first nine months of 2025, slightly lower than the $12.1 billion in the corresponding 2024 period. Lower spend in downstream businesses was largely offset by higher upstream investment related to legacy Hess assets and the acquisition of lithium acreage.
Affiliate Capital Expenditures The company’s affiliate capital expenditures (affiliate capex) primarily includes additions to fixed assets or investments in the equity affiliate’s financial statements and does not require cash outlays by the company. Third quarter 2025 affiliate capex was $136 million lower than third quarter 2024 and year-to-date 2025 affiliate capex was $455 million lower than the year-ago period due to lower spend at TCO.
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Capex and Affiliate Capex by Business Segment
| Three Months Ended September 30 |  | Nine Months Ended September 30
| 2025 |  | 2024 |  | 2025 |  | 2024
Capex | (Millions of dollars)
United States |  |  |  |  |  |  |
Upstream | $ | 2,383 |  |  | $ | 2,349 |  |  | $ | 7,209 |  |  | $ | 7,126 |
Downstream | 133 |  |  | 349 |  |  | 442 |  |  | 1,116 |
All Other | 112 |  |  | 93 |  |  | 286 |  |  | 274 |
Total United States | 2,628 |  |  | 2,791 |  |  | 7,937 |  |  | 8,516 |
International |  |  |  |  |  |  |
Upstream | 1,732 |  |  | 1,212 |  |  | 3,967 |  |  | 3,462 |
Downstream | 72 |  |  | 47 |  |  | 139 |  |  | 124 |
All Other | 12 |  |  | 5 |  |  | 40 |  |  | 8 |
Total International | 1,816 |  |  | 1,264 |  |  | 4,146 |  |  | 3,594 |
Capex | $ | 4,444 |  |  | $ | 4,055 |  |  | $ | 12,083 |  |  | $ | 12,110 |
Affiliate Capex |  |  |  |  |  |  |
Upstream | $ | 214 |  |  | $ | 329 |  |  | $ | 593 |  |  | $ | 1,110 |
Downstream | 215 |  |  | 236 |  |  | 766 |  |  | 704 |
Affiliate Capex | $ | 429 |  |  | $ | 565 |  |  | $ | 1,359 |  |  | $ | 1,814 |

Contingencies and Significant Litigation
Climate Change Information related to climate change-related matters is included in Note 11 Litigation under the heading “Climate Change.”
Louisiana Information related to Louisiana coastal matters is included in Note 11 Litigation under the heading “Louisiana.”
Income Taxes Information related to income tax contingencies is included in Note 10 Income Taxes and in Note 12 Other Contingencies and Commitments under the heading “Income Taxes.”
Guarantees Information related to the company’s guarantees is included in Note 12 Other Contingencies and Commitments under the heading “Guarantees.”
Indemnification Information related to indemnification is included in Note 12 Other Contingencies and Commitments under the heading “Indemnification.”
Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements Information related to the company’s long-term unconditional purchase obligations and commitments is included in Note 12 Other Contingencies and Commitments under the heading “Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements.”
Environmental Information related to environmental matters is included in Note 12 Other Contingencies and Commitments under the heading “Environmental.”
Acquisition and Disposition of Assets Information related to the company’s acquisition and disposition of assets is included in Note 12 Other Contingencies and Commitments under the headings “Decommissioning Obligations for Previously Sold Assets” and “Other Contingencies.”
Other Contingencies Information related to the company’s other contingencies is included in Note 12 Other Contingencies and Commitments under the heading “Other Contingencies.”
Item 3.Quantitative and Qualitative Disclosures About Market Risk
Information about market risks for the nine months ended September 30, 2025, does not differ materially from that discussed under Item 7A of Chevron’s 2024 Annual Report on Form 10-K.
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Item 4.Controls and Procedures
(a) Evaluation of disclosure controls and procedures
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 Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this report. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the company’s disclosure controls and procedures were effective as of September 30, 2025.
(b) Changes in internal control over financial reporting
In the third quarter of 2025, the company significantly progressed a multi-year implementation of an updated global enterprise resource planning (ERP) system. As a result, the company made corresponding changes to its business processes and information systems, updating applicable internal control over financial reporting where necessary.
Except with respect to the ongoing implementation of ERP systems, there were no changes in the company’s internal control over financial reporting during the quarter ended September 30, 2025, that have materially affected, or are reasonably likely to materially affect, the company’s internal control over financial reporting.
PART II
OTHER INFORMATION
Item 1.Legal Proceedings
Item 103 of Regulation S-K promulgated by the U.S. Securities and Exchange Commission (SEC) requires disclosure of certain legal proceedings that involve governmental authorities as a party and that the company reasonably believes would result in $1.0 million or more of monetary sanctions, exclusive of interest and costs, under federal, state and local laws that have been enacted or adopted regulating the discharge of materials into the environment or primarily for the purpose of protecting the environment. The following proceeding includes those matters relating to third quarter 2025 and any material developments with respect to matters previously reported in Chevron’s 2024 Annual Report on Form 10-K.
In February 2025, the United States Department of Justice notified Hess Corporation of alleged Clean Water Act violations relating to Hess’s National Pollutant Discharge Elimination System permit covering operations in Hess facilities in the Gulf of America. Resolution of the alleged violations may result in the payment of a civil penalty of $1.0 million or more.
Please see information related to other legal proceedings in Note 11 Litigation.
Item 1A.Risk Factors
Some inherent risks could materially impact the company’s results of operations or financial condition. Information about risk factors for the nine months ended September 30, 2025, does not differ materially from that set forth under the heading “Risk Factors” on pages 20 through 27 of the company’s 2024 Annual Report on Form 10-K, other than as reflected in the risk factor below.
The Hess acquisition may cause Chevron’s financial results to differ from the company’s expectations or the expectations of the investment community, the company may not achieve the anticipated benefits of the acquisition, and the acquisition may disrupt the company’s current plans or operations. The success of the Hess acquisition, which closed in July 2025, will depend, in part, on Chevron’s ability to successfully integrate the business of Hess and realize the anticipated benefits, including the anticipated run-rate cost synergies, estimated five-year production and free cash flow growth rates, among other anticipated benefits, and anticipated higher returns to shareholders over the long-term. Difficulties in integrating Hess may result in a failure to realize anticipated synergies in the expected timeframe, in operational challenges, and in the diversion of management’s attention from ongoing business concerns as well as in unforeseen expenses associated with the acquisition, which may have an adverse impact on the company’s financial results.
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Item 2.Unregistered Sales of Equity Securities and Use of Proceeds
CHEVRON CORPORATION
ISSUER PURCHASES OF EQUITY SECURITIES

Period | Total Number of Shares Purchased (1,2) |  | Average Price Paid per Share |  | Total Number of Shares Purchased as Part of Publicly Announced Program |  | Approximate Dollar Value of Shares that May Yet Be Purchased Under the 2023 Program (2) (Billions of dollars)
July 1 - July 31, 2025 | 5,326,866 |  |  | $151.39 |  | 5,324,930 |  |  | $41.3
August 1 - August 31, 2025 | 5,565,175 |  |  | $154.69 |  | 5,563,870 |  |  | $40.4
September 1 - September 30, 2025 | 5,731,240 |  |  | $156.85 |  | 5,731,200 |  |  | $39.5
Total | 16,623,281 |  |  | $154.38 |  | 16,620,000 |  |  |

(1) Includes common shares repurchased from participants in the company’s executive compensation plans for personal income tax withholdings.
(2) Refer to “Liquidity and Capital Resources” for additional information regarding the company’s authorized stock repurchase program.
Item 5.Other Information
Rule 10b5-1 Plan Elections
During the three months ended September 30, 2025, none of our directors or executive officers adopted, modified or terminated a Rule 10b5-1 trading arrangement or a non-Rule 10b5-1 trading arrangement, as such terms are defined in Item 408 of Regulation S-K.
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Item 6.Exhibits

Exhibit Index
Exhibit Number |  | Description
4.1 |  | Fourth Supplemental Indenture, dated as of August 13, 2025, among Chevron U.S.A. Inc., Chevron Corporation, as guarantor, and Deutsche Bank Trust Company Americas, as trustee, filed as Exhibit 4.2 to Chevron Corporation’s Current Report on Form 8-K filed August 13, 2025, and incorporated herein by reference.
4.2 |  | Forms of 3.950% Notes Due 2027, 4.050% Notes Due 2028, Floating Rate Notes Due 2028-B, 4.300% Notes Due 2030, Floating Rate Notes due 2030, 4.500% Notes Due 2032 and 4.850% Notes Due 2035, contained in Exhibit 4.2 to Chevron Corporation’s Current Report on Form 8-K filed August 13, 2025, and incorporated herein by reference.
10.1+* |  | Aircraft Time-Sharing Agreement, dated as of February 24, 2015, between Hess Corporation and John B. Hess.
10.2* |  | Transition Services Agreement, dated as of July 14, 2025, between Chevron U.S.A. Inc. and HFO Holdings LLC.
10.3* |  | Amendment One to Transition Services Agreement, dated as of August 27, 2025, between Chevron U.S.A. Inc. and HFO Holdings LLC.
10.4* |  | Membership Interest Purchase Agreement, dated as of September 10, 2025, between Hess Corporation and JBH Ventures, LLC.
31.1* |  | Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Executive Officer
31.2* |  | Rule 13a-14(a)/15d-14(a) Certification by the company’s Chief Financial Officer
32.1** |  | Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Executive Officer
32.2** |  | Rule 13a-14(b)/15d-14(b) Certification by the company’s Chief Financial Officer
101* |  | Interactive data files (formatted as Inline XBRL)
104* |  | Cover Page Interactive Data File (contained in Exhibit 101)

____________________________________________
+ Indicates a management contract or compensatory plan or arrangement.
* Filed herewith.
** Furnished herewith.
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

| C HEVRON C ORPORATION (R EGISTRANT)
| /S/ A LANA K. K NOWLES
| Alana K. Knowles, Vice President and Controller (Principal Accounting Officer and Duly Authorized Officer)

Date: November 6, 2025
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