cvx-20240930

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, 2024

☐ 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)

5001 Executive Parkway, Suite 200

Delaware

94-0890210

San Ramon,

California

94583-5006

(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: (925) 842-1000

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 1,797,091,325 shares of the company’s common stock outstanding on September 30, 2024.

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 Ni ne Months Ended September 30, 2024 and 2023	3
	Consolidated Statement of Comprehensive Income for the Three and Ni ne Months Ended September 30, 2024 and 2023	4
	Consolidated Balance Sheet at September 30, 2024 and December 31, 2023	5
	Consolidated Statement of Cash Flows for the Nine Months Ended September 30, 2024 and 2023	6
	Consolidated Statement of Equity for the Three and Nine Months Ended September 30, 2024 and 2023	7
	Notes to Consolidated Financial Statements	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	42
Item 4.	Controls and Procedures	42
PART II OTHER INFORMATION
Item 1.	Legal Proceedings	43
Item 1A.	Risk Factors	43
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	44
Item 5.	Other Information	44
Item 6.	Exhibits	45
Signature		46

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 and lower carbon 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,” “may,” “can,” “could,” “should,” “will,” “budgets,” “outlook,” “trends,” “guidance,” “focus,” “on track,” “goals,” “objectives,” “strategies,” “opportunities,” “poised,” “potential,” “ambitions,” “aspires” and similar expressions, and variations or negatives of these words, are intended to identify such forward-looking statements, but not all forward-looking statements include such words. These statements are not guarantees of future performance and are subject to numerous risks, uncertainties and other factors, many of which are beyond the company’s control and are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed or forecasted in such forward-looking statements. The reader should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Chevron undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.

Among the important factors that could cause actual results to differ materially from those in the forward-looking statements are: changing crude oil and natural gas prices and demand for the company’s products, and production curtailments due to market conditions; crude oil production quotas or other actions that might be imposed by the Organization of Petroleum Exporting Countries and other producing countries; technological advancements; changes to government policies in the countries in which the company operates; public health crises, such as pandemics and epidemics, and any related government policies and actions; disruptions in the company’s global supply chain, including supply chain constraints and escalation of the cost of goods and services; changing economic, regulatory and political environments in the various countries in which the company operates; general domestic and international economic, market and political conditions, including the military conflict between Russia and Ukraine, the conflict in Israel 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; timing of crude oil liftings; the competitiveness of alternate-energy sources or product substitutes; development of large carbon capture and offset markets; the results of operations and financial condition of the company’s suppliers, vendors, partners and equity affiliates; the inability or failure of the company’s joint-venture partners to fund their share of operations and development activities; the potential failure to achieve expected net production from existing and future crude oil and natural gas development projects; potential delays in the development, construction or start-up of planned projects; the potential disruption or interruption of the company’s operations due to war, accidents, political events, civil unrest, severe weather, cyber threats, terrorist acts, or other natural or human causes beyond the company’s control; the potential liability for remedial actions or assessments under existing or future environmental regulations and litigation; significant operational, investment or product changes undertaken or required by existing or future environmental statutes and regulations, including international agreements and national or regional legislation and regulatory measures related to greenhouse gas emissions and climate change; the potential liability resulting from pending or future litigation; the risk that regulatory approvals and clearances related to the Hess Corporation (Hess) transaction are not obtained or are obtained subject to conditions that are not anticipated by the company and Hess; potential delays in consummating the Hess transaction, including as a result of the ongoing arbitration proceedings regarding preemptive rights in the Stabroek Block joint operating agreement; risks that such ongoing arbitration is not satisfactorily resolved and the potential transaction fails to be consummated; uncertainties as to whether the potential transaction, if consummated, will achieve its anticipated economic benefits, including as a result of risks associated with third party contracts containing material consent, anti-assignment, transfer or other provisions that may be related to the potential transaction that are not waived or otherwise satisfactorily resolved; the company’s ability to integrate Hess’ operations in a successful manner and in the expected time period; the possibility that any of the anticipated benefits and projected synergies of the potential transaction will not be realized or will not be realized within the expected time period; the company’s future acquisitions or dispositions of assets or shares or the delay or failure of such transactions to close based on required closing conditions; the potential for gains and losses from asset dispositions or impairments; government mandated sales, divestitures, recapitalizations, taxes and tax audits, tariffs, sanctions, changes in fiscal terms or restrictions on scope of company operations; foreign currency movements compared with the U.S. dollar; higher inflation and related impacts; material reductions in corporate liquidity and access to debt markets; changes to the company’s capital allocation strategies; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; the company’s ability to identify and mitigate the risks and hazards inherent in operating in the global energy industry; and the factors set forth under the heading “Risk Factors” on pages 20 through 26 of the company’s 2023 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.

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
	2024		2023		2024		2023
	(Millions of dollars, except per-share amounts)
Revenues and Other Income
Sales and other operating revenues	$	48,926	$	51,922	$	145,080	$	147,980
Income (loss) from equity affiliates	1,261		1,313		3,908		4,141
Other income (loss)	482		845		1,578		1,648
Total Revenues and Other Income	50,669		54,080		150,566		153,769
Costs and Other Deductions
Purchased crude oil and products	30,450		32,328		89,058		90,719
Operating expenses	6,695		6,299		19,842		18,377
Selling, general and administrative expenses	1,191		1,163		3,249		3,172
Exploration expenses	154		301		546		660
Depreciation, depletion and amortization	4,214		4,025		12,309		11,072
Taxes other than on income	1,263		1,021		3,575		3,158
Interest and debt expense	164		114		395		349
Other components of net periodic benefit costs	49		91		145		168
Total Costs and Other Deductions	44,180		45,342		129,119		127,675
Income (Loss) Before Income Tax Expense	6,489		8,738		21,447		26,094
Income Tax Expense (Benefit)	1,993		2,183		6,957		6,926
Net Income (Loss)	4,496		6,555		14,490		19,168
Less: Net income (loss) attributable to noncontrolling interests	9		29		68		58
Net Income (Loss) Attributable to Chevron Corporation	$	4,487	$	6,526	$	14,422	$	19,110
Per Share of Common Stock
Net Income (Loss) Attributable to Chevron Corporation
- Basic	$	2.49	$	3.48	$	7.91	$	10.18
- Diluted	$	2.48	$	3.48	$	7.88	$	10.14
Weighted Average Number of Shares Outstanding (000s)
- Basic	1,800,336		1,870,963		1,822,770		1,876,532
- Diluted	1,807,030		1,877,104		1,829,776		1,884,407

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Net Income (Loss)	$	4,496	$	6,555	$	14,490	$	19,168
Currency translation adjustment	23		(21)		(9)		(21)
Unrealized holding gain (loss) on securities
Net gain (loss) arising during period	4		(1)		(5)		(4)
Derivatives
Net derivatives gain (loss) on hedge transactions	18		(16)		(33)		(18)
Reclassification to net income	16		4		43		17
Income taxes on derivatives transactions	(8)		3		(3)		—
Total	26		(9)		7		(1)
Defined benefit plans
Actuarial gain (loss)
Amortization to net income of net actuarial loss and settlements	61		101		185		197
Actuarial gain (loss) arising during period	1		49		1		49
Prior service credits (cost)
Amortization to net income of net prior service costs and curtailments	(3)		(3)		(8)		(10)
Prior service (costs) credits arising during period	—		—		—		—
Defined benefit plans sponsored by equity affiliates - benefit (cost)	1		—		3		14
Income (taxes) benefit on defined benefit plans	(14)		(2)		(39)		(23)
Total	46		145		142		227
Other Comprehensive Gain (Loss), Net of Tax	99		114		135		201
Comprehensive Income (Loss)	4,595		6,669		14,625		19,369
Comprehensive loss (income) attributable to noncontrolling interests	(9)		(29)		(68)		(58)
Comprehensive Income (Loss) Attributable to Chevron Corporation	$	4,586	$	6,640	$	14,557	$	19,311

See accompanying notes to consolidated financial statements.

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CHEVRON CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)


	At September 30, 2024		At December 31, 2023
	(Millions of dollars)
Assets
Cash and cash equivalents	$	4,699	$	8,178
Time deposits	4		—
Marketable securities	—		45
Accounts and notes receivable (less allowance: 2024 - $259; 2023 - $301)	19,591		19,921
Inventories:
Crude oil and products	6,767		6,059
Chemicals	479		406
Materials, supplies and other	2,479		2,147
Total inventories	9,725		8,612
Prepaid expenses and other current assets	4,168		4,372
Total Current Assets	38,187		41,128
Long-term receivables (less allowance: 2024 - $354; 2023 - $340)	942		942
Investments and advances	47,476		46,812
Properties, plant and equipment, at cost	343,450		346,081
Less: Accumulated depreciation, depletion and amortization	195,559		192,462
Properties, plant and equipment, net	147,891		153,619
Deferred charges and other assets	14,039		13,734
Goodwill	4,722		4,722
Assets held for sale	5,975		675
Total Assets	$	259,232	$	261,632
Liabilities and Equity
Short-term debt	$	5,144	$	529
Accounts payable	20,037		20,423
Accrued liabilities	8,313		7,655
Federal and other taxes on income	702		1,863
Other taxes payable	1,522		1,788
Total Current Liabilities	35,718		32,258
Long-term debt	20,697		20,307

Deferred credits and other noncurrent obligations	21,955		24,226
Noncurrent deferred income taxes	19,899		18,830
Noncurrent employee benefit plans	3,933		4,082
Total Liabilities*	$	102,202	$	99,703
Preferred stock (authorized 100,000,000 shares; $1.00 par value; none issued)	—		—
Common stock (authorized 6,000,000,000 shares, $0.75 par value; 2,442,676,580 shares issued at September 30, 2024 and December 31, 2023)	1,832		1,832
Capital in excess of par value	21,578		21,365
Retained earnings	205,503		200,025
Accumulated other comprehensive losses	(2,825)		(2,960)
Deferred compensation and benefit plan trust	(240)		(240)
Treasury stock, at cost (645,585,255 and 577,028,776 shares at September 30, 2024 and December 31, 2023, respectively)	(69,646)		(59,065)
Total Chevron Corporation Stockholders’ Equity	156,202		160,957
Noncontrolling interests (includes redeemable noncontrolling interest of $0 and $166 at September 30, 2024 and December 31, 2023, respectively)	828		972
Total Equity	157,030		161,929
Total Liabilities and Equity	$	259,232	$	261,632

* 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
	2024		2023
	(Millions of dollars)
Operating Activities
Net Income (Loss)	$	14,490	$	19,168
Adjustments
Depreciation, depletion and amortization	12,309		11,072
Dry hole expense	225		315
Distributions more (less) than income from equity affiliates	(485)		(2,273)
Net before-tax losses (gains) on asset retirements and sales	(236)		(133)
Net foreign currency effects	104		(135)
Deferred income tax provision	1,545		1,346
Net decrease (increase) in operating working capital	(2,172)		(4,181)
Decrease (increase) in long-term receivables	54		36
Net decrease (increase) in other deferred charges	(765)		(423)
Cash contributions to employee pension plans	(658)		(893)
Other	(1,614)		(724)
Net Cash Provided by Operating Activities	22,797		23,175
Investing Activities

Acquisition of businesses, net of cash received	—		55
Capital expenditures	(12,110)		(11,468)
Proceeds and deposits related to asset sales and returns of investment	620		410
Net maturities of (investments in) time deposits	(4)		—
Net sales (purchases) of marketable securities	45		84
Net repayment (borrowing) of loans by equity affiliates	(157)		(242)
Net Cash Used for Investing Activities	(11,606)		(11,161)
Financing Activities
Net borrowings (repayments) of short-term obligations	5,615		(33)
Proceeds from issuances of long-term debt	403		150
Repayments of long-term debt and other financing obligations	(1,062)		(4,207)
Cash dividends - common stock	(8,914)		(8,527)
Net contributions from (distributions to) noncontrolling interests	(197)		(44)
Net sales (purchases) of treasury shares	(10,535)		(11,281)
Net Cash Provided by (Used for) Financing Activities	(14,690)		(23,942)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash	(12)		(187)
Net Change in Cash, Cash Equivalents and Restricted Cash	(3,511)		(12,115)
Cash, Cash Equivalents and Restricted Cash at January 1	9,275		19,121
Cash, Cash Equivalents and Restricted Cash at September 30	$	5,764	$	7,006

See accompanying notes to consolidated financial statements.

Table of Contents

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, 2023	$	20,350	$	196,926	$	(2,711)	$	(56,240)	$	158,325	$	973	$	159,298
Treasury stock transactions	43		—		—		—		43		—		43
PDC Energy, Inc. acquisition	2,550		—		—		3,970		6,520		—		6,520
Net income (loss)	—		6,526		—		—		6,526		29		6,555
Cash dividends ($1.51 per share)	—		(2,852)		—		—		(2,852)		(45)		(2,897)
Stock dividends	—		(6)		—		—		(6)		—		(6)
Other comprehensive income	—		—		114		—		114		—		114
Purchases of treasury shares	—		—		—		(3,424)		(3,424)		—		(3,424)
Issuances of treasury shares	2		—		—		54		56		—		56
Other changes, net	(36)		(1)		—		—		(37)		26		(11)
Balance at September 30, 2023	$	22,909	$	200,593	$	(2,597)	$	(55,640)	$	165,265	$	983	$	166,248

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

Nine Months Ended September 30
Balance at December 31, 2022	$	20,252	$	190,024	$	(2,798)	$	(48,196)	$	159,282	$	960	$	160,242
Treasury stock transactions	123		—		—		—		123		—		123
PDC Energy, Inc. acquisition	2,550		—		—		3,970		6,520		—		6,520
Net income (loss)	—		19,110		—		—		19,110		58		19,168
Cash dividends ($4.53 per share)	—		(8,527)		—		—		(8,527)		(54)		(8,581)
Stock dividends	—		(7)		—		—		(7)		—		(7)
Other comprehensive income	—		—		201		—		201		—		201
Purchases of treasury shares	—		—		—		(11,631)		(11,631)		—		(11,631)
Issuances of treasury shares	20		—		—		217		237		—		237
Other changes, net	(36)		(7)		—		—		(43)		19		(24)
Balance at September 30, 2023	$	22,909	$	200,593	$	(2,597)	$	(55,640)	$	165,265	$	983	$	166,248

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(2)	—		—		—		(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

(Number of Shares)	Common Stock - 2024								Common Stock - 2023
Three Months Ended September 30	Issued(3)		Treasury		Outstanding				Issued(3)		Treasury		Outstanding
Balance at June 30	2,442,676,580		(613,759,467)		1,828,917,113				2,442,676,580		(575,431,362)		1,867,245,218
Purchases	—		(32,209,398)		(32,209,398)				—		(20,721,774)		(20,721,774)
Issuances	—		383,610		383,610				—		41,225,221		41,225,221
Balance at September 30	2,442,676,580		(645,585,255)		1,797,091,325				2,442,676,580		(554,927,915)		1,887,748,665

Nine Months Ended September 30
Balance at December 31	2,442,676,580		(577,028,776)		1,865,647,804				2,442,676,580		(527,460,237)		1,915,216,343
Purchases	—		(70,981,509)		(70,981,509)				—		(70,455,234)		(70,455,234)
Issuances	—		2,425,030		2,425,030				—		42,987,556		42,987,556
Balance at September 30	2,442,676,580		(645,585,255)		1,797,091,325				2,442,676,580		(554,927,915)		1,887,748,665

(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, 2024, 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 2023 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, 2024 and 2023, 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, 2022	$	(203)	$	(12)	$	(12)	$	(2,571)	$	(2,798)
Components of Other Comprehensive Income (Loss):
Before Reclassifications	(21)		(4)		(18)		51		8
Reclassifications(2) (3)	—		—		17		176		193
Net Other Comprehensive Income (Loss)	(21)		(4)		(1)		227		201
Balance at September 30, 2023	$	(224)	$	(16)	$	(13)	$	(2,344)	$	(2,597)

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)

(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 settlement losses, totaling $177 that are included in employee benefit costs for the nine months ended September 30, 2024. Related income taxes for the same period, totaling $48, 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
	2024		2023
	(Millions of dollars)
Distributions more (less) than income from equity affiliates included the following:
Distributions from equity affiliates	$	3,423	$	1,868
(Income) loss from equity affiliates	(3,908)		(4,141)
Distributions more (less) than income from equity affiliates	$	(485)	$	(2,273)
Net decrease (increase) in operating working capital was composed of the following:
Decrease (increase) in accounts and notes receivable	$	286	$	(890)
Decrease (increase) in inventories	(1,113)		(1,136)
Decrease (increase) in prepaid expenses and other current assets	96		(1,121)
Increase (decrease) in accounts payable and accrued liabilities	(121)		1,706
Increase (decrease) in income and other taxes payable	(1,320)		(2,740)
Net decrease (increase) in operating working capital	$	(2,172)	$	(4,181)
Net cash provided by operating activities included the following cash payments:
Interest on debt (net of capitalized interest)	$	326	$	292
Income taxes	6,586		8,189
Proceeds and deposits related to asset sales and returns of investment consisted of the following gross amounts:
Proceeds and deposits related to asset sales	$	497	$	218
Returns of investment from equity affiliates	123		192
Proceeds and deposits related to asset sales and returns of investment	$	620	$	410
Net maturities of (investments in) time deposits consisted of the following gross amounts:
Investments in time deposits	$	(4)	$	—
Maturities of time deposits	—		—
Net maturities of (investments in) time deposits	$	(4)	$	—
Net sales (purchases) of marketable securities consisted of the following gross amounts:
Marketable securities purchased	$	—	$	(289)
Marketable securities sold	45		373
Net sales (purchases) of marketable securities	$	45	$	84
Net repayment (borrowing) of loans by equity affiliates consisted of the following gross amounts:
Borrowing of loans by equity affiliates	$	(211)	$	(296)
Repayment of loans by equity affiliates	54		54
Net repayment (borrowing) of loans by equity affiliates	$	(157)	$	(242)
Net borrowings (repayments) of short-term obligations consisted of the following gross and net amounts:
Proceeds from issuances of short-term debt obligations	$	829	$	—
Repayments of short-term debt obligations	—		—
Net borrowings (repayments) of short-term debt obligations with three months or less maturity	4,786		(33)
Net borrowings (repayments) of short-term obligations	$	5,615	$	(33)
Net contributions from (distributions to) noncontrolling interests consisted of the following gross amounts:
Distributions to noncontrolling interests	$	(210)	$	(54)
Contributions from noncontrolling interests	13		10
Net contributions from (distributions to) noncontrolling interests	$	(197)	$	(44)
Net sales (purchases) of treasury shares consisted of the following gross and net amounts:
Shares issued for share-based compensation plans	$	194	$	237
Shares purchased under share repurchase and deferred compensation plans	(10,729)		(11,518)
Net sales (purchases) of treasury shares	$	(10,535)	$	(11,281)

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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. Asset retirement obligation payments totaled $1.8 billion in the first nine months of 2024, compared to $1.1 billion in the year-ago period.

The company paid dividends of $1.63 per share of common stock in third quarter 2024. This compares to dividends of $1.51 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
	2024		2023
	(Millions of dollars)
Additions to properties, plant and equipment	$	11,590	$	10,602
Additions to investments	392		636
Current-year dry hole expenditures	128		205
Payments for other assets and liabilities, net	—		25
Capital expenditures	$	12,110	$	11,468

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
	2024		2023		2023		2022
	(Millions of dollars)				(Millions of dollars)
Cash and cash equivalents	$	4,699	$	5,797	$	8,178	$	17,678
Restricted cash included in “Prepaid expenses and other current assets”	240		306		275		630
Restricted cash included in “Deferred charges and other assets”	825		903		822		813
Total cash, cash equivalents and restricted cash	$	5,764	$	7,006	$	9,275	$	19,121

Additional information related to restricted cash is included in Note 13 Fair Value Measurements under the heading “Restricted Cash.”

Note 4. New Accounting Standards

Segment Reporting (Topic 280) Improvements to Reportable Segment Disclosures In November 2023, the Financial Accounting Standards Board (FASB) issued Accounting Standard Update (ASU) 2023-07, which becomes effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. The standard requires companies to disclose significant segment expenses. The company does not expect the standard to have a material effect on its consolidated financial statements and continues to evaluate disclosure presentation alternatives.

Income Taxes (Topic 740) Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09, which becomes effective for fiscal years beginning after December 15, 2024. The standard requires companies to disclose specific categories in the income tax rate reconciliation table and the amount of income taxes paid per major jurisdiction. The company does not expect the standard to have a material effect on its consolidated financial statements and continues to evaluate disclosure presentation alternatives.

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:

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)


	Nine Months Ended September 30
	2024		2023
	(Millions of dollars)
Sales and other operating revenues	$	14,857	$	14,720
Costs and other deductions	8,200		7,799
Net income attributable to TCO	$	4,727	$	4,918

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
	2024		2023
	(Millions of dollars)
Sales and other operating revenues	$	112,708	$	113,817
Costs and other deductions	107,834		106,318
Net income (loss) attributable to CUSA	$	4,491	$	6,152


	At September 30, 2024		At December 31, 2023
	(Millions of dollars)
Current assets	$	18,855	$	19,489
Other assets	57,597		54,460
Current liabilities	22,115		20,624
Other liabilities	21,748		22,227
Total CUSA net equity	$	32,589	$	31,098
Memo: Total debt	$	9,571	$	9,740

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 liquefied 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 companies.

The company’s segments are managed by “segment managers” who report to the “chief operating decision maker” (CODM). The segments represent components of the company that engage in activities (a) from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the CODM, which makes decisions about resources to be allocated to the segments and assesses their performance; and (c) for which discrete financial information is available.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

The company’s primary country of operation is the United States of America, its country of domicile. Other components of the company’s operations are reported as “International” (outside the United States).

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 and assets 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.” Earnings by major operating area for the three- and nine-month periods ended September 30, 2024 and 2023, are presented in the following table:


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
Segment Earnings	(Millions of dollars)				(Millions of dollars)
Upstream
United States	$	1,946	$	2,074	$	6,182	$	5,495
International	2,643		3,681		8,116		10,357
Total Upstream	4,589		5,755		14,298		15,852
Downstream
United States	146		1,376		879		3,434
International	449		307		1,096		1,556
Total Downstream	595		1,683		1,975		4,990
Total Segment Earnings	5,184		7,438		16,273		20,842
All Other
Interest expense	(146)		(104)		(358)		(321)
Interest income	64		103		215		401
Other	(615)		(911)		(1,708)		(1,812)
Net Income Attributable to Chevron Corporation	$	4,487	$	6,526	$	14,422	$	19,110

Segment Assets Segment assets do not include intercompany investments or intercompany receivables. Segment assets at September 30, 2024, and December 31, 2023, are as follows:


	At September 30, 2024		At December 31, 2023
Segment Assets	(Millions of dollars)
Upstream
United States	$	59,573	$	58,750
International	128,373		131,685
Goodwill	4,370		4,370
Total Upstream	192,316		194,805
Downstream
United States	34,689		33,066
International	22,516		21,070
Goodwill	352		352
Total Downstream	57,557		54,488
Total Segment Assets	249,873		249,293
All Other
United States	7,186		10,292
International	2,173		2,047
Total All Other	9,359		12,339
Total Assets — United States	101,448		102,108
Total Assets — International	153,062		154,802
Goodwill	4,722		4,722
Total Assets	$	259,232	$	261,632

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

Segment Sales and Other Operating Revenues Segment sales and other operating revenues, including internal transfers, for the three- and nine-month periods ended September 30, 2024 and 2023, are presented in the following table. 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 and natural gas, as well as the sale of third-party production of natural gas. Revenues for the downstream segment are derived primarily from the refining and marketing of petroleum products such as gasoline, jet fuel, gas oils, lubricants, residual fuel oils, other products derived from crude oil, and manufacturing and marketing of renewable fuels. This segment also generates revenues from the manufacture and sale of fuel and lubricant additives 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.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
Sales and Other Operating Revenues	(Millions of dollars)				(Millions of dollars)
Upstream
United States	$	10,730	$	10,278	$	33,184	$	28,656
International	11,330		10,633		32,334		31,705
Subtotal	22,060		20,911		65,518		60,361
Intersegment Elimination — United States	(7,432)		(6,797)		(22,911)		(18,766)
Intersegment Elimination — International	(2,745)		(3,256)		(8,742)		(8,281)
Total Upstream	11,883		10,858		33,865		33,314
Downstream
United States	20,167		22,749		61,889		62,394
International	19,488		21,028		58,210		59,499
Subtotal	39,655		43,777		120,099		121,893
Intersegment Elimination — United States	(2,432)		(2,278)		(7,725)		(5,929)
Intersegment Elimination — International	(207)		(467)		(1,246)		(1,396)
Total Downstream	37,016		41,032		111,128		114,568
All Other
United States	138		149		411		413
International	1		1		2		2
Subtotal	139		150		413		415
Intersegment Elimination — United States	(111)		(117)		(324)		(315)
Intersegment Elimination — International	(1)		(1)		(2)		(2)
Total All Other	27		32		87		98
Sales and Other Operating Revenues
United States	31,035		33,176		95,484		91,463
International	30,819		31,662		90,546		91,206
Subtotal	61,854		64,838		186,030		182,669
Intersegment Elimination — United States	(9,975)		(9,192)		(30,960)		(25,010)
Intersegment Elimination — International	(2,953)		(3,724)		(9,990)		(9,679)
Total Sales and Other Operating Revenues	$	48,926	$	51,922	$	145,080	$	147,980

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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

The company also sponsors other postretirement employee benefit (OPEB) plans that provide medical and dental benefits, as well as life insurance for some active and qualifying retired employees. The plans are unfunded, and the company and 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 2024 and 2023 are as follows:


	Three Months Ended September 30					Nine Months Ended September 30
	2024		2023			2024		2023
	(Millions of dollars)				(Millions of dollars)
Pension Benefits
United States
Service cost	$	90	$	86		$	268	$	257
Interest cost	116		112			348		336
Expected return on plan assets	(149)		(140)			(447)		(419)
Amortization of prior service costs (credits)	1		1			3		3
Amortization of actuarial losses (gains)	60		51			182		152
Settlement losses	—		53			—		53
Total United States	118		163			354		382
International
Service cost	14		15			41		44
Interest cost	48		49			143		145
Expected return on plan assets	(51)		(52)			(148)		(154)
Amortization of prior service costs (credits)	3		2			8		6
Amortization of actuarial losses (gains)	5		2			14		6

Acquisitions / (divestitures)	—		—			—		(2)
Total International	19		16			58		45
Net Periodic Pension Benefit Costs	$	137	$	179		$	412	$	427
Other Benefits*
Service cost	$	8	$	9		$	25	$	25
Interest cost	24		23			74		72
Amortization of prior service costs (credits)	(7)		(6)			(19)		(19)
Amortization of actuarial losses (gains)	(4)		(5)			(11)		(14)

Net Periodic Other Benefit Costs	$	21	$	21		$	69	$	64

* 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, 2024, a total of $658 million was contributed to employee pension plans (including $588 million to the U.S. plans). Contribution amounts are dependent upon plan investment returns, changes in 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 2024, the company contributed $115 million to its OPEB plans.

Note 9. Assets Held For Sale

At September 30, 2024, the company classified $6.0 billion net properties, plant and equipment as “Assets held for sale” on the Consolidated Balance Sheet. These assets are associated with upstream and downstream operations that are anticipated to be sold in the next 12 months. The revenues and earnings contributions of these assets in 2023 and the first nine months of 2024 were not material.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

Note 10. Income Taxes

The income tax expense decreased $190 million between quarterly periods from $2.2 billion in 2023 to $2.0 billion in 2024. The company’s income before income tax expense decreased $2.2 billion from $8.7 billion in 2023 to $6.5 billion in 2024, primarily due to lower downstream margins, lower upstream realizations, unfavorable foreign currency effects and higher upstream depreciation, depletion and amortization, partially offset by higher upstream sales volumes. The company’s effective tax rate increased between quarterly periods from 25 percent in 2023 to 31 percent in 2024. The change in effective tax rate was primarily due to the absence of prior period favorable 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 increased $31 million between the nine-month periods from $6.9 billion in 2023 to $7.0 billion in 2024. The company’s income before income tax expense decreased $4.6 billion from $26.1 billion in 2023 to $21.4 billion in 2024, primarily due to lower downstream margins, higher upstream depreciation, depletion and amortization, higher operating expenses, unfavorable foreign currency effects and lower upstream realizations, partially offset by higher upstream sales volumes and higher downstream affiliate earnings. The company’s effective tax rate increased between nine-month periods from 27 percent in 2023 to 32 percent in 2024. The change in effective tax rate was primarily due to the absence of prior period favorable tax items, 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 outcomes for 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 31 separate lawsuits filed by various U.S. cities and counties, four U.S. states, the District of Columbia, the Commonwealth of Puerto Rico, two Native American tribes, and a trade group in both federal and state courts.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 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.); City of Annapolis v. BP P.L.C., et al., No. C-02-CV-21-000250 (Md. Cir. Ct.); Anne Arundel County v. BP P.L.C., et al., No. C-02-CV-21-000565 (Md. Cir. Ct.); 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, Plaintiffs’ appeal pending); People ex rel. Bonta v. Exxon Mobil Corp., et al., No. CGC-23-609134 (Cal. Super. Ct.); Bucks County v. BP P.L.C., et al., No. 2024-01836 (Pa. Ct. Com. Pl.); City of Charleston v. Brabham Oil Co., et al., No. 2020-CP-10-3975 (S.C. Ct. of Com. Pl.); District of Columbia v. Exxon Mobil Corp., et al., No. 2020-CA-002892-B (D.C. Super. Ct.); Delaware ex rel. Jennings v. BP America Inc., et al., C.A. No. N20C-09-097 (Del. Super. Ct.) (dismissed in substantial part on the merits); City of Hoboken v. Exxon Mobil Corp., et al., No. HUD-L-003179-20 (N.J. Super. Ct.); City and County of Honolulu, et al. v. Sunoco LP, et al., No. 1CCV-20-0000380 (Haw. Cir. Ct.); City of Imperial Beach v. Chevron Corp., et al., No. C17-01227 (Cal. Super. Ct.); King County v. BP P.L.C., et al., No. 18-2-11859-0 (Wash. Super. Ct.) (voluntarily dismissed); Makah Indian Tribe v. Exxon Mobil Corp., et al., No. 23-25216-1-SEA (Wash. Super. Ct.); County of Marin v. Chevron Corp., et al., No. 17-cv-02586 (Cal. Super. Ct.); County of Maui v. Sunoco LP, et al., No. 2CCV-20-0000283 (Haw. Cir. Ct.); County of Multnomah v. Exxon Mobil Corp., et al., No. 23-cv-25164 (Or. Cir. Ct.); Municipality of San Juan, Puerto Rico v. Exxon Mobil Corp., et al., No. 23-cv-01608 (D.P.R.); City of Oakland v. BP P.L.C., et al., No. RG17875889 (Cal. Super. Ct.); Platkin, et al. v. Exxon Mobil Corp., et al., No. MER-L-001797-22 (N.J. Super. Ct.); Estado Libre Asociado de Puerto Rico [Commonwealth of Puerto Rico] v. Exxon Mobil Corp., et al., No. SJ2024CV06512 (Tribunal de Primera Instancia, Estado Libre Asociado de P.R.) [P.R. Ct. of First Instance, Commonwealth of P.R.]; City of New York v. Chevron Corp., et al., No. 18-cv-00182 (S.D.N.Y.) (dismissed on the merits); Pacific Coast Federation of Fishermen’s Associations, Inc. v. Chevron Corp., et al., No. CGC-18-571285 (Cal. Super. Ct.) (voluntarily dismissed); State of Rhode Island v. Chevron Corp., et al., C.A. No. PC-2018-4716 (R.I. Super. Ct.); City of Richmond v. Chevron Corp., et al., No. C18-00055 (Cal. Super. Ct.); City of San Francisco v. BP P.L.C., et al., No. CGC-17-561370 (Cal. Super. Ct.); County of San Mateo v. Chevron Corp., et al., No. 17-CIV-03222 (Cal. Super. Ct.); City of Santa Cruz v. Chevron Corp., et al., No. 17-CV-03243 (Cal. Super. Ct.); County of Santa Cruz v. Chevron Corp., et al., No. 17-CV-03242 (Cal. Super. Ct.); Shoalwater Bay Indian Tribe v. Exxon Mobil Corp., et al., No. 23-2-25215-2-SEA (Wash. Super. Ct.); City of Chicago v. BP P.L.C., et al., No. 2024-CH-01024 (Ill. 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 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 damages and other relief, including the costs of restoring coastal wetlands allegedly impacted by oil field operations. Further such proceedings may be brought by other parties. The Supreme Court denied a petition for writ of certiorari on jurisdictional questions impacting certain of these cases, and those cases have been or will be remanded to Louisiana state court, one of which has been set for trial and is scheduled to begin in March 2025. Federal jurisdictional questions are still being decided for the remaining cases in the United States Court of Appeals for the Fifth Circuit. Due to the unprecedented nature of the suits, the company is unable to estimate any range of possible liability, but given the uncertainty of litigation there can be no assurance that the cases will not have a material adverse effect on the company’s results of operations and financial condition. Management believes that the claims lack legal and factual merit and will continue to vigorously defend against such proceedings.

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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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

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.

Indemnifications The company often includes standard indemnification provisions in its arrangements with its partners, suppliers and vendors in the ordinary course of business, the terms of which range in duration and sometimes are not limited. The company may be obligated to indemnify such parties for losses or claims suffered or incurred in connection with its service or other claims made against such parties.

Long-Term Unconditional Purchase Obligations and Commitments, Including Throughput and Take-or-Pay Agreements The company and its subsidiaries have certain contingent liabilities with respect to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which may relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline and storage capacity, utilities, and petroleum products, to be used or sold in the ordinary course of the company’s business.

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.

Acquisition and Disposition of Assets The company and its affiliates also 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. In addition, some assets are sold along with their related liabilities and 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.

Other Contingencies 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;

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

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, 2024, and December 31, 2023, is as follows:

Assets and Liabilities Measured at Fair Value on a Recurring Basis


	At September 30, 2024								At December 31, 2023
	(Millions of dollars)
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Marketable Securities	$	—	$	—	$	—	$	—	$	45	$	45	$	—	$	—
Derivatives - not designated	167		95		72		—		152		24		128		—
Derivatives - designated	18		18		—		—		7		7		—		—
Total Assets at Fair Value	$	185	$	113	$	72	$	—	$	204	$	76	$	128	$	—
Derivatives - not designated	128		78		50		—		262		160		102		—

Total Liabilities at Fair Value	$	128	$	78	$	50	$	—	$	262	$	160	$	102	$	—

Marketable Securities The company calculates fair value for its marketable securities based on quoted market prices for identical assets. The fair values reflect the cash that would have been received if the instruments were sold at September 30, 2024.

Derivatives The company records most of its derivative instruments — other than any commodity derivative contracts that are accounted for as normal purchase and normal sale — on the Consolidated Balance Sheet at fair value, with the offsetting amount to the Consolidated Statement of Income. The company designates certain derivative instruments as cash flow hedges 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, 2024, and December 31, 2023, 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 $4.7 billion and $8.2 billion at September 30, 2024, and December 31, 2023, respectively. The fair values of cash and cash equivalents are classified as Level 1 and reflect the cash that would have been received if the instruments were settled at September 30, 2024.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

Restricted Cash had a carrying/fair value of $1.1 billion at September 30, 2024 and December 31, 2023. At September 30, 2024, restricted cash is classified as Level 1 and includes primarily restricted funds related to certain upstream decommissioning activities that are reported in “Prepaid expenses and other current assets” and “Deferred charges and other assets” on the Consolidated Balance Sheet.

Long-Term Debt had a net carrying value, excluding amounts reclassified from short-term debt, purchase price fair value adjustments and finance lease obligations, of $11.6 billion and $14.6 billion at September 30, 2024, and December 31, 2023, respectively. The fair value of these obligations was $10.9 billion and $13.7 billion at September 30, 2024, and December 31, 2023, respectively, and they primarily include corporate issued bonds. At September 30, 2024, the fair value of these obligations classified as Level 1 is $10.4 billion and Level 2 is $583 million.

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, 2024, and December 31, 2023, were not material.

The fair value hierarchy for assets and liabilities measured at fair value on a nonrecurring basis at September 30, 2024, is as follows:

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis


	At September 30, 2024
	(Millions of dollars)
									Before-Tax Loss
	Total		Level 1		Level 2		Level 3		Three Months Ended		Nine Months Ended

Properties, plant and equipment, net (held for sale)	$	663	$	—	$	663	$	—	$	145	$	161
Investments and advances	—		—		—		—		9		9
Total Assets at Fair Value	$	663	$	—	$	663	$	—	$	154	$	170

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 2024.

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 2024.

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, 2024, and December 31, 2023, and their classification on the Consolidated Balance Sheet and Consolidated Statement of Income are as follows:

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)


Consolidated Balance Sheet: Fair Value of Derivatives
Type of		At September 30, 2024		At December 31, 2023
Contract	Balance Sheet Classification	(Millions of dollars)
Commodity	Accounts and notes receivable, net	$	172	$	151
Commodity	Long-term receivables, net	13		8
Total Assets at Fair Value		$	185	$	159
Commodity	Accounts payable	$	106	$	216
Commodity	Deferred credits and other noncurrent obligations	22		46
Total Liabilities at Fair Value		$	128	$	262


Consolidated Statement of Income: The Effect of Derivatives
		Gain / (Loss) Three Months Ended September 30				Gain / (Loss) Nine Months Ended September 30
Type of		2024		2023		2024		2023
Contract	Statement of Income Classification	(Millions of dollars)
Commodity	Sales and other operating revenues	$	258	$	(420)	$	18	$	(439)
Commodity	Purchased crude oil and products	55		(202)		16		(183)
Commodity	Other income (loss)	(8)		(8)		13		(24)
		$	305	$	(630)	$	47	$	(646)

The amount reclassified from AOCL to “Sales and other operating revenues” from designated hedges for the first nine months of 2024 was a decrease of $43 million compared with a decrease of $17 million in the same period of the prior year. At September 30, 2024, before-tax deferred gains in AOCL related to outstanding crude oil price hedging contracts were $18 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, 2024, and December 31, 2023.


Consolidated Balance Sheet: The Effect of Netting Derivative Assets and Liabilities
	Gross Amounts Recognized		Gross Amounts Offset		Net Amounts Presented		Gross Amounts Not Offset		Net Amount

At September 30, 2024	(Millions of dollars)
Derivative Assets - not designated	$	2,453	$	2,286	$	167	$	5	$	162
Derivative Assets - designated	$	20	$	2	$	18	$	—	$	18
Derivative Liabilities - not designated	$	2,414	$	2,286	$	128	$	2	$	126
Derivative Liabilities - designated	$	2	$	2	$	—	$	—	$	—
At December 31, 2023
Derivative Assets - not designated	$	2,394	$	2,242	$	152	$	4	$	148
Derivative Assets - designated	$	8	$	1	$	7	$	—	$	7
Derivative Liabilities - not designated	$	2,504	$	2,242	$	262	$	15	$	247
Derivative Liabilities - designated	$	1	$	1	$	—	$	—	$	—

Derivative assets and liabilities are classified on the Consolidated Balance Sheet as accounts and notes receivable, long-term receivables, accounts payable, and deferred credits and other noncurrent obligations. Amounts not offset on the Consolidated Balance Sheet represent positions that do not meet all the conditions for “a right of offset.”

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

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 $13.2 billion and $13.6 billion at September 30, 2024, and December 31, 2023, respectively. Other items included in “Accounts and notes receivable” represent amounts due from partners for their share of joint venture operating and project costs and amounts due from others, primarily related to derivatives, leases, buy/sell arrangements and product exchanges, which are accounted for outside the scope of Accounting Standard Codification (ASC) 606.

Note 16. Financial Instruments - Credit Losses

Chevron’s expected credit loss allowance balance was $613 million and $641 million at September 30, 2024, and December 31, 2023, respectively, with a majority of the allowance relating to non-trade receivable balances.

The majority of the company’s receivable balance is concentrated in trade receivables, with a balance of $17.3 billion at September 30, 2024, which reflects the company’s diversified sources of revenues and is dispersed across the company’s broad worldwide customer base. As a result, the company believes the concentration of credit risk is limited. The company routinely assesses the financial strength of its customers. When the financial strength of a customer is not considered sufficient, alternative risk mitigation measures may be deployed, including requiring prepayments, letters of credit or other acceptable forms of collateral. Once credit is extended and a receivable balance exists, the company applies a quantitative calculation to current trade receivable balances that reflects credit risk predictive analysis, including probability of default and loss given default, which takes into consideration current and forward-looking market data as well as the company’s historical loss data. This statistical approach becomes the basis of the company’s expected credit loss allowance for current trade receivables with payment terms that are typically short-term in nature, with most due in less than 90 days.

Chevron’s non-trade receivable balance was $3.8 billion at September 30, 2024, which includes receivables from certain governments in their capacity as joint venture partners. Joint venture partner balances that are paid as per contract terms or not yet due are subject to the statistical analysis described above while past due balances are subject to additional qualitative management quarterly review. This management review includes review of reasonable and supportable repayment forecasts. Non-trade receivables also include employee and tax receivables that are deemed immaterial and low risk. Equity affiliate loans are also considered non-trade and an associated allowance of zero and $219 million are included within “Investments and advances” on the Consolidated Balance Sheet at September 30, 2024 and December 31, 2023, respectively.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

Note 17. Agreement to Acquire Hess Corporation

On October 23, 2023, Chevron Corporation announced it had entered into a definitive agreement with Hess Corporation (Hess) to acquire all of its outstanding shares in an all-stock transaction, valued at approximately $53 billion, pursuant to which Hess stockholders will receive 1.0250 shares of Chevron common stock for each Hess share. The transaction was unanimously approved by the Boards of Directors of both companies.

On May 28, 2024, a majority of Hess stockholders voted to approve the merger. Following the Federal Trade Commission’s (FTC) review of the transaction, on September 30, 2024, the FTC announced that a majority of the Commission voted to accept a consent agreement among the FTC, Chevron and Hess, resolving the concerns the FTC identified during its review of the transaction. Chevron and Hess haven taken and will continue to take appropriate steps to maintain our ability to close the merger under the Hart-Scott-Rodino Act of 1976, as amended (HSR Act), following satisfactory resolution of the ongoing arbitration proceedings regarding preemptive rights in the Stabroek Block joint operating agreement, including filing additional notifications under the HSR Act.

The filing of the arbitration relating to the right of first refusal contained in an operating agreement among Hess Guyana Exploration Limited, a wholly owned subsidiary of Hess, affiliates of Exxon Mobil Corporation, and China National Offshore Oil Corporation may cause the transaction to be completed at a later time or to fail to be completed. The arbitration merits hearing about the applicability of the right of first refusal to the transaction has been scheduled for May 2025, with a decision expected in the following three months.

Chevron and Hess are working to complete the merger as soon as practicable. However, neither Chevron nor Hess can predict the actual date on which the transaction will be completed, if at all, because it is subject to conditions beyond each company’s control. See Item 1A. Risk Factors for a discussion of risks related to the Hess acquisition.

Note 18. 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.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)

The following table indicates the changes to the company’s before-tax asset retirement obligations for the nine months ended September 30, 2024 and 2023:


	2024		2023
	(Millions of dollars)
Balance at January 1	$	13,833	$	12,701
Liabilities assumed in the PDC Energy, Inc. acquisition	—		220
Liabilities incurred	38		140
Liabilities settled	(1,803)		(1,124)
Accretion expense	441		457
Revisions in estimated cash flows	(63)		316
Balance at September 30	$	12,446	$	12,710

The long-term portion of the $12.4 billion balance at September 30, 2024 was $11.4 billion.

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Item 2.Management’s Discussion and Analysis of Financial Condition and Results of Operations

Third Quarter 2024 Compared with Third Quarter 2023

Key Financial Results


Earnings by Business Segment
	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)				(Millions of dollars)
Upstream
United States	$	1,946	$	2,074	$	6,182	$	5,495
International	2,643		3,681		8,116		10,357
Total Upstream	4,589		5,755		14,298		15,852
Downstream
United States	146		1,376		879		3,434
International	449		307		1,096		1,556
Total Downstream	595		1,683		1,975		4,990
Total Segment Earnings	5,184		7,438		16,273		20,842
All Other	(697)		(912)		(1,851)		(1,732)
Net Income (Loss) Attributable to Chevron Corporation (1) (2)	$	4,487	$	6,526	$	14,422	$	19,110

(1) Includes foreign currency effects.	$	(44)	$	285	$	(202)	$	255
(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 2024 was $4.5 billion ($2.48 per share — diluted), compared with $6.5 billion ($3.48 per share — diluted) in third quarter 2023. The net income attributable to Chevron Corporation for the first nine months of 2024 was $14.4 billion ($7.88 per share —diluted), compared with $19.1 billion ($10.14 per share — diluted) in the first nine months of 2023.

Upstream earnings in third quarter 2024 were $4.6 billion compared with $5.8 billion in the corresponding 2023 period. The decrease was mainly due to the absence of prior year favorable foreign currency effects, absence of prior year favorable tax effects, and lower realizations, partially offset by higher sales volumes. Earnings for the first nine months of 2024 were $14.3 billion compared with $15.9 billion a year earlier. The decrease was mainly due to higher depreciation, depletion and amortization, an unfavorable swing in tax effects, negative foreign currency effects, and lower realizations, partially offset by higher sales volumes.

Downstream earnings in third quarter 2024 were $595 million compared with $1.7 billion in the corresponding 2023 period. The decrease was mainly due to lower margins on refined product sales. Earnings for the first nine months of 2024 were $2.0 billion compared with $5.0 billion a year earlier. The decrease was mainly due to lower margins on refined product sales and higher operating expenses.

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 2024 versus the same periods in 2023.

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Business Environment and Outlook

Chevron Corporation3 is a global energy company with direct and indirect subsidiaries and affiliates that conduct substantial business activities in the following countries: Angola, Argentina, Australia, Bangladesh, Brazil, Canada, China, Egypt, Equatorial Guinea, Israel, Kazakhstan, Mexico, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait, the Philippines, the Republic of Congo, 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.

Governments, companies, communities, and other stakeholders are increasingly supporting efforts to address climate change. International initiatives and national, regional and state legislation and regulations that aim to directly or indirectly reduce GHG emissions are in various stages of design, adoption, and implementation. These policies and programs, some of which support the global net zero emissions ambitions of the Paris Agreement, can change the amount of energy consumed, the rate of energy-demand growth, the energy mix, and the relative economics of one fuel versus another. Implementation of jurisdiction-specific policies and programs can be dependent on, and can affect the pace of, technological advancements, the granting of necessary permits by governing authorities, the availability and acceptability of cost-effective, verifiable carbon credits, the availability of suppliers that can meet our sustainability-related standards, evolving regulatory or other requirements affecting ESG standards or other disclosures, and evolving standards for tracking, reporting, marketing and advertising relating to emissions and emission 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 the Paris Agreement’s global approach to governments addressing climate change and continues to take actions to help lower the carbon intensity of its operations while continuing to meet the demand for energy. Chevron believes that broad, market-based mechanisms are the most efficient approach to addressing GHG emission reductions. Chevron integrates climate change-related issues and the regulatory and other responses to these issues into its strategy and planning, capital investment reviews, and risk management tools and processes, where it believes they are applicable. They are also factored into the company’s long-range supply, demand, and energy price forecasts. These forecasts reflect estimates of long-range effects from climate change-related policy actions, such as electric vehicle and renewable fuel penetration, energy efficiency standards, and demand response to oil and natural gas prices.

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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The company will continue to develop oil and gas resources to meet customers’ and consumers’ demand for energy. At the same time, Chevron believes that the future of energy is lower carbon. The company will continue to maintain flexibility in its portfolio to be responsive to changes in policy, technology, and customer and consumer preferences. Chevron aims to grow its oil and gas business, lower the carbon intensity of its operations and grow lower carbon businesses in renewable fuels, carbon capture and offsets, hydrogen and other emerging technologies. To grow its lower carbon businesses, Chevron plans to target sectors of the economy where emissions are harder to abate or that cannot be easily electrified, while leveraging the company’s capabilities, assets, partnerships, and customer relationships. The company’s oil and gas business may increase or decrease depending upon regulatory or market forces, among other factors.

Chevron’s previously disclosed 2050 net zero upstream aspiration, carbon intensity targets and planned lower-carbon capital spend through 2028 can be found on pages 35 through 36 of the company’s 2023 Annual Report on Form 10-K.

Chevron’s goals, targets and aspirations reflect Chevron’s current plans, and Chevron regularly evaluates its goals, targets and aspirations and may eliminate, increase or decrease them for various reasons, including market conditions; changes in its portfolio; and financial, operational, regulatory, reputational, legal and other factors. The company’s ability to achieve any aspiration, target or objective is subject to numerous risks, many of which are outside of our control. Examples of such risks include: (1) sufficient and substantial advances in technology, including the continuing progress of commercially viable technologies and low- or non-carbon-based energy sources; (2) laws, governmental regulation, policies, and other enabling actions, including those regarding subsidies, tax and other incentives as well as the granting of necessary permits by governing authorities; (3) the availability and acceptability of cost-effective, verifiable carbon credits; (4) the availability of suppliers that can meet our 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) customer and consumer 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. Please refer to the risk factors regarding our aspirations, targets, and disclosures related to environmental, social, and governance matters included on pages 25 through 26 of the company’s 2023 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.

In December 2021, the Organization for Economic Co-operation and Development (OECD) issued model rules for a new 15 percent global minimum tax (Pillar Two), and various jurisdictions in which the company operates enacted or are in the process of enacting Pillar Two legislation. Certain aspects of the tax under the Pillar Two framework are effective in 2024 in some jurisdictions and in 2025 (or later) in others. Although we do not currently expect that Pillar Two will have a material impact on our results of operations, we are continuing to evaluate the impact of legislative adoption by individual countries.

Supply Chain and Inflation Impacts The company is actively managing its contracting, procurement, and supply chain activities to effectively manage costs and facilitate supply chain resiliency and continuity in support of the company’s operational goals. Third party costs for capital and operating expenses can be subject to external factors beyond the company’s control including, but not limited to: severe weather or civil unrest, delays in construction, global and local supply chain distribution issues, inflation, tariffs or other taxes imposed on goods or services, and market-based prices charged by the industry’s material and service providers. Chevron utilizes contracts with various pricing mechanisms, which may result in a lag before the company’s costs reflect changes in market trends.

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While macroeconomic inflation has slowed, trends in the cost of goods and services vary by spend category. The labor market remains tight, and suppliers are passing along wage rate increases for labor intensive operations. Chevron has applied inflation mitigation strategies to temper these cost increases, including fixed price and index-based contracts. Lead times for key capital equipment remain long and availability of offshore and specialized equipment is under pressure, with some experiencing upward pricing movements. Chevron has addressed equipment cost increases and long lead times by partnering with suppliers on demand planning, volume commitments, standardization, and scope optimization. Cost pressures for materials and onshore drilling and completion equipment in the United States continue to ease.

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 5 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. For example, in fourth quarter 2023, the company recognized an after-tax loss of $1.9 billion related to abandonment and decommissioning obligations from previously sold oil and gas production assets in the U.S. Gulf of Mexico, because the companies that purchased these assets have filed for protection under the U.S. bankruptcy courts. The company is not currently aware of any additional potential material exposure that is reasonably possible.

In October 2024, the company announced that Chevron Canada Limited, an indirect subsidiary, and its related entity entered into a definitive agreement to sell their 20 percent non-operated interest in the Athabasca Oil Sands Project and 70 percent operated interest in the Duvernay shale in Alberta, Canada, to Canadian Natural Resources Limited for $6.5 billion before taxes. The sale is expected to close in fourth quarter 2024, and upon close of the sale, the buyer will assume the asset retirement obligations. In 2023, these assets produced 84 thousand barrels of oil-equivalent per day and generated over $2.3 billion of sales and approximately $700 million of net income. As part of the sale, the company expects to recognize a reduction of approximately 700 million barrels of oil-equivalent proved reserves.

In October 2023, the company announced that it had entered into a definitive merger agreement with Hess Corporation. Refer to Note 17 Agreement to Acquire Hess Corporation 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 recently 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 expects to recognize restructuring and reorganization charges in future periods, which could be significant.

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 and natural gas. Crude oil and natural gas 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.

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The longer-term trend in earnings for the upstream segment is also a function of other factors, including the company’s ability to find or acquire and efficiently produce crude oil and natural gas, changes in fiscal terms of contracts, the pace and extent of the energy transition, and changes in tax, environmental and other applicable laws and regulations.

In April 2024, Tengizchevroil LLP (TCO) achieved start-up of the Wellhead Pressure Management Project (WPMP) and as of September 2024, all four pressure boost facility compressors are online and 14 metering stations have been converted to low pressure. Additional metering station conversions will continue for the remainder of the year. TCO continues to make progress on the Future Growth Project with start-up expected in the first-half of 2025.

Chevron has interests in Venezuelan assets operated by independent affiliates. Chevron has been conducting limited activities in Venezuela consistent with the authorization provided pursuant to general licenses issued by the United States government. In fourth quarter 2022, Chevron received General License 41 from the United States government, enabling the company to resume activity in Venezuela subject to certain limitations, and the company continues such activities under this General License. The financial results for Chevron’s business in Venezuela are being recorded as non-equity investments since 2020, where income is only recognized when cash is received and production and reserves are not included in the company’s results. Crude oil liftings in Venezuela started in first quarter 2023, which has positively impacted the company’s results. The company’s independent affiliates have continued to maintain safe and reliable operations; however, future impact on results of operations and financial condition remain uncertain.

Governments 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. The financial impacts of such risks, including presently imposed sanctions, are not currently material for the company; however, it remains uncertain how long these conditions may last or how severe they may become.

Chevron holds a 39.7 percent interest in the Leviathan field and a 25 percent interest in the Tamar field in Israel. Despite the ongoing conflict between Israel and various regional adversaries, the company continues to maintain safe and reliable operations while meeting its contractual commitments. The project to install a third gathering pipeline at Leviathan is expected to be delayed; however, completion is currently still expected in 2025. The company continues to monitor the ongoing conflict in the region, and any future impacts on the company’s results of operations and financial condition remain uncertain.

Chevron operates and holds interests in the Bibiyana, Jalalabad and Moulavi Bazar fields in Bangladesh. Recent political unrest in the country has not impacted the company's operations to date; however, the future impacts, if any, on the company’s results of operations and financial condition remain uncertain.

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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 $83 per barrel for the first nine months of 2024, compared with $82 per barrel during the first nine months of 2023, and ended October at about $73 per barrel. The WTI price averaged $78 per barrel for the first nine months of 2024 compared to $77 per barrel in the first nine months of 2023, and ended October at about $69 per barrel. The majority of the company’s equity crude production is priced based on the Brent and WTI benchmarks. Crude prices decreased during third quarter 2024 due to concerns over lower global demand, despite increased geopolitical risk, declining inventory levels, and an interest rate cut by the U.S. Federal Reserve. (See page 38 for the company’s average U.S. and international crude oil sales prices.)

Price changes for natural gas are also impacted by seasonal supply, demand and infrastructure conditions in regional and local markets. In the U.S., prices at Henry Hub averaged $2.20 per thousand cubic feet (MCF) for the first nine months of 2024, compared with $2.49 per MCF during the first nine months of 2023. Prices in third quarter 2024 averaged $2.12 per MCF. Lower third quarter 2024 prices have started to incentivize production cuts, but storage levels remain above their five-year average. At the end of October 2024, the Henry Hub spot price was $1.94 per MCF.

Outside the U.S., price changes for natural gas also depend on a wide range of supply, demand and regulatory circumstances. The company’s long-term contract prices for liquefied 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 spot LNG market. The temporary pause on approving LNG export authorizations by the U.S. Department of Energy has not had a significant impact on current LNG prices. International natural gas realizations averaged $7.20 per MCF during the first nine months of 2024, compared with $7.81 per MCF in the same period last year. (See page 38 for the company’s average natural gas sales prices for the U.S. and international regions.)

Production The company’s worldwide net oil-equivalent production in the first nine months of 2024 averaged 3.33 million barrels per day, an increase of 10 percent from the first nine months of 2023 primarily due to the acquisition of PDC Energy, Inc. (PDC) and production growth in the Permian and Denver-Julesburg (DJ) Basin in the U.S., partly offset by planned downtime in Nigeria and exit from Myanmar. About 24 percent of the company’s net oil-equivalent production in the first nine months of 2024 occurred in the OPEC+ member countries of Angola, Equatorial Guinea, Kazakhstan, Nigeria, the Partitioned Zone between Saudi Arabia and Kuwait and the Republic of Congo.

Refer to the “Results of Operations” section on page 32 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, petrochemicals and renewable fuels, 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.

Chevron owns and operates a refinery in Richmond, California. A previous tax settlement between the City of Richmond and the company was replaced with a new agreement that is effective July 1, 2025. The company will pay $550 million to the City of Richmond over ten years as part of an agreement that also provides protections against future new tax liabilities during the ten-year agreement.

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California Assembly Bill ABX2-1, signed into law on October 14, 2024, authorizes the California Energy Commission (CEC) to develop and impose requirements to maintain minimum inventory levels of refined transportation fuels with respect to certain of the company’s downstream activities in California. The law further expands on CEC’s existing authority to impose requirements governing the timing of turnarounds and maintenance. It is uncertain whether, or when, the CEC will establish any such requirements. The company will evaluate the impact that ABX2-1 and any forthcoming CEC regulations may have on its operations in California and results of operations when the regulations have been promulgated.

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 33 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 26 of the company’s 2023 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:

•Australia - Completed major turnaround at Gorgon’s Train 2 plant ahead of schedule.

•Australia - Received an offshore greenhouse gas assessment permit, covering an area of approximately 8,467 km2, to assess future CO2 storage.

•Canada - Announced a $6.5 billion sale of the company’s interest in the Athabasca Oil Sands Project and Duvernay shale assets that is expected to close in fourth quarter 2024.

•India - Announced the establishment of an engineering and innovation center in India to provide technical and digital solutions for the enterprise.

•Kazakhstan - Completed major turnaround at TCO’s Complex Technology Line (KTL-1) ahead of schedule.

•Nigeria - Successfully extended the offshore Meji field with a near-field discovery.

•United States - Cleared Federal Trade Commission antitrust review of the company’s pending merger with Hess Corporation, satisfying a key closing condition for the transaction.

•United States - Started production at the Anchor project in the Gulf of Mexico, marking successful delivery of an industry-first high-pressure deepwater technology.

•United States - Began water injection operations to boost production from company operated Jack/St. Malo and Tahiti fields in the Gulf of Mexico.

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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)	2024		2023		2024		2023

U.S. Upstream
Earnings	$MM	$	1,946	$	2,074	$	6,182	$	5,495
Net Oil-Equivalent Production	MBOED	1,605		1,407		1,584		1,265
Liquids Production	MBD	1,156		1,028		1,139		941
Natural Gas Production	MMCFD	2,694		2,275		2,665		1,947
Liquids Realization	$/BBL	$	54.86	$	62.42	$	57.33	$	59.40
Natural Gas Realization	$/MCF	$	0.55	$	1.39	$	0.85	$	1.69

(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, 2024 and 2023

U.S. upstream earnings decreased by $128 million primarily due to lower realizations of $530 million, higher depreciation, depletion and amortization of $220 million, mainly from higher production, partly offset by higher sales volumes of $420 million and lower operating expenses of $110 million.

Net oil-equivalent production was up 198,000 barrels per day, or 14 percent, and set a new quarterly record. The increase was primarily due to record high production in the Permian Basin and the acquisition of PDC, partly offset by hurricane impacts in the U.S. Gulf of Mexico that reduced production by 17,000 barrels per day.

Nine Month Periods Ended September 30, 2024 and 2023

U.S. upstream earnings increased by $687 million primarily due to higher sales volumes of $2.2 billion, including from legacy PDC assets, partially offset by higher depreciation, depletion and amortization of $1.1 billion and lower realizations of $290 million.

Net oil-equivalent production was up 319,000 barrels per day, or 25 percent. The increase was primarily due to the acquisition of PDC and growth in the Permian and DJ Basins.


		Three Months Ended September 30				Nine Months Ended September 30
	Unit (2)	2024		2023		2024		2023
International Upstream
Earnings (1)	$MM	$	2,643	$	3,681	$	8,116	$	10,357
Net Oil-Equivalent Production	MBOED	1,759		1,739		1,750		1,763
Liquids Production	MBD	834		803		832		826
Natural Gas Production	MMCFD	5,550		5,616		5,513		5,621
Liquids Realization	$/BBL	$	70.59	$	75.64	$	72.70	$	70.78
Natural Gas Realization	$/MCF	$	7.46	$	6.96	$	7.20	$	7.81
(1) Includes foreign currency effects	$MM	$	13	$	584	$	(202)	$	538

(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, 2024 and 2023

International upstream earnings decreased by $1.0 billion primarily due to the absence of prior year one-time favorable tax benefit in Nigeria of $560 million. Foreign currency effects had an unfavorable impact on earnings of $571 million between periods.

Net oil-equivalent production was up 20,000 barrels per day, or 1 percent. The increase was primarily due to entitlement effects.

Nine Month Periods Ended September 30, 2024 and 2023

International upstream earnings decreased by $2.2 billion primarily due to an unfavorable swing in tax effects of $800 million, lower sales volumes of $560 million and lower realizations of $270 million. Foreign currency effects had an unfavorable impact on earnings of $740 million between periods.

Net oil-equivalent production was down 13,000 barrels per day, or 1 percent. The decrease was primarily due to downtime in Nigeria and Australia, and exit from Myanmar, partly offset by entitlement effects.

Downstream


		Three Months Ended September 30				Nine Months Ended September 30
	Unit *	2024		2023		2024		2023
U.S. Downstream
Earnings	$MM	$	146	$	1,376	$	879	$	3,434
Refinery Crude Unit Inputs	MBD	995		980		925		965
Refined Product Sales	MBD	1,312		1,303		1,296		1,283
* MBD — thousands of barrels per day.

Three Month Periods Ended September 30, 2024 and 2023

U.S. downstream earnings decreased by $1.2 billion primarily due to lower margins on refined product sales of $1.3 billion, partly offset by $180 million of higher earnings from the 50 percent-owned affiliate, CPChem.

Refinery crude unit inputs, including crude oil and other inputs, were up 15,000 barrels per day, or 2 percent, primarily due to absence of planned turnaround at the Richmond, California refinery, partly offset by hurricane impacts at the Pasadena, Texas refinery.

Refined product sales were up 9,000 barrels per day, or 1 percent.

Nine Month Periods Ended September 30, 2024 and 2023

U.S. downstream earnings decreased by $2.6 billion primarily due to lower margins on refined product sales of $2.3 billion and higher operating expenses of $490 million, partly offset by $200 million of higher earnings from CPChem.

Refinery crude unit inputs, including crude oil and other inputs, were down 40,000 barrels per day, or 4 percent, primarily due to downtime at the El Segundo, California and Pascagoula, Mississippi refineries, and hurricane impacts at the Pasadena, Texas refinery.

Refined product sales were up 13,000 barrels per day, or 1 percent.

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		Three Months Ended September 30				Nine Months Ended September 30
	Unit (2)	2024		2023		2024		2023
International Downstream
Earnings (1)	$MM	$	449	$	307	$	1,096	$	1,556
Refinery Crude Unit Inputs	MBD	628		637		643		637
Refined Product Sales	MBD	1,507		1,431		1,473		1,448
(1) Includes foreign currency effects	$MM	$	(55)	$	24	$	—	$	46
(2) MBD — thousands of barrels per day.

Three Month Periods Ended September 30, 2024 and 2023

International downstream earnings increased by $142 million primarily due to higher margins on refined product sales of $310 million, partly offset by higher operating expenses of $90 million. Foreign currency effects had an unfavorable impact on earnings of $79 million between periods.

Refinery crude unit inputs, including crude oil and other inputs, were down 9,000 barrels per day, or 1 percent, primarily due to higher planned turnarounds.

Refined product sales were up 76,000 barrels per day, or 5 percent, compared to the year-ago period primarily due to higher demand for gasoline and jet fuel.

Nine Month Periods Ended September 30, 2024 and 2023

International downstream earnings decreased by $460 million primarily due to lower margins on refined product sales of $300 million and higher operating expenses of $60 million. Foreign currency effects had an unfavorable impact on earnings of $46 million between periods.

Refinery crude unit inputs, including crude oil and other inputs, were up 6,000 barrels per day, or 1 percent.

Refined product sales were up 25,000 barrels per day, or 2 percent.

All Other


		Three Months Ended September 30				Nine Months Ended September 30
	Unit	2024		2023		2024		2023
All Other
Earnings/(Charges)*	$MM	$	(697)	$	(912)	$	(1,851)	$	(1,732)

* Includes foreign currency effects		$	(2)	$	(323)	$	—	$	(329)

Three Month Periods Ended September 30, 2024 and 2023

Net charges decreased by $215 million primarily due to the absence of prior year unfavorable foreign currency effects, partly offset by higher interest expense and lower interest income.

Nine Month Periods Ended September 30, 2024 and 2023

Net charges increased by $119 million primarily due to lower interest income and unfavorable tax items, partly offset by the absence of prior year unfavorable foreign currency effects.

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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
	2024		2023		2024		2023
	(Millions of dollars)
Sales and other operating revenues	$	48,926	$	51,922	$	145,080	$	147,980

Sales and other operating revenues for third quarter 2024 decreased mainly due to lower refined product and crude oil prices, partially offset by higher crude oil and refined product sales volumes. Sales and other operating revenues for the nine-month period 2024 also decreased as lower refined product and natural gas prices were partially offset by higher U.S. crude oil, natural gas and refined product sales volumes.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Income from equity affiliates	$	1,261	$	1,313	$	3,908	$	4,141

Income from equity affiliates in third quarter 2024 decreased mainly due to lower downstream-related earnings from GS Caltex in South Korea and upstream-related earnings from TCO, partially offset by higher downstream-related earnings from CPChem. Income from equity affiliates in the nine-month period 2024 decreased mainly due to lower downstream-related earnings from GS Caltex in South Korea and upstream-related earnings from Angola LNG, partially offset by higher downstream-related earnings from CPChem.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Other income (loss)	$	482	$	845	$	1,578	$	1,648

Other income for third quarter 2024 decreased primarily due to an unfavorable swing in foreign currency effects, partially offset by higher income from Venezuela non-equity investments. Other income for the nine-month period 2024 decreased mainly due to lower interest income and an unfavorable swing in foreign currency effects, partially offset by higher income from Venezuela non-equity investments.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Purchased crude oil and products	$	30,450	$	32,328	$	89,058	$	90,719

Purchased crude oil and products decreased for third quarter 2024 primarily due to lower refined product and crude oil prices. Purchased crude oil and products decreased for the nine-month period 2024 as lower refined product prices and lower crude oil purchase volume were partially offset by higher refined product purchases.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Operating, selling, general and administrative expenses	$	7,886	$	7,462	$	23,091	$	21,549

Operating, selling, general and administrative expenses in third quarter 2024 increased mainly due to higher environmental reserve and transportation costs. The increase in Operating, selling, general and administrative expenses for the nine-month period 2024 primarily resulted from higher employee expenses, higher transportation costs and higher material and supply expenses.

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	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Exploration expenses	$	154	$	301	$	546	$	660

Exploration expenses for the third quarter and nine-month period 2024 decreased primarily due to lower charges for well write-offs.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Depreciation, depletion and amortization	$	4,214	$	4,025	$	12,309	$	11,072

Depreciation, depletion and amortization expenses for the third quarter and nine-month period 2024 increased primarily due to higher production volumes and higher rates.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Taxes other than on income	$	1,263	$	1,021	$	3,575	$	3,158

Taxes other than on income for the third quarter and nine-month period 2024 increased primarily due to higher property and excise taxes.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Interest and debt expense	$	164	$	114	$	395	$	349

Interest and debt expenses for the third quarter and nine-month period 2024 increased mainly due to higher debt balance compared to last year.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Other components of net periodic benefit costs	$	49	$	91	$	145	$	168

Other components of net periodic benefit costs for the third quarter and nine-month period 2024 were lower mainly due to the absence of third quarter 2023 pension settlement charges.


	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
	(Millions of dollars)
Income tax expense/(benefit)	$	1,993	$	2,183	$	6,957	$	6,926

The company’s decrease in income tax expense for third quarter 2024 of $190 million was primarily due to the decrease in total income before tax of $2.2 billion, partially offset by the absence of prior period favorable tax items.

U.S. income before tax decreased from $3.5 billion in third quarter 2023 to $1.8 billion in third quarter 2024. This $1.6 billion decrease in income was primarily driven by lower downstream margins, lower upstream realizations, partially offset by higher upstream sales volumes. 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 $498 million between year-over-year periods, from $1.0 billion in 2023 to $460 million in 2024.

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International income before tax decreased from $5.3 billion in third quarter 2023 to $4.7 billion in third quarter 2024. This $616 million decrease in income was primarily driven by unfavorable foreign currency effects and higher operating expenses, partially offset by higher downstream margins. The company’s international income tax expense increased $308 million between year-over-year periods, from $1.2 billion in 2023 to $1.5 billion in 2024, primarily due to the absence of prior period favorable tax items.

The company’s income tax expense increased in the first nine months of 2024 by $31 million while total income before income tax decreased $4.6 billion, primarily due to the absence of prior period favorable tax items and current period unfavorable tax items.

U.S. income before income tax decreased between the nine-month periods, from $9.4 billion in 2023 to $6.9 billion in 2024. This $2.5 billion decrease in income was primarily driven by lower downstream margins, higher depreciation, depletion and amortization, and higher operating expenses, partially offset by higher upstream sales volumes. 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 $575 million between the nine-month periods, from $2.3 billion in 2023 to $1.8 billion in 2024.

International income before income tax decreased for the nine-month period, from $16.7 billion in 2023 to $14.5 billion in 2024. This $2.1 billion decrease in income was primarily due to lower upstream sales volumes, unfavorable foreign currency effects, higher operating expenses, lower downstream margins and lower upstream realizations. International income tax expense increased $606 million between year-over-year periods, from $4.6 billion in 2023 to to $5.2 billion in 2024, primarily due to the absence of prior period favorable tax items and current period unfavorable tax items.

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	2024		2023		2024		2023
U.S. Upstream
Net crude oil and natural gas liquids production	MBD	1,156		1,028		1,139		941
Net natural gas production(3)	MMCFD	2,694		2,275		2,665		1,947
Net oil-equivalent production	MBOED	1,605		1,407		1,584		1,265
Sales of natural gas	MMCFD	5,378		4,942		5,253		4,526
Sales of natural gas liquids	MBD	481		380		460		326
Revenue from net production
Crude	$/BBL	$	73.04	$	80.40	$	75.30	$	74.56
NGLs	$/BBL	$	18.34	$	20.15	$	19.33	$	20.63
Liquids (weighted average of Crude and NGLs)	$/BBL	$	54.86	$	62.42	$	57.33	$	59.40
Natural gas	$/MCF	$	0.55	$	1.39	$	0.85	$	1.69
International Upstream
Net crude oil and natural gas liquids production(4)	MBD	834		803		832		826
Net natural gas production(3)	MMCFD	5,550		5,616		5,513		5,621
Net oil-equivalent production(4)	MBOED	1,759		1,739		1,750		1,763
Sales of natural gas	MMCFD	5,576		5,600		5,579		5,686
Sales of natural gas liquids	MBD	147		88		132		87
Revenue from liftings
Crude	$/BBL	$	72.82	$	78.67	$	75.09	$	73.18
NGLs	$/BBL	$	27.44	$	20.68	$	23.95	$	23.59
Liquids (weighted average of Crude and NGLs)	$/BBL	$	70.59	$	75.64	$	72.70	$	70.78
Natural gas	$/MCF	$	7.46	$	6.96	$	7.20	$	7.81
U.S. and International Upstream
Total net oil-equivalent production(4)	MBOED	3,364		3,146		3,334		3,028
U.S. Downstream
Gasoline sales(5)	MBD	684		652		666		644
Other refined product sales	MBD	628		651		630		639
Total refined product sales	MBD	1,312		1,303		1,296		1,283
Sales of natural gas	MMCFD	37		32		31		32
Sales of natural gas liquids	MBD	21		23		22		21
Refinery crude unit inputs	MBD	995		980		925		965
International Downstream
Gasoline sales(5)	MBD	335		275		335		298
Other refined product sales	MBD	782		756		747		767
Share of affiliate sales	MBD	390		400		391		383
Total refined product sales	MBD	1,507		1,431		1,473		1,448
Sales of natural gas	MMCFD	—		—		—		1
Sales of natural gas liquids	MBD	152		174		136		163
Refinery crude unit inputs	MBD	628		637		643		637
(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); 3Q23 recast to include additional own use volumes from PDC acquisition:
United States		66		70		61		57
International		551		529		542		530
(4) Includes net production of synthetic oil:
Canada		48		52		49		50

(5) Includes branded and unbranded gasoline.

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Liquidity and Capital Resources

Cash, cash equivalents and marketable securities totaled $4.7 billion at September 30, 2024, and $8.2 billion at year-end 2023. 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 2024 was $22.8 billion, compared with $23.2 billion in the year-ago period. Capital expenditures totaled $12.1 billion in the first nine months of 2024, up $642 million from the year-ago period largely due to higher investments in upstream, including post-acquisition spend on legacy PDC assets. Proceeds and deposits related to asset sales and returns of investment totaled $620 million in the first nine months of 2024, compared to $410 million in the year-ago period. Cash provided by financing activities includes proceeds from shares issued for stock option exercises of $194 million in the first nine months of 2024, compared with $237 million in the year-ago period.

Dividends The company paid dividends of $8.9 billion to common stockholders during the first nine months of 2024. In October 2024, the company declared a quarterly dividend of $1.63 per common share, payable in December 2024.

Debt and Finance Lease Liabilities Chevron’s total debt and finance lease liabilities were $25.8 billion at September 30, 2024, up from $20.8 billion at December 31, 2023, as the company issued commercial paper and tax-exempt bonds, and retired a bond that matured during the period.

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, 2024, was $6.0 billion, and there was no commercial paper outstanding at December 31, 2023. 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 $13.2 billion at September 30, 2024, and $5.1 billion at December 31, 2023. Of these amounts, $8.1 billion was reclassified to long-term at September 30, 2024, and $4.5 billion was reclassified to long-term at December 31, 2023. At September 30, 2024, 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, 2024, the company had $8.1 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, 2024.

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. and Noble Energy, Inc. Most of these securities are the obligations of, or guaranteed by, Chevron Corporation and are rated AA- by Standard and Poor’s Corporation (S&P) and Aa2 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.

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, 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.

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Summarized Financial Information for Guarantee of Securities of Subsidiaries CUSA issued bonds that are fully and unconditionally guaranteed on an unsecured basis by Chevron Corporation (together, the “Obligor Group”). The tables below contain summary financial information for Chevron Corporation, as Guarantor, excluding its consolidated subsidiaries, and CUSA, as the issuer, excluding its consolidated subsidiaries. The summary financial information of the Obligor Group is presented on a combined basis, and transactions between the combined entities have been eliminated. Financial information for non-guarantor entities has been excluded. In the nine months ended September 30, 2024, the Obligor Group recognized an increase in “Net income (loss)” and reduction in “Current liability- related party” and “Total net equity (deficit)” following the resolution of outstanding balances with subsidiaries outside of the Obligor Group.


	Nine Months Ended September 30, 2024		Year Ended December 31, 2023
	(Millions of dollars) (unaudited)
Sales and other operating revenues	$	72,362	$	100,405
Sales and other operating revenues - related party	32,438		44,553
Total costs and other deductions	74,815		102,773
Total costs and other deductions - related party	26,610		35,781
Net income (loss)	$	45,620	$	12,190


	At September 30, 2024		At December 31, 2023
	(Millions of dollars) (unaudited)
Current assets	$	16,467	$	19,006
Current assets - related party	1,735		18,375
Other assets	57,991		54,558
Current liabilities	29,269		20,512
Current liabilities - related party	40,997		132,474
Other liabilities	24,512		28,849
Total net equity (deficit)	$	(18,585)	$	(89,896)

Common Stock Repurchase Program On January 25, 2023, the Board of Directors authorized the repurchase of the company’s shares of common stock in an aggregate amount of $75 billion (the “2023 Program”). The 2023 Program took effect on April 1, 2023, and does not have a fixed expiration date. In the aggregate, the company has repurchased 141.4 million shares for $21.9 billion under the 2023 Program, including 32.2 million shares repurchased for $4.7 billion in third quarter 2024. Chevron expects share repurchases in the fourth quarter 2024 to be between $4.0-$4.75 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.

Noncontrolling Interests The company had noncontrolling interests of $828 million at September 30, 2024, and $972 million at December 31, 2023. Included within noncontrolling interests is $166 million at December 31, 2023, of redeemable noncontrolling interest.

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Financial Ratios and Metrics


	At September 30, 2024		At December 31, 2023
Current Ratio (1)	1.1		1.3
Debt Ratio	14.2	%	11.5	%
Net Debt Ratio (2)	11.9	%	7.3	%

(1) At September 30, 2024, the book value of inventory was lower than replacement cost.

(2) Net Debt Ratio for September 30, 2024 is calculated as short-term debt of $5.1 billion plus long-term debt of $20.7 billion (together, “total debt”) less cash and cash equivalents, time deposits and marketable securities of $4.7 billion as a percentage of total debt less cash and cash equivalents, time deposits and marketable securities, plus Chevron Corporation Stockholders’ Equity of $156.2 billion. For the December 31, 2023 calculation, please refer to page 51 of Chevron’s 2023 Annual Report on Form 10-K.


	Nine Months Ended September 30
		2024		2023
	(Millions of dollars)
Net cash provided by operating activities		$	22,797	$	23,175
Less: Capital expenditures		(12,110)		(11,468)
Free Cash Flow		$	10,687	$	11,707

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. Third quarter 2024 capex was $618 million lower than third quarter 2023 largely due to the absence of the acquisition of a majority stake in ACES Delta, LLC and year-to-date 2024 capex was $642 million higher than the year-ago period due to higher investments in upstream, including post-acquisition spend on legacy PDC assets.

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 2024 affiliate capex was $274 million lower than third quarter 2023 and year-to-date 2024 affiliate capex was $870 million lower than the year-ago period.


Capex and Affiliate Capex by Business Segment
	Three Months Ended September 30				Nine Months Ended September 30
	2024		2023		2024		2023
Capex	(Millions of dollars)
United States
Upstream	$	2,349	$	3,020	$	7,126	$	7,234
Downstream	349		408		1,116		1,118
All Other	93		97		274		218
Total United States	2,791		3,525		8,516		8,570
International
Upstream	1,212		1,080		3,462		2,742
Downstream	47		66		124		144
All Other	5		2		8		12
Total International	1,264		1,148		3,594		2,898
Capex	$	4,055	$	4,673	$	12,110	$	11,468
Affiliate Capex
Upstream	$	329	$	539	$	1,110	$	1,793
Downstream	236		300		704		891
Affiliate Capex	$	565	$	839	$	1,814	$	2,684

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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.”

Indemnifications Information related to indemnifications is included in Note 12 Other Contingencies and Commitments under the heading “Indemnifications.”

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 heading “Acquisition and Disposition of Assets.”

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, 2024, does not differ materially from that discussed under Item 7A of Chevron’s 2023 Annual Report on Form 10-K.

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, 2024.

(b) Changes in internal control over financial reporting

During the quarter ended September 30, 2024, there were no changes in the company’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the company’s internal control over financial reporting.

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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 proceedings include those matters relating to third quarter 2024 and any material developments with respect to matters previously reported in Chevron’s 2023 Annual Report on Form 10-K.

As previously disclosed, in April 2015, Noble Energy, Inc. (Noble) entered into a joint consent decree (Consent Decree) with the United States Department of Justice (DOJ), the United States Environmental Protection Agency (EPA) and the State of Colorado to improve emission control systems at a number of condensate storage tanks within the Denver-Julesburg (DJ) Basin. While the associated civil penalty was paid by Noble previously, the Consent Decree provides for stipulated penalties for noncompliance with the Consent Decree. The DOJ, EPA and the State of Colorado have requested payment of $1.5 million in stipulated penalties accrued under the Consent Decree, which was paid in August 2024.

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, 2024, does not differ materially from that set forth under the heading “Risk Factors” on pages 20 through 26 of the company’s 2023 Annual Report on Form 10-K, other than as reflected in the risk factor below.

Chevron may not complete the acquisition of Hess Corporation within the time frame the company anticipates or at all, which could have adverse effects on Chevron The completion of the acquisition of Hess Corporation (Hess) is subject to a number of conditions, including the expiration or termination of any waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended (HSR Act) and approval of any Guyanese governmental body, agency or authority that asserts its approval is required in connection with the transaction, each of which make the completion and timing of the completion of the merger uncertain.

Hess Guyana Exploration Limited (HGEL), a wholly owned subsidiary of Hess, is currently in arbitration with respect to the right of first refusal (Stabroek ROFR) contained in an operating agreement among HGEL, affiliates of Exxon Mobil Corporation (Exxon), and China National Offshore Oil Corporation (CNOOC) regarding the Stabroek Block offshore Guyana. The arbitration merits hearing about the applicability of the Stabroek ROFR to the merger has been scheduled for May 2025, with a decision expected in the following three months. If the arbitration does not result in a confirmation that the Stabroek ROFR is inapplicable to the merger, and if Chevron, Hess, Exxon and/or CNOOC do not otherwise agree upon an acceptable resolution, then there would be a failure of a closing condition under the merger agreement, in which case the merger would not close.

On December 7, 2023, Chevron and Hess each received a request for additional information and documentary materials (Second Request) from the Federal Trade Commission (FTC). Following the FTC review of the transaction, on September 30, 2024, the FTC announced that a majority of the Commission voted to accept a consent agreement among the FTC, Chevron and Hess, resolving the concerns the FTC identified during its review of the transaction. Chevron and Hess have taken and will continue to take appropriate steps to maintain our ability under the Hart-Scott-Rodino Act of 1976, as amended (HSR Act) to close the merger following satisfactory resolution of the ongoing arbitration proceedings regarding preemptive rights in the Stabroek Block joint operating agreement, including filing additional notifications under the HSR Act. Additionally, if any Guyanese governmental body, agency or authority of competent jurisdiction asserts that

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its approval is required as a result of the consequences of the merger in Guyana on Hess’ assets in Guyana (which has not occurred as of the filing date of this report), approval of such governmental body, agency or authority will become a condition to each party’s obligation to complete the merger.

The failure to satisfy all of the required conditions could delay the completion of the acquisition for a significant period of time or prevent it from occurring at all. In addition, the terms and conditions of the required regulatory authorizations and consents for the acquisition that are granted, if any, may impose requirements, limitations or costs or place restrictions on the conduct of the company’s business after the transaction or materially delay the completion of the acquisition. A delay in completing the acquisition could cause the company to realize some or all of the benefits later than we otherwise expect to realize them if the acquisition is successfully completed within the anticipated timeframe, which could result in additional transaction costs or in other negative effects associated with uncertainty about completion of the acquisition.

Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

CHEVRON CORPORATION

ISSUER PURCHASES OF EQUITY SECURITIES


Period	Total Number of Shares Purchased (*)	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 (*) (Billions of dollars)
July 1 - July 31, 2024	7,923,000	$156.56	7,923,000	$56.6
August 1 - August 31, 2024	12,057,000	$146.20	12,057,000	$54.8
September 1 - September 30, 2024	12,229,398	$142.84	12,229,398	$53.1
Total	32,209,398	$147.47	32,209,398

(*) 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

A. Nigel Hearne, Executive Vice President, Senior Advisor, entered into a pre-arranged stock trading plan on August 19, 2024. Mr. Hearne’s plan provides for the potential exercise of vested stock options and the associated sale of up to 60,468 shares of Chevron common stock between November 18, 2024, and February 28, 2025.

The trading plan was entered into during an open insider trading window and is intended to satisfy the affirmative defense of Rule 10b5-1(c) under the Securities Exchange Act of 1934, as amended, and Chevron’s policies regarding transactions in Chevron securities.

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Item 6.Exhibits


Exhibit Index
Exhibit Number						Description

10.1+*						Chevron Incentive Plan, amended and restated effective October 2, 2023 (refi l ed to correct formatting in the previo usly filed version).
10.2+*						Chevron Corporation Retirement Restoration Plan, amended and restated effective August 1, 2024.
10.3+*						Chevron Corporation ESIP Restoration Plan, amended and restated effective August 1, 2024.
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.


			CHEVRON CORPORATION (REGISTRANT)


			/S/ ALANA K. KNOWLES
			Alana K. Knowles, Vice President and Controller (Principal Accounting Officer and Duly Authorized Officer)

Date: November 7, 2024