Form 10-Q - Quarterly report [Sections 13 or 15(d)]

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Name	Symbol	Market	Type
California Resources Corporation (PK)	USOTC:CRCQW	OTCMarkets	Equity Warrant

	Price Change	% Change	Price	Bid Price	Offer Price	High Price	Low Price	Open Price	Traded	Last Trade
	0.00	0.00%	17.12	13.32	22.00				0.00	00:00:00

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 March 31, 2024

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___________ to ___________

Commission file number 001-36478

California Resources Corporation

(Exact name of registrant as specified in its charter)


Delaware						46-5670947
(State or other jurisdiction of incorporation or organization)						(I.R.S. Employer Identification No.)

1 World Trade Center, Suite 1500

Long Beach, California 90831

(Address of principal executive offices) (Zip Code)

(888) 848-4754

(Registrant’s telephone number, including area code)

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


Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
Common Stock	CRC	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

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court. ☑ Yes ☐ No

Indicate the number of shares outstanding for each of the issuer's classes of common stock, as of the latest practicable date.

The number of shares of common stock outstanding as of March 31, 2024 was 68,530,744.

California Resources Corporation and Subsidiaries

Table of Contents


	Page
Part I
Item 1	Financial Statements (unaudited)	4
	Condensed Consolidated Balance Sheets	4
	Condensed Consolidated Statements of Operations	5
	Condensed Consolidated Statements of Comprehensive (Loss) Income	6
	Condensed Consolidated Statements of Stockholders' Equity	7
	Condensed Consolidated Statements of Cash Flows	8
	Notes to the Condensed Consolidated Financial Statements	9
Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
	General	25
	Pending Aera Merger	25
	Business Environment and Industry Outlook	26
	Regulatory Updates	26
	Results of Oil and Gas Operations	27
	Statements of Operations Analysis	30
	Liquidity and Capital Resources	33
	Divestitures and Acquisitions	36
	Lawsuits, Claims, Commitments and Contingencies	37
	Critical Accounting Estimates and Significant Accounting and Disclosure Changes	37
	Forward-Looking Statements	38
Item 3	Quantitative and Qualitative Disclosures About Market Risk	40
Item 4	Controls and Procedures	40

Part II
Item 1	Legal Proceedings	41
Item 1A	Risk Factors	41
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	41
Item 5	Other Disclosures	41
Item 6	Exhibits	42

GLOSSARY AND SELECTED ABBREVIATIONS

The following are abbreviations and definitions of certain terms used within this Form 10-Q:

•ABR - Alternate base rate.

•ASC - Accounting Standards Codification.

•ARO - Asset retirement obligation.

•Bbl - Barrel.

•Bbl/d - Barrels per day.

•Bcf - Billion cubic feet.

•Bcfe - Billion cubic feet of natural gas equivalent using the ratio of one barrel of oil, condensate, or NGLs converted to six thousand cubic feet of natural gas.

•Boe - We convert natural gas volumes to crude oil equivalents using a ratio of six thousand cubic feet (Mcf) to one barrel of crude oil equivalent based on energy content. This is a widely used conversion method in the oil and natural gas industry.

•Boe/d - Barrel of oil equivalent per day.

•Btu - British thermal unit.

•CalGEM - California Geologic Energy Management Division.

•CCS - Carbon capture and storage.

•CDMA - Carbon Dioxide Management Agreement.

•CEQA - California Environmental Quality Act.

•CO2 - Carbon dioxide.

•DAC - Direct air capture.

•DD&A - Depletion, depreciation, and amortization.

•EOR - Enhanced oil recovery.

•EPA - United States Environmental Protection Agency.

•ESG - Environmental, social and governance.

•E&P - Exploration and production.

•Full-Scope Net Zero - Achieving permanent storage of captured or removed carbon emissions in a volume equal to all of our scope 1, 2 and 3 emissions by 2045.

•GAAP - United States Generally Accepted Accounting Principles.

•G&A - General and administrative expenses.

•GHG - Greenhouse gases.

•JV - Joint venture.

•LCFS - Low Carbon Fuel Standard.

•LIBOR - London Interbank Offered Rate.

•MBbl - One thousand barrels of crude oil, condensate or NGLs.

•MBbl/d - One thousand barrels per day.

•MBoe/d - One thousand barrels of oil equivalent per day.

•MBw/d - One thousand barrels of water per day

•Mcf - One thousand cubic feet of natural gas equivalent, with liquids converted to an equivalent volume of natural gas using the ratio of one barrel of oil to six thousand cubic feet of natural gas.

•MHp - One thousand horsepower.

•MMBbl - One million barrels of crude oil, condensate or NGLs.

•MMBoe - One million barrels of oil equivalent.

•MMBtu - One million British thermal units.

•MMcf/d - One million cubic feet of natural gas per day.

•MMT - Million metric tons.

•MMTPA - Million metric tons per annum.

•MW - Megawatts of power.

•NGLs - Natural gas liquids. Hydrocarbons found in natural gas that may be extracted as purity products such as ethane, propane, isobutane and normal butane, and natural gasoline.

•NYMEX - The New York Mercantile Exchange.

•OCTG - Oil country tubular goods.

•Oil spill prevention rate - Calculated as total Boe less net barrels lost divided by total Boe.

•OPEC - Organization of the Petroleum Exporting Countries.

•OPEC+ - OPEC together with Russia and certain other producing countries.

•PHMSA - Pipeline and Hazardous Materials Safety Administration.

•Proved developed reserves - Reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.

•Proved reserves - The estimated quantities of natural gas, NGLs, and oil that geological and engineering data demonstrate with reasonable certainty to be commercially recoverable in future years from known reservoirs under existing economic conditions, operating methods and government regulations.

•Proved undeveloped reserves - Proved reserves that are expected to be recovered from new wells on undrilled acreage that are reasonably certain of production when drilled or from existing wells where a relatively major expenditure is required for recompletion.

•PSCs - Production-sharing contracts.

•PV-10 - Non-GAAP financial measure and represents the year-end present value of estimated future cash flows from proved oil and natural gas reserves, less future development and operating costs, discounted at 10% per annum and using SEC Prices. PV-10 facilitates the comparisons to other companies as it is not dependent on the tax-paying status of the entity.

•Scope 1 emissions - Our direct emissions.

•Scope 2 emissions - Indirect emissions from energy that we use (e.g., electricity, heat, steam, cooling) that is produced by others.

•Scope 3 emissions - Indirect emissions from upstream and downstream processing and use of our products.

•SDWA - Safe Drinking Water Act.

•SEC - United States Securities and Exchange Commission.

•SEC Prices - The unweighted arithmetic average of the first day-of-the-month price for each month within the year used to determine estimated volumes and cash flows for our proved reserves.

•SOFR - Secured overnight financing rate as administered by the Federal Reserve Bank of New York.

•Standardized measure - The year-end present value of after-tax estimated future cash flows from proved oil and natural gas reserves, less future development and operating costs, discounted at 10% per annum and using SEC Prices. Standardized measure is prescribed by the SEC as an industry standard asset value measure to compare reserves with consistent pricing, costs and discount assumptions.

•TRIR - Total Recordable Incident Rate calculated as recordable incidents per 200,000 hours for all workers (employees and contractors).

•Working interest - The right granted to a lessee of a property to explore for and to produce and own oil, natural gas or other minerals in-place. A working interest owner bears the cost of development and operations of the property.

•WTI - West Texas Intermediate.

PART I FINANCIAL INFORMATION

Item 1Financial Statements (unaudited)

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Condensed Consolidated Balance Sheets

As of March 31, 2024 and December 31, 2023

(in millions, except share data)


	March 31,		December 31,
	2024		2023
CURRENT ASSETS
Cash and cash equivalents	$	403	$	496
Trade receivables	192		216
Inventories	70		72
Assets held for sale	13		13
Receivable from affiliate	66		19
Other current assets, net	95		113
Total current assets	839		929
PROPERTY, PLANT AND EQUIPMENT	3,514		3,437
Accumulated depreciation, depletion and amortization	(721)		(667)
Total property, plant and equipment, net	2,793		2,770
INVESTMENT IN UNCONSOLIDATED SUBSIDIARY	16		19
DEFERRED INCOME TAXES	139		132
OTHER NONCURRENT ASSETS	123		148
TOTAL ASSETS	$	3,910	$	3,998


CURRENT LIABILITIES



Accounts payable	251		245
Liabilities associated with assets held for sale	5		5

Accrued liabilities	338		366

Total current liabilities	594		616
NONCURRENT LIABILITIES
Long-term debt, net	541		540

Asset retirement obligations	429		422
Other long-term liabilities	253		201



STOCKHOLDERS' EQUITY
Preferred stock (20,000,000 shares authorized at $0.01 par value) no shares outstanding at March 31, 2024 and December 31, 2023	—		—
Common stock (200,000,000 shares authorized at $0.01 par value) (84,460,423 and 83,557,800 shares issued; 68,530,744 and 68,693,885 shares outstanding at March 31, 2024 and December 31, 2023)	1		1
Treasury stock (15,929,679 shares held at cost at March 31, 2024 and 14,863,915 shares held at cost at December 31, 2023)	(662)		(604)
Additional paid-in capital	1,295		1,329
Retained earnings	1,387		1,419
Accumulated other comprehensive income	72		74


Total stockholders' equity	2,093		2,219
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	3,910	$	3,998

The accompanying notes are an integral part of these condensed consolidated financial statements.

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Condensed Consolidated Statements of Operations

For the three months ended March 31, 2024 and 2023

(dollars in millions, except share and per share data; shares in millions)


	Three months ended March 31,
	2024		2023
REVENUES
Oil, natural gas and NGL sales	$	429	$	715
Net (loss) gain from commodity derivatives	(71)		42
Revenue from marketing of purchased commodities	74		187
Electricity sales	15		68
Interest and other revenue	7		12
Total operating revenues	454		1,024

OPERATING EXPENSES
Operating costs	176		254
General and administrative expenses	57		65
Depreciation, depletion and amortization	53		58
Asset impairment	—		3
Taxes other than on income	38		42
Exploration expense	1		1
Costs related to marketing of purchased commodities	54		124
Electricity generation expenses	8		49
Transportation costs	20		17
Accretion expense	12		12
Carbon management business expenses	8		5
Other operating expenses, net	37		8
Total operating expenses	464		638
Gain on asset divestitures	6		7

OPERATING (LOSS) INCOME	(4)		393

NON-OPERATING (EXPENSES) INCOME

Interest and debt expense	(13)		(14)

Loss from investment in unconsolidated subsidiary	(3)		(2)
Other non-operating income (loss)	1		(1)
(LOSS) INCOME BEFORE INCOME TAXES	(19)		376
Income tax benefit (provision)	9		(75)
NET (LOSS) INCOME	$	(10)	$	301






Net (loss) income per share
Basic	$	(0.14)	$	4.22
Diluted	$	(0.14)	$	4.09

Weighted-average common shares outstanding
Basic	69.0		71.3
Diluted	69.0		73.5

The accompanying notes are an integral part of these condensed consolidated financial statements.

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Condensed Consolidated Statements of Comprehensive (Loss) Income

For the three months ended March 31, 2024 and 2023

(in millions)


	Three months ended March 31,
	2024		2023
Net (loss) income	$	(10)	$	301
Other comprehensive income:
Amortization of prior service cost credit included in net periodic benefit cost, net of tax(a)	(2)		—
Comprehensive (loss) income attributable to common stock	$	(12)	$	301

(a) Tax effects of the amortization of prior service cost credit were insignificant for the three months ended March 31, 2024.

The accompanying notes are an integral part of these condensed consolidated financial statements.

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Condensed Consolidated Statements of Stockholders' Equity

For the three months ended March 31, 2024 and 2023

(in millions)


	Three months ended March 31, 2024
	Common Stock		Treasury Stock		Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total Equity
Balance, December 31, 2023	$	1	$	(604)	$	1,329	$	1,419	$	74	$	2,219
Net loss	—		—		—		(10)		—		(10)

Share-based compensation	—		—		7		—		—		7



Repurchases of common stock	—		(58)		—		—		—		(58)

Cash dividend ($0.31 per share)	—		—		—		(22)		—		(22)
Shares cancelled for taxes	—		—		(41)		—		—		(41)
Other comprehensive income, net of tax	—		—		—		—		(2)		(2)
Balance, March 31, 2024	$	1	$	(662)	$	1,295	$	1,387	$	72	$	2,093


	Three months ended March 31, 2023
	Common Stock		Treasury Stock		Additional Paid-in Capital		Retained Earnings		Accumulated Other Comprehensive Income		Total Equity
Balance, December 31, 2022	$	1	$	(461)	$	1,305	$	938	$	81	$	1,864
Net income	—		—		—		301		—		301

Share-based compensation	—		—		7		—		—		7



Repurchases of common stock	—		(59)		—		—		—		(59)

Cash dividend ($0.2825 per share)	—		—		—		(20)		—		(20)
Shares cancelled for taxes	—		—		(1)		—		—		(1)

Balance, March 31, 2023	$	1	$	(520)	$	1,311	$	1,219	$	81	$	2,092

The accompanying notes are an integral part of these condensed consolidated financial statements.

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Condensed Consolidated Statements of Cash Flows

For the three months ended March 31, 2024 and 2023

(in millions)


	Three months ended March 31,
	2024		2023
CASH FLOW FROM OPERATING ACTIVITIES
Net (loss) income	$	(10)	$	301
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	53		58
Deferred income tax (benefit) provision	(9)		47
Asset impairment	—		3
Net loss (gain) from commodity derivatives	72		(42)
Net payments on settled commodity derivatives	(14)		(65)


Gain on asset divestitures	(6)		(7)



Other non-cash charges to income, net	6		21
Changes in operating assets and liabilities, net	(5)		(6)
Net cash provided by operating activities	87		310

CASH FLOW FROM INVESTING ACTIVITIES
Capital investments	(54)		(47)
Changes in accrued capital investments	(4)		(13)
Proceeds from asset divestitures, net	10		—



Other, net	(1)		(1)
Net cash used in investing activities	(49)		(61)

CASH FLOW FROM FINANCING ACTIVITIES












Repurchases of common stock	(58)		(59)
Common stock dividends	(21)		(20)
Payments on equity-settled awards	(4)		—




Issuance of common stock	1		1
Bridge loan commitment and debt amendment costs	(8)		—
Shares cancelled for taxes	(41)		(1)

Net cash used in financing activities	(131)		(79)
(Decrease) increase in cash and cash equivalents	(93)		170
Cash and cash equivalents—beginning of period	496		307
Cash and cash equivalents—end of period	$	403	$	477

The accompanying notes are an integral part of these condensed consolidated financial statements.

CALIFORNIA RESOURCES CORPORATION AND SUBSIDIARIES

Notes to the Condensed Consolidated Financial Statements

March 31, 2024

NOTE 1 BASIS OF PRESENTATION

We are an independent oil and natural gas exploration and production and carbon management company operating properties exclusively within California. We are committed to energy transition and have some of the lowest carbon intensity production in the United States. We are in the early stages of permitting several carbon capture and storage (CCS) projects in California. Our carbon management business, which we refer to as Carbon TerraVault, is expected to build, install, operate and maintain CO2 capture equipment, transportation assets and storage facilities in California. In August 2022, we entered into a joint venture with BGTF Sierra Aggregator LLC (Brookfield) to pursue carbon management and storage activities (Carbon TerraVault JV). See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV.

Except when the context otherwise requires or where otherwise indicated, all references to ‘‘CRC,’’ the ‘‘Company,’’ ‘‘we,’’ ‘‘us’’ and ‘‘our’’ refer to California Resources Corporation and its subsidiaries.

In the opinion of our management, the accompanying unaudited financial statements contain all adjustments necessary to fairly present our financial position, results of operations, comprehensive income, equity and cash flows for all periods presented. We have eliminated all significant intercompany transactions and accounts. We account for our share of oil and natural gas producing activities, in which we have a direct working interest, by reporting our proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on our condensed consolidated financial statements. In applying the equity method of accounting, our investment in an unconsolidated subsidiary (Carbon TerraVault JV HoldCo, LLC) was initially recognized at cost and then adjusted for our proportionate share of income or loss in addition to contributions and distributions.

We have prepared this report in accordance with generally accepted accounting principles (GAAP) in the United States and the rules and regulations of the U.S. Securities and Exchange Commission applicable to interim financial information which permit the omission of certain disclosures to the extent they have not changed materially since the latest annual financial statements. We believe our disclosures are adequate to make the information presented not misleading.

The preparation of financial statements in conformity with GAAP requires management to select appropriate accounting policies and make informed estimates and judgments regarding certain types of financial statement balances and disclosures. Actual results could differ. Management believes that these estimates and judgments provide a reasonable basis for the fair presentation of our condensed consolidated financial statements. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2023 (2023 Annual Report).

The carrying amounts of cash, cash equivalents and on-balance sheet financial instruments, other than debt, approximate fair value. Refer to Note 4 Debt for the fair value of our debt.

Certain prior period balances related to natural gas liquid (NGL) marketing activities have been reclassified to conform to our 2024 presentation. For the three months ended March 31, 2023, we reclassified $3 million related to NGL storage activities from other revenue to revenue from marketing of purchased commodities on our condensed consolidated statement of operations.

NOTE 2 PENDING AERA MERGER

On February 7, 2024, we entered into a definitive agreement and plan of merger (Merger Agreement) to combine with Aera Energy, LLC (Aera) in an all-stock transaction (Aera Merger) with an effective date of January 1, 2024. Aera is a leading operator of mature fields in California, primarily in the San Joaquin and Ventura basins, with high oil-weighted production.

Pursuant to the Merger Agreement, we have agreed to issue 21,170,357 shares of common stock (subject to customary adjustments in the event of stock splits, dividend paid in stock and similar items) plus an additional number of shares determined by reference to the dividends declared by us having a record date between the effective date and closing as more fully described in the Merger Agreement. Upon closing, Aera's $950 million outstanding long-term debt will become due as a result of a change in control provision within their legacy debt agreement. We expect to repay a significant portion of this indebtedness with cash on hand and borrowings under our Revolving Credit Facility. We intend to refinance the balance through one or more debt capital markets transactions and, only to the extent necessary, borrowings under a bridge loan facility provided by Citigroup Global Markets, Inc. (the Bank). Under the terms of our debt commitment letter with the Bank, it has committed, subject to satisfaction of customary conditions, to provide us with an unsecured 364-day bridge loan facility in an aggregate principal amount of $500 million (Bridge Loan Facility). Additionally, we have amended our Revolving Credit Facility as described in Note 4 Debt in connection with the pending Aera Merger. During the three months ended March 31, 2024, we incurred $8 million related to the bridge loan commitment and amending our Revolving Credit Facility which is reported in other current assets, net on our condensed consolidated balance sheet.

Closing of the Aera Merger is subject to certain conditions, including, among others, approval of the stock issuance by our stockholders, expiration of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended (HSR Act), prior authorization by the Federal Energy Regulatory Commission under Section 203 of the Federal Power Act and other customary closing conditions. The required waiting period under the HSR Act expired on March 25, 2024.

NOTE 3 INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS

In August 2022, our wholly-owned subsidiary Carbon TerraVault I, LLC entered into a joint venture with Brookfield for the further development of a carbon management business in California. We hold a 51% interest in the Carbon TerraVault JV and Brookfield holds a 49% interest. We determined that the Carbon TerraVault JV is a variable interest entity (VIE); however, we share decision-making power with Brookfield on all matters that most significantly impact the economic performance of the joint venture. Therefore, we account for our investment in the Carbon TerraVault JV under the equity method of accounting. Transactions between us and the Carbon TerraVault JV are related party transactions.

Brookfield has committed an initial $500 million to invest in CCS projects that are jointly approved through the Carbon TerraVault JV. As part of the formation of the Carbon TerraVault JV, we contributed rights to inject CO2 into the 26R reservoir in our Elk Hills field for permanent CO2 storage (26R reservoir) and Brookfield committed to make an initial investment of $137 million, payable in three installments with the last two installments subject to the achievement of certain milestones. We achieved the milestone for the second installment in March 2024. The third installment will be sized based on permitted storage capacity.

Brookfield contributed the first $46 million installment of their initial investment to the Carbon TerraVault JV in 2022 and the second $46 million installment was recorded as a receivable from affiliate on our condensed consolidated balance sheet as of March 31, 2024. The remaining balance of the initial installment plus the second installment may, at our sole discretion, be distributed to us or used to satisfy future capital contributions, among other items. Because the parties have certain put and call rights (repurchase features) with respect to the 26R reservoir if certain milestones are not met, the first and second installment of the initial investment by Brookfield is reflected as a contingent liability included in other long-term liabilities on our condensed consolidated balance sheets. The contingent liability was $99 million and $52 million at March 31, 2024 and December 31, 2023, respectively.

The tables below present the summarized financial information related to our equity method investment in the Carbon TerraVault JV (and do not include amounts we have incurred related to development of our carbon management business, Carbon TerraVault) along with related party transactions for the periods presented.



	March 31,		December 31,
	2024		2023
	(in millions)
Investment in unconsolidated subsidiary(a)	$	16	$	19
Receivable from affiliate(b)	$	66	$	19
Other long-term liabilities - Contingent liability (related to Carbon TerraVault JV put and call rights)	$	99	$	52

(a)Reflects our investment less losses allocated to us of $3 million and $9 million for the three months ended March 31, 2024 and the year ended December 31, 2023, respectively.

(b)The amount of Brookfield's contributions available to us and amounts due to us under the MSA (described further below) are reported as receivable from affiliate. At March 31, 2024, the amount of $66 million includes the remaining $63 million of Brookfield's first and second installments of their initial investment which is available to us and $3 million related to the MSA and vendor reimbursements. At December 31, 2023, the amount of $19 million includes $17 million remaining of Brookfield's initial contribution available to us and $2 million related to the MSA and vendor reimbursements.


	Three months ended March 31,
	2024		2023
	(in millions)
Loss from investment in unconsolidated subsidiary	$	3	$	2
General and administrative expenses(a)	$	2	$	1

(a)General and administrative expenses on our condensed consolidated statements of operations have been reduced by this amount which we have invoiced to the Carbon TerraVault JV under the MSA for back-office operational and commercial services.

We are also performing well abandonment work at our Elk Hills field as part of the permitting process for injection of CO2 at the 26R reservoir. During the three months ended March 31, 2024 and 2023, we performed abandonment work and sought reimbursement in the amounts of $4 million and $1 million, respectively, from the Carbon TerraVault JV.

The Carbon TerraVault JV has an option to participate in certain projects that involve the capture, transportation and storage of CO2 in California. This option expires upon the earlier of (1) August 2027, (2) when a final investment decision has been approved by the Carbon TerraVault JV for storage projects representing in excess of 5 million metric tons per annum (MMTPA) in the aggregate, or (3) when Brookfield has made contributions to the joint venture in excess of $500 million (unless Brookfield elects to increase its commitment).

We entered into a Management Services Agreement (MSA) with the Carbon TerraVault JV whereby we provide administrative, operational and commercial services under a cost-plus arrangement. Services may be supplemented by using third parties and payments to us under the MSA are limited to the amount in an approved budget. The MSA may be terminated by mutual agreement of the parties, among other events.

NOTE 4 DEBT

As of March 31, 2024 and December 31, 2023, our long-term debt consisted of the following:



	March 31,		December 31,
	2024		2023		Interest Rate	Maturity
	(in millions)

Revolving Credit Facility	$	—	$	—	SOFR plus 2.50%-3.50% ABR plus 1.50%-2.50%(a)	July 31, 2027(b)

Senior Notes	545		545		7.125%	February 1, 2026
Principal amount	$	545	$	545
Unamortized debt issuance costs	(4)		(5)
Long-term debt, net	$	541	$	540

(a)At our election, borrowings under the amended Revolving Credit Facility may be alternate base rate (ABR) loans or term SOFR loans, plus an applicable margin. ABR loans bear interest at a rate equal to the highest of (i) the federal funds effective rate plus 0.50%, (ii) the administrative agent prime rate and (iii) the one-month SOFR rate plus 1%. Term SOFR loans bear interest at term SOFR, plus an additional 10 basis points per annum credit spread adjustment. The applicable margin is adjusted based on the commitment utilization percentage and will vary from (i) in the case of ABR loans, 1.50% to 2.50% and (ii) in the case of term SOFR loans, 2.50% to 3.50%.

(b)The Revolving Credit Facility is subject to a springing maturity to August 4, 2025 if any of our Senior Notes are outstanding on that date.

On April 26, 2023, we entered into an Amended and Restated Credit Agreement (Revolving Credit Facility) with Citibank, N.A., as administrative agent, and certain other lenders, which amended and restated in its entirety the prior credit agreement dated October 27, 2020. As of March 31, 2024, our Revolving Credit Facility consisted of a senior revolving loan facility with an aggregate commitment of $630 million. Our Revolving Credit Facility also included a sub-limit of $250 million for the issuance of letters of credit. As of March 31, 2024, $153 million letters of credit were issued to support ordinary course marketing, insurance, regulatory and other matters. As of March 31, 2024, we had $477 million of availability on our Revolving Credit Facility after taking into account the $153 million letters of credit outstanding.

In connection with the Merger Agreement in February 2024, we entered into a second amendment to our Revolving Credit Facility to, among other things, permit the incurrence of indebtedness under the Bridge Loan Facility. In March 2024, we entered into the third amendment to our Revolving Credit Facility. The amendment facilitated certain matters with respect to the Aera Merger, including the postponement of the regular spring borrowing base redetermination until the fall of 2024 and certain other amendments.

In March 2024, we obtained commitments from our existing lenders and certain new lenders to amend our Revolving Credit Facility upon the closing of the Aera Merger. These commitments include increasing our borrowing base from $1.2 billion to $1.5 billion, increasing the aggregate commitment amount from $630 million to $1.1 billion and other matters. These commitments are subject to certain conditions prior to becoming effective, including the closing of the Aera Merger.

The borrowing base is redetermined semi-annually and was reaffirmed at $1.2 billion on October 30, 2023. The regular spring borrowing base redetermination for 2024 was postponed until the fall of 2024. The borrowing base takes into account the estimated value of our proved reserves, total indebtedness and other relevant factors consistent with customary reserves-based lending criteria. The amount we are able to borrow under our Revolving Credit Facility is limited to the amount of the commitment described above.

As of March 31, 2024, we were in compliance with all financial and other debt covenants under our Revolving Credit Facility and Senior Notes. For more information on our Senior Notes, see Part II, Item 8 – Financial Statements and Supplementary Data, Note 4 Debt in our 2023 Annual Report.

Fair Value

The fair value of our fixed-rate debt at March 31, 2024 and December 31, 2023 was approximately $549 million and $554 million, respectively. We estimate fair value based on known prices from market transactions (using Level 1 inputs on the fair value hierarchy).

NOTE 5 LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES

We are involved, in the normal course of business, in lawsuits, environmental and other claims and other contingencies that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties or injunctive or declaratory relief.

We accrue reserves for currently outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserve balances for these items at March 31, 2024 and December 31, 2023 were not material to our condensed consolidated balance sheets as of such dates. We also evaluate the amount of reasonably possible losses that we could incur as a result of these matters. We believe that reasonably possible losses that we could incur in excess of reserves cannot be accurately determined.

In October 2020, Signal Hill Services, Inc. defaulted on its decommissioning obligations associated with two offshore platforms. The Bureau of Safety and Environmental Enforcement (BSEE) determined that former lessees, including our former parent, Occidental Petroleum Corporation (Oxy) with a 37.5% share, are responsible for accrued decommissioning obligations associated with these offshore platforms. Oxy sold its interest in the platforms approximately 30 years ago and it is our understanding that Oxy has not had any connection to the operations since that time and was challenging BSEE's order. Oxy notified us of the claim under the indemnification provisions of the Separation and Distribution Agreement between us and Oxy. In September 2021, we accepted the indemnification claim from Oxy and are challenging the order from BSEE. In March 2024, we entered into a cost sharing agreement with former lessees to share in ongoing maintenance costs during the pendency of the challenge to the BSEE order. We estimate our ongoing share of maintenance costs for the platforms could approximate $5 million to $8 million per year. Due to the preliminary stage of the process, no cost estimates to abandon the offshore platforms have been determined.

NOTE 6 DERIVATIVES

We continue to maintain a commodity hedging program primarily focused on crude oil to help protect our cash flows, margins and capital program from the volatility of commodity prices. We also enter into natural gas swaps for the purpose of hedging our fuel consumption at one of our steamfloods as well as swaps for natural gas purchases and sales related to our marketing activities. We did not have any derivative instruments designated as accounting hedges as of and for the three months ended March 31, 2024 and 2023. Unless otherwise indicated, we use the term "hedge" to describe derivative instruments that are designed to implement our hedging strategy.

Summary of Derivative Contracts

We held the following Brent-based contracts as of March 31, 2024:


	Q2 2024		Q3 2024		Q4 2024		1H 2025		2H 2025
Sold Calls
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	90.07	$	90.07	$	90.07	$	86.88	$	86.90

Purchased Puts
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	65.17	$	65.17	$	65.17	$	61.43	$	61.45

Swaps
Barrels per day	8,875		8,875		5,500		3,500		3,250
Weighted-average price per barrel	$	79.28	$	80.10	$	77.45	$	72.81	$	72.50

The outcomes of the derivative positions are as follows:

•Sold calls – we make settlement payments for prices above the indicated weighted-average price per barrel.

•Purchased puts – we receive settlement payments for prices below the indicated weighted-average price per barrel.

•Swaps – we make settlement payments for prices above the indicated weighted-average price per barrel and receive settlement payments for prices below the indicated weighted-average price per barrel.

At March 31, 2024, we also held the following swaps to hedge purchased natural gas used in our operations as shown in the table below.


	Q2 2024		Q3 2024		Q4 2024
Swaps:
MMBtu per day	10,000		10,000		10,000
Weighted-average price per MMBtu	$	5.65	$	5.65	$	5.65

We also have a limited number of derivative contracts related to our natural gas marketing activities are intended to lock in locational price spreads. These derivative contracts are not significant to our results of operations or financial statements taken as a whole.

Fair Value of Derivatives

Derivative instruments not designated as hedging instruments are required to be recorded on the balance sheet at fair value. We report gains and losses on our derivative contracts which hedge commodity price risk related to our oil production and our marketing activities in operating revenue on our consolidated statements of operations as shown in the table below:


	Three months ended March 31,
	2024		2023
(in millions)
Non-cash commodity derivative (loss) gain	$	(59)	$	107


Settlements and premiums	(12)		(65)

Net (loss) gain from commodity derivatives	$	(71)	$	42

We report gains and losses on our derivative contracts for purchased natural gas used to generate steam for our steamflood operations as a component of operating expense on our consolidated statement of operations. For the three months ended March 31, 2024, we recognized a net loss of $1 million (which includes a non-cash gain of $1 million and $2 million of settlement payments) in other operating expenses, net on our consolidated statement of operations. We did not have derivative contracts related to purchased natural gas for the three months ended March 31, 2023.

Our derivative contracts are measured at fair value using industry-standard models with various inputs, including quoted forward prices, and are classified as Level 2 in the required fair value hierarchy for the periods presented.

The following tables present the fair values of our outstanding commodity derivatives as of March 31, 2024 and December 31, 2023:


March 31, 2024
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	11	$	(11)	$	—
Other noncurrent assets	24		(24)		—

Current liabilities	(46)		11		(35)
Noncurrent liabilities	(38)		24		(14)
	$	(49)	$	—	$	(49)


December 31, 2023
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	39	$	(18)	$	21
Other noncurrent assets	38		(32)		6

Current liabilities	(26)		18		(8)
Noncurrent liabilities	(34)		32		(2)
	$	17	$	—	$	17

NOTE 7 INCOME TAXES

The following table presents the components of our total income tax provision:


	Three months ended March 31,
	2024		2023
	(in millions)
(Loss) income before income taxes	$	(19)	$	376

Current income tax provision	—		28
Deferred income tax (benefit) provision	(9)		47
Total income tax (benefit) provision	$	(9)	$	75

Our income tax provision or benefit for interim periods is determined by applying an estimated annual effective tax rate to (loss) income before income taxes with the result adjusted for discrete items, if any, in the relevant period. A reconciliation of the U.S. federal statutory tax rate to effective tax rate, including discrete items, for the three months ended March 31, 2024 and 2023 is shown below:


	Three months ended March 31,
	2024		2023
U.S federal statutory tax rate	21	%	21	%
State income taxes, net	7		7
Other	3		—
Annual effective tax rate	31	%	28	%
Discrete items:
Stock compensation and other	16		—
Change in the valuation allowance	—		(8)
Effective tax rate	47	%	20	%

Our annual effective tax rate of 31% differed from the U.S. federal statutory tax rate of 21% for the three months ended March 31, 2024 primarily due to state taxes and disallowed executive compensation expense. During the three months ended March 31, 2024, we recognized an income tax benefit related to the settlement of certain equity-settled stock-based compensation awards, which have the effect of increasing our effective tax rate by 16%.

Our annual effective tax rate of 28% differed from the U.S. federal statutory tax rate of 21% for the three months ended March 31, 2023 due to state taxes. During the three months ended March 31, 2023 we recognized a tax benefit for the release of a valuation allowance which was recorded in 2022 related to a capital loss generated from the divestiture of oil and gas assets. See Part II, Item 8 – Financial Statements and Supplementary Data, Note 7 Income Taxes in our 2023 Annual Report for additional information.

Management expects to realize the recorded deferred tax assets primarily through future income and reversal of taxable temporary differences. Realization of our existing deferred tax assets is not assured and depends on a number of factors including our ability to generate sufficient taxable income in future periods.

NOTE 8 DIVESTITURES AND ACQUISITIONS

Divestitures

Fort Apache in Huntington Beach

In March 2024, we sold our 0.9-acre Fort Apache real estate property in Huntington Beach, California for a purchase price of $10 million and recognized a $6 million gain.

Ventura Basin Transactions

During 2021 and 2022, we entered into transactions to sell our Ventura basin assets. The transaction contemplates multiple closings that are subject to customary closing conditions. The closing of the sale of our remaining assets in the Ventura basin is subject to final approval from the State Lands Commission, which we expect could occur in 2024. These remaining assets, consisting of property, plant and equipment, and associated asset retirement obligations are classified as held for sale on our condensed consolidated balance sheets at March 31, 2024 and December 31, 2023. See Part II, Item 8 – Financial Statements and Supplementary Data, Note 8 Divestitures and Acquisitions in our 2023 Annual Report for additional information on the Ventura basin transactions.

Other

During the three months ended March 31, 2023, we sold a non-producing asset in exchange for the assumption of liabilities, recognizing a $7 million gain related to the liability reduction.

Acquisitions

In 2022, we acquired properties for carbon management activities for approximately $17 million. We intend to divest a portion of these assets and recorded these assets at fair value recognizing an impairment of $3 million in the first quarter of 2023. The fair value, using Level 3 inputs in the fair value hierarchy, declined during the first quarter of 2023 due to market conditions (including inflation and rising interest rates). The assets being divested are classified as held for sale as of March 31, 2024 on our condensed consolidated balance sheet.

NOTE 9 STOCKHOLDERS' EQUITY

Share Repurchase Program

Our Board of Directors has authorized a Share Repurchase Program to acquire up to $1.35 billion of our common stock through December 31, 2025. The repurchases may be effected from time-to-time through open market purchases, privately negotiated transactions, Rule 10b5-1 plans, accelerated stock repurchases, derivative contracts or otherwise in compliance with Rule 10b-18, subject to market conditions. The Share Repurchase Program does not obligate us to repurchase any dollar amount or number of shares and our Board of Directors may modify, suspend or discontinue authorization of the program at any time. The following is a summary of our share repurchases, which is held as treasury stock, for the periods presented:


	Total Number of Shares Purchased	Total Value of Shares Purchased		Average Price Paid per Share
	(number of shares)	(in millions)		($ per share)
Three months ended March 31, 2023	1,423,764	$	59	$	41.25
Three months ended March 31, 2024	1,065,764	$	58	$	53.26




Inception of Program (May 2021) through March 31, 2024	15,929,679	$	662	$	41.39

Note: The total value of shares purchased includes approximately $1 million in both the three months ended March 31, 2024 and 2023 related to excise taxes on share repurchases, which was effective beginning on January 1, 2023. Commissions paid on share repurchases were not significant in all periods presented.

Dividends

Our Board of Directors declared the following cash dividends for each of the periods presented.


	Total Dividend		Rate Per Share
	(in millions)		($ per share)

Three months ended March 31, 2024	$	21	$	0.31




Three months ended March 31, 2023	$	20	$	0.2825

In addition to dividends on our common stock shown in the table above, we paid $4 million on equity-settled stock-based compensation awards in the three months ended March 31, 2024. Future cash dividends, and the establishment of record and payment dates, are subject to final determination by our Board of Directors each quarter after reviewing our financial performance and position. See Note 14 Subsequent Events for information on future cash dividends.

Warrants

In October 2020, we reserved an aggregate 4,384,182 shares of our common stock for warrants which are exercisable at $36 per share through October 26, 2024.

As of March 31, 2024, we had outstanding warrants exercisable into 4,163,670 shares of our common stock (subject to adjustments pursuant to the terms of the warrants). During the three months ended March 31, 2024, we issued 18,851 shares of our common stock in exchange for warrants. During the three months ended March 31, 2023, we issued an insignificant number of shares of our common stock in exchange for warrants.

See Part II, Item 8 – Financial Statements and Supplementary Data, Note 10 Stockholders' Equity in our 2023 Annual Report for additional information on the terms of our warrants.

NOTE 10 EARNINGS PER SHARE

Basic and diluted earnings per share (EPS) were calculated using the treasury stock method for the three months ended March 31, 2024 and 2023. Our restricted stock unit (RSU) and performance stock unit (PSU) awards are not considered participating securities since the dividend rights on unvested shares are forfeitable.

For basic EPS, the weighted-average number of common shares outstanding excludes shares underlying our equity-settled awards and warrants. For diluted EPS, the basic shares outstanding are adjusted by adding potential common shares, if dilutive.

The following table presents the calculation of basic and diluted EPS, for the three months ended March 31, 2024 and 2023:


	Three months ended March 31,
	2024		2023
	(in millions, except per-share amounts)
Numerator for Basic and Diluted EPS
Net (loss) income	$	(10)	$	301





Denominator for Basic EPS
Weighted-average shares	69.0		71.3

Potential common shares, if dilutive:
Warrants	—		0.5
Restricted stock units	—		0.9
Performance stock units	—		0.8

Denominator for Diluted EPS
Weighted-average shares	69.0		73.5

EPS
Basic	$	(0.14)	$	4.22
Diluted	$	(0.14)	$	4.09

The following table presents potentially dilutive weighted-average common shares which were excluded from the denominator for diluted EPS in periods of losses:


	Three months ended March 31,
	2024	2023
(in millions)
Shares issuable upon exercise of warrants	4.2	—
Shares issuable upon settlement of RSUs	0.9	—
Shares issuable upon settlement of PSUs	1.1	—
Total antidilutive shares	6.2	—

NOTE 11 SUPPLEMENTAL ACCOUNT BALANCES

Revenues — We derive most of our revenue from sales of oil, natural gas and NGLs, with the remaining revenue primarily generated from sales of electricity and marketing activities related to storage and managing excess pipeline capacity.

The following table provides disaggregated revenue for sales of produced oil, natural gas and NGLs to customers:



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	348	$	390
Natural gas	32		263
NGLs	49		62
Oil, natural gas and NGL sales	$	429	$	715

From time-to-time, we enter into transactions for third-party production, which we report as revenue from marketing of purchased commodities on our condensed consolidated statement of operations. Revenues from marketing of purchased commodities primarily results from the storage or transportation of natural gas to take advantage of differences in pricing or location or in the quality of other products. The following table provides disaggregated revenue for sales to customers related to our marketing activities:



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	20	$	—
Natural gas	48		184
NGLs	6		3
Revenue from marketing of purchased commodities	$	74	$	187

Inventories — Materials and supplies, which primarily consist of well equipment and tubular goods used in our oil and natural gas operations, are valued at weighted-average cost and are reviewed periodically for obsolescence. Finished goods include produced oil and NGLs in storage, which are valued at the lower of cost or net realizable value. Inventories, by category, are as follows:



	March 31,		December 31,
	2024		2023
	(in millions)
Materials and supplies	$	68	$	68
Finished goods	2		4
Inventories	$	70	$	72

Other current assets, net — Other current assets, net include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Net amounts due from joint interest partners(a)	$	40	$	43

Fair value of commodity derivative contracts	—		21
Prepaid expenses	29		19
Greenhouse gas allowances	6		12

Income tax receivable	4		—
Other	16		18
Other current assets, net	$	95	$	113

(a)Included in the March 31, 2024 and December 31, 2023 net amounts due from joint interest partners are allowances of $3 million.

Other noncurrent assets — Other noncurrent assets include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Operating lease right-of-use assets	$	85	$	73
Deferred financing costs - Revolving Credit Facility	10		11
Emission reduction credits	11		11
Prepaid power plant maintenance	2		34
Fair value of commodity derivative contracts	—		6
Deposits and other	15		13
Other noncurrent assets	$	123	$	148

Accrued liabilities — Accrued liabilities include the following:


	March 31,		December 31,
	2024		2023
	(in millions)
Employee-related costs	$	48	$	82
Taxes other than on income	50		35
Asset retirement obligations	90		99
Interest	8		18
Operating lease liability	19		15
Fair value of derivative contracts	35		8
Premiums due on commodity derivative contracts	13		21
Liability for settlement payments on commodity derivative contracts	5		8
Amounts due under production-sharing contracts	10		5
Signal Hill maintenance	13		12
Income taxes payable	—		18

Other	47		45
Accrued liabilities	$	338	$	366

Other long-term liabilities — Other long-term liabilities includes the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Compensation-related liabilities	$	33	$	38
Postretirement benefit plan	35		36
Operating lease liability	56		55
Fair value of commodity derivative contracts	14		2
Premiums due on commodity derivative contracts	10		10
Contingent liability (related to Carbon TerraVault JV put and call rights)	99		52
Other	6		8
Other long-term liabilities	$	253	$	201

General and administrative expenses — The table below shows G&A expenses for our exploration and production business (including unallocated corporate overhead and other) separately from our carbon management business. The amounts shown for our carbon management business are net of amounts invoiced by us under the MSA with the Carbon TerraVault JV. See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV.


	Three months ended March 31,
	2024		2023
	(in millions)
Exploration and production, corporate and other	$	55	$	62
Carbon management business	2		3
Total general and administrative expenses	$	57	$	65

NOTE 12 SUPPLEMENTAL CASH FLOW INFORMATION

We made U.S. federal and state income tax payments of $22 million during the three months ended March 31, 2024. We did not make U.S. federal or state income tax payments during the three months ended March 31, 2023.

Interest paid, net of capitalized amounts, was $20 million and $21 million for the three months ended March 31, 2024 and 2023, respectively. Interest income was $6 million and $3 million for the three months ended March 31, 2024 and 2023, respectively.

Non-cash investing activities in the three months ended March 31, 2023 included $2 million related to our share of capital calls by the Carbon TerraVault JV. See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV.

Non-cash financing activities in the three months ended March 31, 2024 included approximately $87 million related to the issuance of shares for our stock-based compensation awards. Non-cash financing activities in the three months ended March 31, 2024 also included approximately $1 million related to dividend equivalents accrued for stock-based compensation awards and approximately $1 million related to an excise tax on share repurchases. Non-cash financing activities in the three months ended March 31, 2023 included an insignificant amount, for dividend equivalents accrued for stock-based compensation awards and approximately $1 million related to an excise tax on share repurchases.

NOTE 13 CONDENSED CONSOLIDATING FINANCIAL INFORMATION

We have designated certain of our subsidiaries as Unrestricted Subsidiaries under the indenture governing our Senior Notes (Senior Notes Indenture). Unrestricted Subsidiaries (as defined in the Senior Notes Indenture) are subject to fewer restrictions under the Senior Notes Indenture. We are required under the Senior Notes Indenture to present the financial condition and results of operations of CRC and its Restricted Subsidiaries (as defined in the Senior Notes Indenture) separate from the financial condition and results of operations of its Unrestricted Subsidiaries. The following condensed consolidating balance sheets as of March 31, 2024 and December 31, 2023 and the condensed consolidating statements of operations for the three months ended March 31, 2023 and 2024, as applicable, reflect the condensed consolidating financial information of our parent company, CRC (Parent), our combined Unrestricted Subsidiaries, our combined Restricted Subsidiaries and the elimination entries necessary to arrive at the information for the Company on a consolidated basis. The financial information may not necessarily be indicative of the financial condition and results of operations had the Unrestricted Subsidiaries operated as independent entities.

Condensed Consolidating Balance Sheets

As of March 31, 2024 and December 31, 2023


	As of March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	428	$	67	$	344	$	—	$	839
Total property, plant and equipment, net	13		16		2,764		—		2,793
Investments in consolidated subsidiaries	2,358		(17)		1,328		(3,669)		—
Deferred tax asset	139		—		—		—		139
Investment in unconsolidated subsidiary	—		16		—		—		16
Other assets	12		50		61		—		123
TOTAL ASSETS	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910

Total current liabilities	82		15		497		—		$	594
Long-term debt	541		—		—		—		541
Asset retirement obligations	—		—		429		—		429
Other long-term liabilities	71		122		60		—		253
Amounts due to (from) affiliates	163		24		(187)		—		—
Total equity	2,093		(29)		3,698		(3,669)		2,093
TOTAL LIABILITIES AND EQUITY	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910


	As of December 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	511	$	20	$	398	$	—	$	929
Total property, plant and equipment, net	14		12		2,744		—		2,770
Investments in consolidated subsidiaries	2,311		(11)		1,347		(3,647)		—
Deferred tax asset	132		—		—		—		132
Investment in unconsolidated subsidiary	—		19		—		—		19
Other assets	12		36		100		—		148
TOTAL ASSETS	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Total current liabilities	142		13		461		—		$	616
Long-term debt	540		—		—		—		540
Asset retirement obligations	—		—		422		—		422
Other long-term liabilities	79		73		49		—		201

Total equity	2,219		(10)		3,657		(3,647)		2,219
TOTAL LIABILITIES AND EQUITY	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Condensed Consolidating Statement of Operations

For the three months ended March 31, 2024 and 2023


	Three months ended March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	6	$	—	$	457	$	(9)	$	454
Total costs and other	60		10		403		(9)		464
Gain on asset divestitures	—		—		6		—		6
Non-operating (loss) income	(12)		(4)		1		—		(15)
(LOSS) INCOME BEFORE INCOME TAXES	(66)		(14)		61		—		(19)
Income tax benefit	9		—		—		—		9
NET (LOSS) INCOME	$	(57)	$	(14)	$	61	$	—	$	(10)


	Three months ended March 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	4	$	—	$	1,020	$	—	$	1,024
Total costs and other	50		8		580		—		638
Gain on asset divestitures	—		—		7		—		7
Non-operating (loss) income	(15)		(3)		1		—		(17)
(LOSS) INCOME BEFORE INCOME TAXES	(61)		(11)		448		—		376
Income tax provision	(75)		—		—		—		(75)
NET (LOSS) INCOME	$	(136)	$	(11)	$	448	$	—	$	301

NOTE 14 SUBSEQUENT EVENTS

Dividend

On May 7, 2024, our Board of Directors declared a quarterly cash dividend of $0.31 per share of common stock. The dividend is payable to shareholders of record at the close of business on May 31, 2024 and is expected to be paid on June 14, 2024.

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

General

We are an independent oil and natural gas exploration and production and carbon management company operating properties exclusively within California. We are committed to energy transition and have some of the lowest carbon intensity production in the United States. We are in the early stages of permitting several carbon capture and storage (CCS) projects in California. Our carbon management business, which we refer to as Carbon TerraVault, is expected to build, install, operate and maintain CO2 capture equipment, transportation assets and storage facilities in California. In August 2022, we entered into a joint venture with BGTF Sierra Aggregator LLC (Brookfield) to pursue carbon management and storage activities (Carbon TerraVault JV). For more information about the risks involved in our carbon capture projects, see Part I, Item 1A – Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2023 (2023 Annual Report) and for more information on the Carbon TerraVault JV, see Part I, Item 1 – Financial Statements, Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions.

Pending Aera Merger

Upon completion of the transaction, we currently expect our existing stockholders to own approximately 77% of the combined company and the existing Aera owners to own approximately 23% of the combined company, on a fully diluted basis. The Aera Merger is expected to close around mid-year 2024. Post closing of the Aera Merger, and subject to Board approval, we expect to increase our quarterly dividend.

In the three months ended March 31, 2024, we incurred $13 million of transaction and integration costs related to the Aera Merger included in other operating expenses, net on our condensed consolidated statement of operations. We also incurred $8 million in financing fees, which is included in other current assets, net on our condensed consolidated balance sheet as of March 31, 2024.

Business Environment and Industry Outlook

Commodity Prices

Our operating results and those of the oil and natural gas industry as a whole are heavily influenced by commodity prices. Oil and natural gas prices and differentials may fluctuate significantly as a result of numerous market-related variables. These and other factors make it impossible to predict realized prices reliably. We may respond to economic conditions by adjusting the amount and allocation of our capital program while continuing to identify efficiencies and cost savings. Volatility in oil prices may materially affect the quantities of oil and natural gas reserves we can economically produce over the longer term. Refer to Prices and Realizations below for information on our realized prices.

The following table presents the average daily benchmark prices for oil and natural gas during the periods presented:


	Three months ended
	March 31, 2024		December 31, 2023
Brent oil ($/Bbl)	$	81.84	$	82.69
WTI oil ($/Bbl)	$	76.96	$	78.32
NYMEX Henry Hub ($/MMBtu) Average Monthly Settled Price	$	2.24	$	2.88

Regulatory Updates

Well Permits

CalGEM remains in the process of developing standard operating procedures for reviewing well permit applications that it commenced in the second half of 2023. Significant permitting delays continue pending CalGEM’s completion of this process. An increase in permits approvals for workovers has continued through the first quarter of 2024, and substantially increased in April 2024. As of May 6, 2024, we have received 73 permits for workovers since the beginning of the year. As of May 6, 2024, we have also received 8 permits for deepenings and 1 permit for a sidetrack for wells in our Wilmington field. With only a few exceptions, there continues to be no new drill permits issued in the state.

Kern County EIR Litigation

On March 7, 2024, the California Court of Appeals, Fifth Appellate District (Court of Appeals), issued its ruling on the six challenges to Kern County’s Supplemental Recirculated Environmental Impact Report (SREIR) for Kern County Zoning Ordinance G-8992 (Ordinance). In its disposition, the Court of Appeals ordered the Trial Court to enter a modified judgement and fourth preemptory writ directing Kern County (i) to set aside approval of the Ordinance, SREIR and related findings of facts and statements of overriding considerations; and (ii) not to present a revised Ordinance for approval until Kern County has (a) prepared a revised SREIR that corrects CEQA violations relating to the (1) rejection of agricultural conservation easements as a form of partial mitigation for the conversion of agricultural land, (2) assessment of cancer risks associated with the drilling of multiple wells near sensitive receptors and (3) analysis of water supply impacts; and (b) circulated the revised SREIR for public review and comment, prepared responses to comments, and certified the revised SREIR.

On March 22, 2024, Kern County released a notice of preparation of the Second Supplemental Revised Environmental Impact Report (SSREIR). We expect that Kern County will prepare a draft SSREIR, circulate it for public comments and thereafter certify the SSREIR and approve the Ordinance. After that, the Trial Court would then consider whether to lift the stay. If that occurs, well permitting could resume assuming no further challenges to the SSREIR.

As a result of the ruling of the Court of Appeals in the Kern County EIR litigation and current lack of permits with respect to our Kern County properties, we currently plan to operate one drilling rig within Kern County in 2024. We have sufficient permits in hand to keep that rig active through the end of 2025.

CCS Project Permitting

In December 2023, Kern County released a draft EIR prepared in connection with our application for conditional use permits for our CTV I CCS project. The project was originally scheduled to be considered by the Kern County Planning Commission on March 28th; however, based on comments received the Planning Commission required further environmental review before it can consider the project and the draft EIR. The Planning Commission recommended that the consideration of applicable changes to the zoning ordinance and certification of the EIR be continued to the August 22, 2024 Planning Commission hearing, at which the Planning Commission will decide whether to recommend the adoption of the changes to the zoning ordinance and certification of the EIR to the Board of Supervisors. The Board of Supervisors meeting is expected to occur in or around September or October.

Low Carbon Fuel Standard

On February 14, 2024, the California Air Resources Board (CARB) announced that it was postponing the previously scheduled March 21, 2024, public hearing regarding the proposed amendments to the LCFS Regulation released on December 19, 2023. Due to continuous substantial public feedback on the proposed amendments, CARB intends to release revised proposed amendments for public review and comment, to be followed by a public hearing. The release of the revised proposed amendments is pending. These revisions may impact the eligibility of certain of our CCS projects for LCFS credits.

Results of Oil and Gas Operations

Production

The following table sets forth our average net production of oil, NGLs and natural gas per day in each of the California oil and natural gas basins in which we operated for the periods presented.


	Three months ended
	March 31, 2024	December 31, 2023
Oil (MBbl/d)
San Joaquin Basin	30	32
Los Angeles Basin	18	18


Total	48	50
NGLs (MBbl/d)
San Joaquin Basin	11	11



Total	11	11
Natural gas (MMcf/d)
San Joaquin Basin	90	114
Los Angeles Basin	1	1

Sacramento Basin	14	15
Total	105	130

Total Net Production (MBoe/d)	76	83

Total daily net production for the three months ended March 31, 2024 compared to the three months ended December 31, 2023 decreased by 7 MBoe/d predominately due to scheduled plant downtime during the first quarter of 2024. The decrease in production also reflects natural production decline as well as the divestiture of our share of a non-operated field in December 2023. Our production-sharing contracts (PSCs), which are described below, did not have a significant impact on our net oil production in the three months ended March 31, 2024 compared to the three months ended December 31, 2023.

The following table reconciles our average net production to our average gross production (which includes production from the fields we operate and our share of production from fields operated by others) for the periods presented:


	Three months ended
	March 31, 2024	December 31, 2023
	(MBoe/d)
Total Net Production	76	83
Partners' share under PSC-type contracts	7	7
Working interest and royalty holders' share	7	7
Changes in NGL inventory and other	4	1
Total Gross Production	94	98

Production-Sharing Contracts (PSCs)

Our share of production and reserves from operations in the Wilmington field in the Los Angeles basin is subject to contractual arrangements similar to production-sharing contracts (PSCs) that are in effect through the economic life of the assets. The reporting of our PSC-type contracts creates a difference between reported operating costs, which are for the full field, and reported volumes, which are only our net share, inflating the per barrel operating costs. Operating costs, excluding effects of PSC-type contracts is a non-GAAP measure which adjusts for excess costs attributable to PSC-type contracts for the periods presented in the tables below:


	Three months ended
	March 31, 2024				December 31, 2023
	(in millions)		($ per Boe)		(in millions)		($ per Boe)
Operating costs(a)	$	179	$	25.80	$	186	$	24.49
Excess costs attributable to PSC-type contracts	(18)		(2.54)		(17)		(2.22)
Operating costs, excluding effects of PSC-type contracts	$	161	$	23.26	$	169	$	22.27

(a)Operating costs related to our exploration and production activities and are presented before elimination entries.

For further information on our production-sharing contracts, see Part I, Item 1 & 2 Business and Properties, Oil and Natural Gas Operations, Production, Price and Cost History in our 2023 Annual Report.

Prices and Realizations

The following tables set forth the average realized prices and price realizations as a percentage of average Brent, WTI and NYMEX indexes for our oil and natural gas operations for the periods presented:


	Three months ended
	March 31, 2024			December 31, 2023
	Price		Realization	Price		Realization
Oil ($ per Bbl)
Brent	$	81.84		$	82.69

Realized price without derivative settlements	$	80.16	98%	$	82.00	99%
Derivative settlements	(2.99)			(10.66)
Realized price with derivative settlements	$	77.17	94%	$	71.34	86%

WTI	$	76.96		$	78.32

Realized price without derivative settlements	$	80.16	104%	$	82.00	105%
Realized price with derivative settlements	$	77.17	100%	$	71.34	91%

NGLs ($ per Bbl)
Realized price (% of Brent)	$	50.50	62%	$	49.08	59%
Realized price (% of WTI)	$	50.50	66%	$	49.08	63%

Natural gas
NYMEX Henry Hub ($/MMBtu) - Average Monthly Settled Price	$	2.24		$	2.88

Realized price ($/Mcf)	$	3.90	174%	$	4.66	162%

Oil — Brent prices were relatively flat for the three months ended March 31, 2024 compared to the three months ended December 31, 2023. The slight decline in Brent prices is attributable to general market factors, including developing concern over the strength of China’s economy.

NGLs — NGL prices for the three months ended March 31, 2024 increased compared to the three months ended December 31, 2023 due to slightly stronger butane demand and development of alternative markets for our natural gasoline. California remained a premium market compared to other North American locations.

Natural Gas — Natural gas prices decreased for the three months ended March 31, 2024 compared to the three months ended December 31, 2023 driven by growing natural gas production nationally and a surplus of natural gas in storage both nationally as well as in California.

Statements of Operations Analysis

The following table includes key operating data for our oil and gas operations, excluding certain corporate expenses and intercompany eliminations, for the three months ended March 31, 2024 and December 31, 2023. All metrics are shown on a per Boe basis except as otherwise stated. Energy operating costs consist of purchased natural gas used to generate electricity for our operations and steam for our steamfloods, purchased electricity and internal costs to generate electricity used in our operations. Gas processing costs include costs associated with compression, maintenance and other activities needed to run our gas processing facilities at Elk Hills. Non-energy operating costs equal total operating costs less energy operating costs and gas processing costs.


	Three months ended
	March 31, 2024		December 31, 2023

Total net production (MBoe/d)	76		83
Total oil, natural gas and NGL sales (in millions)	$	435	$	483
Energy operating costs	$	8.07	$	8.65
Gas processing costs	0.58		0.60
Non-energy operating costs	17.15		15.24
Operating costs	$	25.80	$	24.49


Field general and administrative expenses(a)	$	1.30	$	1.18
Field depreciation, depletion and amortization(b)	$	7.06	$	6.58
Field taxes other than on income	$	4.61	$	2.63

(a)Excludes unallocated general and administrative expenses.

(b)Excludes depreciation, depletion and amortization related to our corporate assets and our Elk Hills power plant.

Energy operating costs were lower on a per Boe basis during the three months ended March 31, 2024 compared to the three months ended December 31, 2023 where the benefit of lower electricity and natural gas prices was predominately offset by lower production volumes between periods. Non-energy operating costs were higher on a per Boe basis between the three months ended March 31, 2024 compared to the three months ended December 31, 2023 due to lower production volumes between periods.

Consolidated Results of Operations

For financial information related to our subsidiaries designated as Unrestricted Subsidiaries under the Senior Notes Indenture, see Part I, Item 1 – Financial Statements, Note 13 Condensed Consolidated Financial Information.

Certain prior period balances related to NGL marketing activities have been reclassified to conform to our 2024 presentation. For the three months ended December 31, 2023, we reclassified $4 million related to NGL storage activities from other revenue to revenue from marketing of purchased commodities on our condensed consolidated statement of operations. We also reclassified $3 million of NGL processing fees from other operating expenses, net to costs related to marketing of purchased commodities.

Three months ended March 31, 2024 compared to December 31, 2023

The following table presents our consolidated operating revenues for the three months ended March 31, 2024 and December 31, 2023:


	Three months ended
	March 31, 2024		December 31, 2023
	(in millions)
Oil, natural gas and NGL sales	$	429	$	483
Net (loss) gain from commodity derivatives	(71)		119
Revenue from marketing of purchased commodities	74		71
Electricity sales	15		42
Other revenue	7		11
Total operating revenues	$	454	$	726

Oil, natural gas and NGL sales — Oil, natural gas and NGL sales, excluding the effects of cash settlements on our commodity derivative contracts, were $429 million for the three months ended March 31, 2024, which is a decrease of $54 million compared to $483 million for the three months ended December 31, 2023. This decrease was primarily due to lower production volumes and lower realized prices for the first quarter of 2024 as shown in the table below. The effect of cash settlements on our commodity derivative contracts is not included in the table below.


	Oil		NGLs		Natural Gas		Total
	(in millions)
Three months ended December 31, 2023	$	380	$	47	$	56	$	483
Change in realized prices	(9)		1		(9)		(17)
Change in production	(23)		1		(9)		(31)
Change in intercompany sales of natural gas	—		—		(6)		(6)
Three months ended March 31, 2024	$	348	$	49	$	32	$	429

Note: See Production for volumes by commodity type and Prices and Realizations for index and realized prices for comparative periods.

Net (loss) gain from commodity derivatives — Net loss from commodity derivatives was $71 million for the three months ended March 31, 2024 compared to net gain of $119 million for the three months ended December 31, 2023. The net loss from commodity derivatives primarily resulted from changes in the fair value of our outstanding commodity derivatives from the positions held as well as the relationship between contract prices and the associated forward curves at the end of each measurement period.

Payments on commodity derivatives were $12 million for the three months ended March 31, 2024 compared to $49 million for the three months ended December 31, 2023. Including the effect of settlement payments for commodity derivatives, the realized prices received for our oil, natural gas and NGL sales decreased by $17 million compared to the three months ended December 31, 2023.


	Three months ended
	March 31, 2024		December 31, 2023
	(in millions)
Non-cash commodity derivative (loss) gain	$	(59)	$	168


Settlements and premiums	(12)		(49)

Net (loss) gain from commodity derivatives	$	(71)	$	119

Electricity sales — Electricity sales decreased by $27 million to $15 million for the three months ended March 31, 2024 compared to $42 million for the three months ended December 31, 2023 due to downtime at our Elk Hills power plant for planned maintenance and lower electricity prices in the first quarter of 2024.

The following table presents our consolidated operating and non-operating expenses and income for the three months ended March 31, 2024 and December 31, 2023:


	Three months ended
	March 31, 2024		December 31, 2023
	(in millions)
Operating expenses
Energy operating costs	$	53	$	65
Gas processing costs	4		4
Non-energy operating costs	119		117
General and administrative expenses	57		66
Depreciation, depletion and amortization	53		55

Taxes other than on income	38		33
Exploration expense	1		1
Costs related to marketing of purchased commodities	54		42
Electricity generation expenses	8		18
Transportation costs	20		18
Accretion expense	12		11
Carbon management business expenses	8		17
Other operating expenses, net	37		21
Total operating expenses	464		468
Gain on asset divestitures	6		25
Operating (loss) income	(4)		283

Non-operating (expenses) income

Interest and debt expense	(13)		(13)
Loss on early extinguishment of debt	—		(1)
Loss from investment in unconsolidated subsidiary	(3)		(3)
Other non-operating income	1		1
(Loss) income before income taxes	(19)		267
Income tax benefit (provision)	9		(79)
Net (loss) income	$	(10)	$	188

Energy operating costs — Energy operating costs for the three months ended March 31, 2024 were $53 million, which was a decrease of $12 million from $65 million for the three months ended December 31, 2023. This decrease was primarily the result of lower electricity and natural gas prices in the first quarter of 2024. For more information on natural gas market prices, see Prices and Realizations above.

General and administrative expenses — General and administrative (G&A) expenses were $57 million for the three months ended March 31, 2024, which was a decrease of $9 million from $66 million for the three months ended December 31, 2023. The decrease in G&A expenses was primarily attributable to a reduction in compensation-related expenses.

Stock-based compensation awards are granted under our stock-based compensation plans to executives, non-executive employees and non-employee directors that are either settled with shares of our common stock or cash. Our equity-settled awards granted to executives include performance stock units and restricted stock units that either cliff vest at the end of a two- or three-year period or vest ratably over a two- or three-year period. Our equity-settled awards granted to non-employee directors are restricted stock units that vest ratably over a three-year period. Our cash-settled awards granted to non-executive employees vest ratably over a three-year period.

Changes in our stock price introduce volatility in our results of operations because we pay half of our cash-settled awards based on our stock price performance and we adjust our obligation for unvested cash-settled awards at the end of each reporting period. Equity-settled awards are not similarly adjusted for changes in our stock price.

Stock-based compensation included in G&A expense is shown in the table below:


	Three months ended
	March 31, 2024		December 31, 2023
	(in millions)
Cash-settled awards	$	3	$	2
Stock-settled awards	5		6
Total included in general and administrative expenses	$	8	$	8

Costs related to marketing of purchased commodities — Costs related to marketing of purchased commodities were $54 million for the three months ended March 31, 2024 compared to $42 million for the three months ended December 31, 2023. The increase of $12 million was primarily due to higher purchases of third-party crude oil.

Electricity generation expenses — Electricity generation expenses for the three months ended March 31, 2024 were $8 million, which was a decrease of $10 million from $18 million for the three months ended December 31, 2023. This decrease was primarily due to lower variable operating costs due to downtime resulting from scheduled maintenance of our Elk Hills power plant in the first quarter of 2024.

Other operating expenses, net — Other operating expenses, net increased $16 million to $37 million for the three months ended March 31, 2024 compared to $21 million for the three months ended December 31, 2023. The increase was predominately due to additional expenses related to electricity purchased during the scheduled maintenance at our Elk Hills power plant as well as transaction and integration costs related to the Aera Merger.

Income taxes — The income tax benefit for the three months ended March 31, 2024 was $9 million (representing an effective tax rate of 47%), compared to a provision of $79 million (representing an effective tax rate of 30%) for the three months ended December 31, 2023. We recognized an excess tax benefit as a discrete adjustment in the first quarter of 2024 related to the settlement of certain equity-settled stock-based compensation awards. See Part I, Item 1 – Financial Statements, Note 7 Income Taxes for additional information on our effective tax rate.

Liquidity and Capital Resources

Liquidity

Our primary sources of liquidity and capital resources are cash flows from operations, cash and cash equivalents and available borrowing capacity under our Revolving Credit Facility. We consider our low leverage and ability to control costs to be a core strength and strategic advantage, which we are focused on maintaining. Our primary uses of operating cash flow for the three months ended March 31, 2024 were for capital investments, repurchases of our common stock and dividends.

The following table summarizes our liquidity:



	March 31, 2024
	(in millions)
Cash and cash equivalents	$	403
Revolving Credit Facility:
Borrowing capacity	630
Outstanding letters of credit	(153)
Availability	$	477

Liquidity	$	880

We amended our Revolving Credit Facility during the first quarter of 2024 as described in Part I, Item 1 – Financial Statements, Note 4 Debt and continue to evaluate refinancing options for our Senior Notes. In March 2024, we obtained commitments from our existing lenders and certain new lenders to amend our Revolving Credit Facility upon closing of the Aera Merger. These commitments include increasing our borrowing base from $1.2 billion to $1.5 billion, increasing the aggregate commitment amount from $630 million to $1.1 billion and other matters. These commitments are subject to certain conditions prior to becoming effective, including the closing of the Aera Merger.

We intend to undertake certain financing transactions in connection with the Aera Merger. See Part I, Item 1 – Financial Statements, Note 2 Pending Aera Merger. We also intend to pursue financing options for our carbon management business that are separate from the rest of our business.

At current commodity prices and based upon our planned 2024 capital program described below, we expect to generate operating cash flow to support and invest in our core assets and preserve financial flexibility. We regularly review our financial position and evaluate whether to (i) adjust our drilling program, (ii) return available cash to shareholders through dividends or stock buybacks to the extent permitted under our Revolving Credit Facility and Senior Notes indenture, (iii) repurchase outstanding indebtedness, (iv) advance carbon management activities, or (v) maintain cash and cash equivalents on our balance sheet. We believe we have sufficient sources of liquidity to meet our obligations for the next twelve months.

Cash Flow Analysis

Cash flows from operating activities — For the three months ended March 31, 2024, our operating cash flow decreased $223 million to $87 million from $310 million in the same period in 2023. This decrease in operating cash flow was primarily driven by lower natural gas prices in California markets during the first quarter of 2024 compared to 2023. Our average natural gas prices decreased $17.66 per Mcf from $21.56 per MMcf in the three months ended March 31, 2024 to $3.90 per Mcf during the three months ended March 31, 2024. Further, our natural gas production decreased by 31 MMcf/d from 136 MMcf/d in the three months ended March 31, 2023 to 105 MMcf/d in the three months ended March 31, 2024, also contributing to the decrease.

While our realized oil price with derivative settlements increased by $14.13 per barrel to $77.17 in the three months ended March 31, 2024 from $63.04 in the same prior year period, our net oil production volumes decreased 7 MBbl/d from 55 MBbl/d in the three months ended March 31, 2023 to 48 MBbl/d in the three months ended March 31, 2024. Our total net production volumes decreased by 13 MBoe/d from 89 MBoe/d in the three months ended March 31, 2023 to 76 MBoe/d for the three months ended March 31, 2024 primarily due to scheduled plant downtime during the first quarter of 2024, natural production decline and the divestiture of our share of a non-operated field in December 2023. Our PSCs also negatively impacted our net oil production by 1 MBoe/d in the three months ended March 31, 2024 compared to the same prior year period.

Cash flows used in investing activities — The following table provides a comparative summary of net cash used in investing activities:



	Three months ended March 31,
		2024		2023
		(in millions)
Capital investments		$	(54)	$	(47)
Changes in accrued capital investments		(4)		(13)
Proceeds from divestitures, net		10		—



Other, net		(1)		(1)
Net cash used in investing activities		$	(49)	$	(61)

In March 2024, we sold our 0.9-acre Fort Apache real estate property in Huntington Beach, California. For more information on our divestiture in the three months ended March 31, 2024, see Part I, Item 1 – Financial Statements, Note 8 Divestitures and Acquisitions.

Cash flows used in financing activities — The following table provides a comparative summary of net cash used in financing activities:


	Three months ended March 31,
		2024		2023
		(in millions)




Repurchases of common stock(a)		$	(58)	$	(59)
Common stock dividends		(21)		(20)
Payments on equity-settled awards		(4)		—

Issuance of common stock		1		1
Bridge loan commitment and debt amendment costs		(8)		—

Shares cancelled for taxes		(41)		(1)
Net cash used in financing activities		$	(131)	$	(79)

(a)The total value of shares purchased includes approximately $1 million in both the three months ended March 31, 2024 and 2023 related to excise taxes on share repurchases, which was effective beginning on January 1, 2023. Commissions paid on share repurchases were not significant in all periods presented.

A significant number of stock-based compensation awards were settled in the first quarter of 2024. These awards were primarily granted in January 2021 following our emergence from bankruptcy. We withheld shares of common stock to satisfy the tax withholding obligations (shares cancelled for taxes). In addition to the $21 million of dividends paid in the first quarter of 2024, we paid $4 million of dividend equivalents accrued on these stock-based compensation awards.

2024 Capital Program

Our capital program is dynamic in response to commodity price volatility while focusing on oil production and maximizing our free cash flow. Following the Court of Appeals decision in the Kern County EIR matter, we expect our 2024 capital program to range between $200 million and $240 million under current permitting conditions. Of this amount, $165 million to $185 million is related to oil and natural gas development (including $20 million to $25 million for maintenance at one of our gas processing facilities at our Elk Hills field), $20 million to $25 million is for carbon management projects and $15 million to $30 million is for corporate and other (including $10 million to $15 million related to scheduled maintenance at our Elk Hills power plant). We expect to run a one rig program for 2024 executing projects using existing permits. Refer to Regulatory Updates above for more information.

The amounts in the table below reflect components of our capital investment for the periods indicated, excluding changes in capital investment accruals:


		Three months ended March 31, 2024
	(in millions)
Oil and natural gas operations(a)		$	36
Carbon management business		4
Corporate and other(b)		14
Total Capital		$	54

(a)During the three months ended March 31, 2024, we incurred an insignificant amount of costs related to planned maintenance at one of our gas processing facilities at our Elk Hills field.

(b)During the three months ended March 31, 2024, we incurred approximately $13 million related to planned maintenance at our Elk Hills power plant.

Derivatives

Significant changes in oil and natural gas prices may have a material impact on our liquidity. Declining commodity prices negatively affect our operating cash flow, and the inverse applies during periods of rising commodity prices. Our hedging strategy seeks to mitigate our exposure to commodity price volatility and ensure our financial strength and liquidity by protecting our cash flows. We will continue to evaluate our hedging strategy based on prevailing market prices and conditions.

Unless otherwise indicated, we use the term “hedge” to describe derivative instruments that are designed to achieve our hedging requirements and program goals, even though they are not accounted for as cash-flow or fair-value hedges. We did not have any commodity derivatives designated as accounting hedges as of and during the three months ended March 31, 2024. See Part I, Item 1 – Financial Statements, Note 6 Derivatives for further information on our derivatives and a summary of our open derivative contracts as of March 31, 2024 and Part II, Item 8 – Financial Statements and Supplementary Data, Note 4 Debt in our 2023 Annual Report for information on the hedging requirements included in our Revolving Credit Facility.

Dividends

Our Board of Directors declared the following cash dividends in each of the periods presented.


	Total Dividend		Rate Per Share
	(in millions)		($ per share)

Three months ended March 31, 2024	$	21	$	0.31




Three months ended March 31, 2023	$	20	$	0.2825

In addition to dividends declared, we paid $4 million of dividend equivalents related to stock-based compensation awards which were settled in the three months ended March 31, 2024. The declaration of future cash dividends, and the establishment of record and payment dates, is subject to final determination by our Board of Directors each quarter after reviewing our financial performance and position. Since the adoption of our dividend policy in 2021, we have returned $175 million to shareholders through dividends. For information regarding past dividends paid, see Cash Flow Analysis, Cash Flow Used in Financing Activities above.

Share Repurchase Program

Our Board of Directors has authorized a Share Repurchase Program to acquire up to $1.35 billion of our common stock through December 31, 2025. The aggregate value of shares that may yet be purchased under the Share Repurchase Program totaled $691 million, excluding commissions and excise taxes on repurchases, as of March 31, 2024. The repurchases may be effected from time-to-time through open market purchases, privately negotiated transactions, Rule 10b5-1 plans, accelerated stock repurchases, derivative contracts or otherwise in compliance with Rule 10b-18, subject to market conditions and contractual limitations in our debt agreements. The Share Repurchase Program does not obligate us to repurchase any dollar amount or number of shares and our Board of Directors may modify, suspend or discontinue authorization of the program at any time. The following is a summary of our share repurchases, which are held as treasury stock, for the periods presented:


	Total Number of Shares Purchased	Total Value of Shares Purchased		Average Price Paid per Share
	(number of shares)	(in millions)		($ per share)
Three months ended March 31, 2023	1,423,764	$	59	$	41.25
Three months ended March 31, 2024	1,065,764	$	58	$	53.26




Inception of Program (May 2021) through March 31, 2024	15,929,679	$	662	$	41.39

Divestitures and Acquisitions

See Part I, Item 1 – Financial Statements, Note 7 Divestitures and Acquisitions for information on our transactions during the three months ended March 31, 2024 and 2023.

Lawsuits, Claims, Commitments and Contingencies

We accrue reserves for currently outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserve balances at March 31, 2024 and December 31, 2023 were not material to our condensed consolidated balance sheets as of such dates. We also evaluate the amount of reasonably possible losses that we could incur as a result of these matters. We believe that reasonably possible losses that we could incur in excess of reserves cannot be accurately determined.

See Part I, Item 1 – Financial Statements, Note 5 Lawsuits, Claims, Commitments and Contingencies for further information.

Critical Accounting Estimates and Significant Accounting and Disclosure Changes

There have been no changes to our critical accounting estimates, which are summarized in Part II, Item 7 – Management’s Discussion and Analysis of Financial Condition and Results of Operations, Critical Accounting Estimates of our 2023 Annual Report.

Forward-Looking Statements

This document contains statements that we believe to be “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts are forward-looking statements, and include statements regarding our future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and plans and objectives of management for the future. Words such as "expect," “could,” “may,” "anticipate," "intend," "plan," “ability,” "believe," "seek," "see," "will," "would," “estimate,” “forecast,” "target," “guidance,” “outlook,” “opportunity,” “strategy” or similar expressions are generally intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements. Additionally, the information in this report contains forward-looking statements related to the pending Aera Merger.

Although we believe the expectations and forecasts reflected in our forward-looking statements are reasonable, they are inherently subject to numerous risks and uncertainties, most of which are difficult to predict and many of which are beyond our control. No assurance can be given that such forward-looking statements will be correct or achieved, or that the assumptions are accurate or will not change over time. Particular uncertainties that could cause our actual results to be materially different than those expressed in our forward-looking statements include:

•fluctuations in commodity prices, including supply and demand considerations for our products and services;

•decisions as to production levels and/or pricing by OPEC or U.S. producers in future periods;

•government policy, war and political conditions and events, including the military conflicts in Israel, Ukraine and Yemen and the Red Sea;

•the ability to successfully integrate the business of Aera once the Aera merger is completed;

•the timing, receipt and terms and conditions of any required governmental and regulatory approvals of the Aera merger that could reduce anticipated benefits or cause the parties to abandon the Aera merger;

•the occurrence of any event, change or other circumstances that could give rise to the termination of the Merger Agreement;

•the possibility that the stockholders of CRC may not approve the issuance of new shares of common stock in the Aera merger;

•the ability to obtain the required debt financing pursuant to our commitment letters and, if obtained, the potential impact of additional debt on our business and the financial impacts and restrictions due to the additional debt;

•regulatory actions and changes that affect the oil and gas industry generally and us in particular, including (1) the availability or timing of, or conditions imposed on, permits and approvals necessary for drilling or development activities or our carbon management business, (2) the management of energy, water, land, greenhouse gases (GHGs) or other emissions, (3) the protection of health, safety and the environment or (4)

the transportation, marketing and sale of our products;

•the impact of inflation on future expenses and changes generally in the prices of goods and services;

•changes in business strategy and our capital plan;

•lower-than-expected production or higher-than-expected production decline rates;

•changes to our estimates of reserves and related future cash flows, including changes arising from our inability to develop such reserves in a timely manner, and any inability to replace such reserves;

•the recoverability of resources and unexpected geologic conditions;

•general economic conditions and trends, including conditions in the worldwide financial, trade and credit markets;

•production-sharing contracts' effects on production and operating costs;

•the lack of available equipment, service or labor price inflation;

•limitations on transportation or storage capacity and the need to shut-in wells;

•any failure of risk management;

•results from operations and competition in the industries in which we operate;

•our ability to realize the anticipated benefits from prior or future efforts to reduce costs;

•environmental risks and liability under federal, regional, state, provincial, tribal, local and international environmental laws and regulations (including remedial actions);

• the creditworthiness and performance of our counterparties, including financial institutions, operating partners, CCS project participants and other parties;

•reorganization or restructuring of our operations;

•our ability to claim and utilize tax credits or other incentives in connection with our CCS projects and clean energy projects;

•our ability to realize the benefits contemplated by our energy transition strategies and initiatives, including CCS projects and other renewable energy efforts;

•our ability to successfully identify, develop and finance carbon capture and storage projects and other renewable energy efforts, including those in connection with the Carbon TerraVault JV, and our ability to convert our CDMAs to definitive agreements and enter into other offtake agreements;

•our ability to maximize the value of our carbon management business and operate it on a stand-alone basis;

•our ability to successfully develop infrastructure projects and enter into third party contracts on contemplated terms;

•uncertainty around the accounting of emissions and our ability to successfully gather and verify emissions data and other environmental impacts;

•changes to our dividend policy and share repurchase program, and our ability to declare future dividends or repurchase shares under our debt agreements;

•limitations on our financial flexibility due to existing and future debt;

•insufficient cash flow to fund our capital plan and other planned investments and return capital to shareholders;

•changes in interest rates;

•our access to and the terms of credit in commercial banking and capital markets, including our ability to refinance our debt or obtain separate financing for our carbon management business;

•changes in state, federal or international tax rates, including our ability to utilize our net operating loss carryforwards to reduce our income tax obligations;

•effects of hedging transactions;

•the effect of our stock price on costs associated with incentive compensation;

•inability to enter into desirable transactions, including joint ventures, divestitures of oil and natural gas properties and real estate, and acquisitions, and our ability to achieve any expected synergies;

•disruptions due to earthquakes, forest fires, floods, extreme weather events or other natural occurrences, accidents, mechanical failures, power outages, transportation or storage constraints, labor difficulties, cybersecurity breaches or attacks or other catastrophic events;

•pandemics, epidemics, outbreaks, or other public health events, such as the COVID-19 pandemic; and

•other factors discussed in Part I, Item 1A – Risk Factors in our 2023 Annual Report.

We caution you not to place undue reliance on forward-looking statements contained in this document, which speak only as of the filing date, and we undertake no obligation to update this information. This document may also contain information from third party sources. This data may involve a number of assumptions and limitations, and we have not independently verified them and do not warrant the accuracy or completeness of such third-party information.

Item 3Quantitative and Qualitative Disclosures About Market Risk

For the three months ended March 31, 2024, there were no material changes to market risks from the information provided under Item 305 of Regulation S-K included under the caption Part II, Item 7A – Quantitative and Qualitative Disclosures About Market Risk in the 2023 Annual Report.

Commodity Price Risk

Our financial results are sensitive to fluctuations in oil, NGL and natural gas prices. These commodity price changes also impact the volume changes under our PSC-type contracts. We maintain a commodity hedging program primarily focused on hedging crude oil sales to help protect our cash flows, margins and capital program from the volatility of crude oil prices. As of March 31, 2024, we had a net liability of $49 million for our commodity derivative positions which are carried at fair value. For more information on our derivative positions as of March 31, 2024, refer to Part I, Item 1 – Financial Statements, Note 6 Derivatives. We have price exposure for natural gas we purchase and use in our business. We used natural gas to generate electricity for our operations and higher natural gas prices will also result in an increase to our electricity costs.

Counterparty Credit Risk

Our credit risk relates primarily to trade receivables and derivative financial instruments. Credit exposure for each customer is monitored for outstanding balances and current activity. Counterparty credit limits have been established based upon the financial health of our counterparties, and these limits are actively monitored. In the event counterparty credit risk is heightened, we may request collateral and accelerate payment dates. Concentration of credit risk is regularly reviewed to ensure that counterparty credit risk is adequately diversified.

As of March 31, 2024, the majority of our credit exposure was with investment-grade counterparties. We believe exposure to counterparty credit-related losses related to our business at March 31, 2024 was not material and losses associated with counterparty credit risk have been insignificant for all periods presented.

Interest-Rate Risk

Changes in interest rate may affect the amount of interest we pay on our long-term debt. We had no variable-rate debt outstanding as of March 31, 2024. Our Senior Notes bear interest at a fixed rate of 7.125% per annum.

Item 4Controls and Procedures

Our Chief Executive Officer and Chief Financial Officer supervised and participated in management's evaluation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based upon that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that our disclosure controls and procedures were effective as of March 31, 2024.

There were no changes in our internal controls over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) during the three months ended March 31, 2024 that materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.

PART II OTHER INFORMATION

Item 1Legal Proceedings

For additional information regarding legal proceedings, see Item 1 – Financial Statements, Note 5 Lawsuits, Claims, Commitments and Contingencies in the Notes to the Condensed Consolidated Financial Statements included in Part I of this Form 10-Q, Part I, Item 2 – Management's Discussion and Analysis of Financial Condition and Results of Operations, Lawsuits, Claims, Commitments and Contingencies in this Form 10-Q, and Part I, Item 3, Legal Proceedings in our 2023 Annual Report.

Item 1A Risk Factors

We are subject to various risks and uncertainties in the course of our business. A discussion of such risks and uncertainties may be found under the heading Risk Factors in our 2023 Annual Report. There were no material changes to those risk factors during the three months ended March 31, 2024.

Item 2 Unregistered Sales of Equity Securities and Use of Proceeds

Our Board of Directors has authorized a Share Repurchase Program to acquire up to $1.35 billion of our common stock through December 31, 2025. The repurchases may be affected from time-to-time through open market purchases, privately negotiated transactions, Rule 10b5-1 plans, accelerated stock repurchases, derivative contracts or otherwise in compliance with Rule 10b-18, subject to market and contractual limitations in our debt agreements. The Share Repurchase Program does not obligate us to repurchase any dollar amount or number of shares and our Board of Directors may modify, suspend or discontinue authorization of the program at any time. Shares repurchased are held as treasury stock.

Our share repurchase activity for the three months ended March 31, 2024 was as follows:


Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Dollar Value of Shares that May Yet be Purchased Under the Plans or Programs(a)
January 1, 2024 - January 31, 2024	—	$	—	—	$	—
February 1, 2024 - February 29, 2024	—	$	—	—	—
March 1, 2024 - March 31, 2024	1,065,764	$	53.26	1,065,764	—
Total	1,065,764	$	53.26	1,065,764	$	—

(a)The total value of shares that may yet be purchased under the Share Repurchase Program totaled $691 million as of March 31, 2024.

Item 5 Other Disclosures

Rule 10b5-1 Trading Arrangements

During the three months ended March 31, 2024, none of our directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408 of Regulation S-K.

Item 6 Exhibits


3.1			Amended and Restated Certificate of Incorporation of California Resources Corporation (filed as Exhibit 3.1 to Registrant’s Registration Statement on Form 8-A filed October 27, 2020 and incorporated herein by reference).

3.2			Certificate of Amendment of Amended and Restated Certificate of Incorporation of California Resources Corporation (filed as Exhibit 3.1 to Registrant's Current Report on Form 8-K filed on May 6, 2022 and incorporated herein by reference).

3.3			Certificate of Amendment of Amended and Restated Certificate of Incorporation of California Resources Corporation (filed as Exhibit 3.1 to Registrant's Current Report on Form 8-K filed on May 1, 2023 and incorporated herein by reference).

3.4			Amended and Restated Bylaws of California Resources Corporation (filed as Exhibit 3.2 to the Registrant’s Registration Statement on Form 8-A filed October 27, 2020 and incorporated herein by reference).

10.1			Agreement and Plan of Merger, dated February 7, 2024, among California Resources Corporation and Petra Merger Sub I, LLC, Petra Merger Sub C, LLC, Petra Merger Sub O, LLC, Petra Merger Sub O2, LLC, Petra Merger Sub O3, LLC, each a Delaware limited liability company and a wholly-owned direct subsidiary of the Company, Petra Merger Sub S, LLC, a Delaware limited liability company and a wholly-owned direct subsidiary of the Company, IKAV Impact USA Inc., a Delaware corporation, CPPIB Vedder US Holdings LLC, a Delaware limited liability company, Opps Xb Aera E CTB, LLC, a Delaware limited liability company, Opps XI Aera E CTB, LLC, a Delaware limited liability company, Green Gate COI, LLC, a Delaware limited liability company and solely for purposes of the Member Provisions (as defined in the Merger Agreement), IKAV Impact S.a.r.l., a Luxembourg corporation, Simlog Inc., a Delaware corporation, and IKAV Energy Inc., a Delaware corporation, CPP Investment Board Private Holdings (6), Inc., a Canadian corporation, OCM Opps Xb AIF Holdings (Delaware), L.P., a Delaware limited partnership, Oaktree Huntington Investment Fund II AIF (Delaware), L.P. – Class C, a Delaware limited partnership, OCM Opps XI AIV Holdings (Delaware), L.P., a Delaware limited partnership and OCM Aera E Holdings, LLC, a Delaware limited liability company. (filed as Exhibit 10.1 to the Registrant's Current Report on Form 8-K filed February 9, 2024 and incorporated herein by reference).

10.2			Second Amendment to the Amended and Restated Credit Agreement, entered into effective as of February 2, 2024, by and among California Resources Corporation, as the Borrower, the several lenders from time to time parties thereto and Citibank, N.A., as Administrative Agent (filed as Exhibit 10.1 to the Registrant's Current Report on Form 8-K filed February 14, 2024 and incorporated herein by reference).

10.3			T hird Amendment to the Amended and Restated Credit Agreement, entered into effective as of Ma rch 8 , 2024 , by and among California Resources Corporation, as the Borrower , the several lenders from time to time parties thereto and Citibank, N.A., as A dministrative Agent (filed as Exh ibit 10.1 to the R egistrant's Current Report on Form 8-K filed March 11, 2024 and incorporated herein by reference ).

10.4			2024 Form of California Resources Corporation 2021 Long Term Incentive Restricted Stock Unit Award Term and Conditions (filed as Exhibit 10.29 to the Registrant’s Annual Report on Form 10-K filed on February 28, 2024 and incorporated herein by reference).

10.5			2024 Form of California Resources Corporation 2021 Long Term Incentive Plan Performance Stock Unit Award Term and Conditions (filed as Exhibit 10.30 to the Registrant’s Annual Report on Form 10-K filed on February 28, 2024 and incorporated herein by reference).

31.1*			Certification of Principal Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*			Certification of Principal Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1*			Certifications of Principal Executive Officer and Principal Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS*			Inline XBRL Instance Document.

101.SCH*			Inline XBRL Taxonomy Extension Schema Document.

101.CAL*			Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101.LAB*			Inline XBRL Taxonomy Extension Label Linkbase Document.

101.PRE*			Inline XBRL Taxonomy Extension Presentation Linkbase Document.

101.DEF*			Inline XBRL Taxonomy Extension Definition Linkbase Document.

104			Cover Page Interactive Data File (formatted in inline XBRL and contained in Exhibits 101).

* - Filed or furnished herewith

**Certain portions of this exhibit (indicated by "[*****]") have been omitted pursuant to Item 601(b)(10) of Regulation S-K

SIGNATURES

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.


			CALIFORNIA RESOURCES CORPORATION


DATE:	May 8, 2024	/s/ Noelle M. Repetti
		Noelle M. Repetti
		Senior Vice President and Controller
		(Principal Accounting Officer)

EXHIBIT 31.1

RULE 13a – 14(a) / 15d – 14(a)

CERTIFICATION

PURSUANT TO §302 OF THE SARBANES-OXLEY ACT OF 2002

I, Francisco J. Leon, certify that:

1.I have reviewed this quarterly report on Form 10-Q of California Resources Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 8, 2024


			/s/ Francisco J. Leon
			Francisco J. Leon
			President and Chief Executive Officer
			(Principal Executive Officer)

EXHIBIT 31.2

RULE 13a – 14(a) / 15d – 14(a)

CERTIFICATION

PURSUANT TO §302 OF THE SARBANES-OXLEY ACT OF 2002

I, Manuela (Nelly) Molina, certify that:

1.I have reviewed this quarterly report on Form 10-Q of California Resources Corporation;

5.The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 8, 2024

/s/ Manuela (Nelly) Molina

Manuela (Nelly) Molina

Executive Vice President and

Chief Financial Officer

(Principal Financial Officer)

EXHIBIT 32.1

CERTIFICATION OF CEO AND CFO PURSUANT TO

18 U.S.C. § 1350,

AS ADOPTED PURSUANT TO

§ 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of California Resources Corporation (the “Company”) for the fiscal period ended March 31, 2024, as filed with the Securities and Exchange Commission on May 8, 2024 (the “Report”), Francisco J. Leon, as Chief Executive Officer of the Company, and Manuela (Nelly) Molina, as Chief Financial Officer of the Company, each hereby certifies, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that, to the best of his or her knowledge, respectively:

1.The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Francisco J. Leon

Name:

Francisco J. Leon

Title:

President and Chief Executive Officer

(Principal Executive Officer)

Date:

May 8, 2024

/s/ Manuela (Nelly) Molina

Name:

Manuela (Nelly) Molina

Title:

Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

Date:

May 8, 2024

A signed original of this written statement required by Section 906 has been provided to California Resources Corporation and will be retained by California Resources Corporation and furnished to the Securities and Exchange Commission or its staff upon request.

This certification accompanies the Report pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 and shall not, except to the extent required by the Sarbanes-Oxley Act of 2002, be deemed filed by the Company for purposes of Section 18 of the Securities Exchange Act of 1934, as amended.

Cover	3 Months Ended
Cover	Mar. 31, 2024 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2024
Document Transition Report	false
Entity File Number	001-36478
Entity Registrant Name	California Resources Corp
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	46-5670947
Entity Address, Address Line One	1 World Trade Center
Entity Address, Address Line Two	Suite 1500
Entity Address, City or Town	Long Beach
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90831
City Area Code	888
Local Phone Number	848-4754
Title of 12(b) Security	Common Stock
Trading Symbol	CRC
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Bankruptcy Proceedings, Reporting Current	true
Entity Common Stock, Shares Outstanding	68,530,744
Entity Central Index Key	0001609253
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2024
Document Fiscal Period Focus	Q1
Amendment Flag	false

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
CURRENT ASSETS
Cash and cash equivalents	$ 403	$ 496
Trade receivables	192	216
Inventories	70	72
Assets held for sale	13	13
Receivable from affiliate	66	19
Other current assets, net	95	113
Total current assets	839	929
PROPERTY, PLANT AND EQUIPMENT	3,514	3,437
Accumulated depreciation, depletion and amortization	(721)	(667)
Total property, plant and equipment, net	2,793	2,770
INVESTMENT IN UNCONSOLIDATED SUBSIDIARY	16	19
DEFERRED INCOME TAXES	139	132
OTHER NONCURRENT ASSETS	123	148
TOTAL ASSETS	3,910	3,998
CURRENT LIABILITIES
Accounts payable	251	245
Liabilities associated with assets held for sale	5	5
Accrued liabilities	338	366
Total current liabilities	594	616
NONCURRENT LIABILITIES
Long-term debt, net	541	540
Asset retirement obligations	429	422
Other long-term liabilities	253	201
STOCKHOLDERS' EQUITY
Preferred stock (20,000,000 shares authorized at $0.01 par value) no shares outstanding at March 31, 2024 and December 31, 2023	0	0
Common stock (200,000,000 shares authorized at $0.01 par value) (84,460,423 and 83,557,800 shares issued; 68,530,744 and 68,693,885 shares outstanding at March 31, 2024 and December 31, 2023)	1	1
Treasury stock (15,929,679 shares held at cost at March 31, 2024 and 14,863,915 shares held at cost at December 31, 2023)	(662)	(604)
Additional paid-in capital	1,295	1,329
Retained earnings	1,387	1,419
Accumulated other comprehensive income	72	74
Total stockholders' equity	2,093	2,219
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 3,910	$ 3,998

Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2024	Dec. 31, 2023
Statement of Financial Position [Abstract]
Preferred stock, authorized shares (in shares)	20,000,000	20,000,000
Preferred stock, par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock, outstanding shares (in shares)	0	0
Common stock, authorized shares (in shares)	200,000,000	200,000,000
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, issued shares (in shares)	84,460,423	83,557,800
Common stock, outstanding shares (in shares)	68,530,744	68,693,885
Treasury stock (in shares)	15,929,679	14,863,915

Condensed Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
REVENUES
Oil, natural gas and NGL sales	$ 429	$ 715
Net (loss) gain from commodity derivatives	(71)	42
Total operating revenues	454	1,024
OPERATING EXPENSES
Operating costs	176	254
General and administrative expenses	57	65
Depreciation, depletion and amortization	53	58
Asset impairment	0	3
Taxes other than on income	38	42
Exploration expense	1	1
Accretion expense	12	12
Carbon management business expenses	8	5
Other operating expenses, net	37	8
Total operating expenses	464	638
Gain on asset divestitures	6	7
OPERATING (LOSS) INCOME	(4)	393
NON-OPERATING (EXPENSES) INCOME
Interest and debt expense	(13)	(14)
Loss from investment in unconsolidated subsidiary	(3)	(2)
Other non-operating income (loss)	1	(1)
(LOSS) INCOME BEFORE INCOME TAXES	(19)	376
Income tax benefit (provision)	9	(75)
NET (LOSS) INCOME	$ (10)	$ 301
Net (loss) income per share
Basic (in dollars per share)	$ (0.14)	$ 4.22
Diluted (in dollars per share)	$ (0.14)	$ 4.09
Weighted-average common shares outstanding
Basic (in shares)	69.0	71.3
Diluted (in shares)	69.0	73.5
Revenue from marketing of purchased commodities
REVENUES
Revenue not from contract with customer	$ 74	$ 187
OPERATING EXPENSES
Costs of sales	54	124
Electricity sales
REVENUES
Revenue not from contract with customer	15	68
Interest and other revenue
REVENUES
Revenue not from contract with customer	7	12
Electricity generation expenses
OPERATING EXPENSES
Costs of sales	8	49
Transportation costs
OPERATING EXPENSES
Costs of sales	$ 20	$ 17

Condensed Consolidated Statements of Comprehensive (Loss) Income - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2024

Mar. 31, 2023

Statement of Comprehensive Income [Abstract]

NET (LOSS) INCOME

$ (10)

$ 301

Amortization of prior service cost credit included in net periodic benefit cost, net of tax(a)

^[1]

(2)

Comprehensive (loss) income attributable to common stock

$ (12)

$ 301

[1]	(a) Tax effects of the amortization of prior service cost credit were insignificant for the three months ended March 31, 2024.

Condensed Consolidated Statements of Stockholders' Equity - USD ($) $ in Millions	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income
Beginning balance at Dec. 31, 2022	$ 1,864	$ 1	$ (461)	$ 1,305	$ 938	$ 81
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	301				301
Share-based compensation	7			7
Repurchases of common stock	(59)		(59)
Cash dividend	(20)				(20)
Shares cancelled for taxes	(1)			(1)
Ending balance at Mar. 31, 2023	2,092	1	(520)	1,311	1,219	81
Beginning balance at Dec. 31, 2023	2,219	1	(604)	1,329	1,419	74
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(10)				(10)
Share-based compensation	7			7
Repurchases of common stock	(58)		(58)
Cash dividend	(22)				(22)
Shares cancelled for taxes	(41)			(41)
Other comprehensive income, net of tax	(2)					(2)
Ending balance at Mar. 31, 2024	$ 2,093	$ 1	$ (662)	$ 1,295	$ 1,387	$ 72

Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Statement of Stockholders' Equity [Abstract]
Dividends declared, common stock (in dollars per share)	$ 0.31	$ 0.2825

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
CASH FLOW FROM OPERATING ACTIVITIES
Net (loss) income	$ (10)	$ 301
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	53	58
Deferred income tax (benefit) provision	(9)	47
Asset impairment	0	3
Net loss (gain) from commodity derivatives	72	(42)
Net payments on settled commodity derivatives	(14)	(65)
Gain on asset divestitures	(6)	(7)
Other non-cash charges to income, net	6	21
Changes in operating assets and liabilities, net	(5)	(6)
Net cash provided by operating activities	87	310
CASH FLOW FROM INVESTING ACTIVITIES
Capital investments	(54)	(47)
Changes in accrued capital investments	(4)	(13)
Proceeds from asset divestitures, net	10	0
Other, net	(1)	(1)
Net cash used in investing activities	(49)	(61)
CASH FLOW FROM FINANCING ACTIVITIES
Repurchases of common stock	(58)	(59)
Common stock dividends	(21)	(20)
Payments on equity-settled awards	(4)	0
Issuance of common stock	1	1
Bridge loan commitment and debt amendment costs	(8)	0
Shares cancelled for taxes	(41)	(1)
Net cash used in financing activities	(131)	(79)
(Decrease) increase in cash and cash equivalents	(93)	170
Cash and cash equivalents—beginning of period	496	307
Cash and cash equivalents—end of period	$ 403	$ 477

BASIS OF PRESENTATION	3 Months Ended
BASIS OF PRESENTATION	Mar. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
BASIS OF PRESENTATION	BASIS OF PRESENTATION We are an independent oil and natural gas exploration and production and carbon management company operating properties exclusively within California. We are committed to energy transition and have some of the lowest carbon intensity production in the United States. We are in the early stages of permitting several carbon capture and storage (CCS) projects in California. Our carbon management business, which we refer to as Carbon TerraVault, is expected to build, install, operate and maintain CO2 capture equipment, transportation assets and storage facilities in California. In August 2022, we entered into a joint venture with BGTF Sierra Aggregator LLC (Brookfield) to pursue carbon management and storage activities (Carbon TerraVault JV). See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV. Except when the context otherwise requires or where otherwise indicated, all references to ‘‘CRC,’’ the ‘‘Company,’’ ‘‘we,’’ ‘‘us’’ and ‘‘our’’ refer to California Resources Corporation and its subsidiaries. In the opinion of our management, the accompanying unaudited financial statements contain all adjustments necessary to fairly present our financial position, results of operations, comprehensive income, equity and cash flows for all periods presented. We have eliminated all significant intercompany transactions and accounts. We account for our share of oil and natural gas producing activities, in which we have a direct working interest, by reporting our proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on our condensed consolidated financial statements. In applying the equity method of accounting, our investment in an unconsolidated subsidiary (Carbon TerraVault JV HoldCo, LLC) was initially recognized at cost and then adjusted for our proportionate share of income or loss in addition to contributions and distributions. We have prepared this report in accordance with generally accepted accounting principles (GAAP) in the United States and the rules and regulations of the U.S. Securities and Exchange Commission applicable to interim financial information which permit the omission of certain disclosures to the extent they have not changed materially since the latest annual financial statements. We believe our disclosures are adequate to make the information presented not misleading. The preparation of financial statements in conformity with GAAP requires management to select appropriate accounting policies and make informed estimates and judgments regarding certain types of financial statement balances and disclosures. Actual results could differ. Management believes that these estimates and judgments provide a reasonable basis for the fair presentation of our condensed consolidated financial statements. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2023 (2023 Annual Report). The carrying amounts of cash, cash equivalents and on-balance sheet financial instruments, other than debt, approximate fair value. Refer to Note 4 Debt for the fair value of our debt. Certain prior period balances related to natural gas liquid (NGL) marketing activities have been reclassified to conform to our 2024 presentation. For the three months ended March 31, 2023, we reclassified $3 million related to NGL storage activities from other revenue to revenue from marketing of purchased commodities on our condensed consolidated statement of operations.

PENDING AERA MERGER	3 Months Ended
PENDING AERA MERGER	Mar. 31, 2024
Business Combination and Asset Acquisition [Abstract]
PENDING AERA MERGER	PENDING AERA MERGER On February 7, 2024, we entered into a definitive agreement and plan of merger (Merger Agreement) to combine with Aera Energy, LLC (Aera) in an all-stock transaction (Aera Merger) with an effective date of January 1, 2024. Aera is a leading operator of mature fields in California, primarily in the San Joaquin and Ventura basins, with high oil-weighted production. Pursuant to the Merger Agreement, we have agreed to issue 21,170,357 shares of common stock (subject to customary adjustments in the event of stock splits, dividend paid in stock and similar items) plus an additional number of shares determined by reference to the dividends declared by us having a record date between the effective date and closing as more fully described in the Merger Agreement. Upon closing, Aera's $950 million outstanding long-term debt will become due as a result of a change in control provision within their legacy debt agreement. We expect to repay a significant portion of this indebtedness with cash on hand and borrowings under our Revolving Credit Facility. We intend to refinance the balance through one or more debt capital markets transactions and, only to the extent necessary, borrowings under a bridge loan facility provided by Citigroup Global Markets, Inc. (the Bank). Under the terms of our debt commitment letter with the Bank, it has committed, subject to satisfaction of customary conditions, to provide us with an unsecured 364-day bridge loan facility in an aggregate principal amount of $500 million (Bridge Loan Facility). Additionally, we have amended our Revolving Credit Facility as described in Note 4 Debt in connection with the pending Aera Merger. During the three months ended March 31, 2024, we incurred $8 million related to the bridge loan commitment and amending our Revolving Credit Facility which is reported in other current assets, net on our condensed consolidated balance sheet. Closing of the Aera Merger is subject to certain conditions, including, among others, approval of the stock issuance by our stockholders, expiration of the applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended (HSR Act), prior authorization by the Federal Energy Regulatory Commission under Section 203 of the Federal Power Act and other customary closing conditions. The required waiting period under the HSR Act expired on March 25, 2024. Upon completion of the transaction, we currently expect our existing stockholders to own approximately 77% of the combined company and the existing Aera owners to own approximately 23% of the combined company, on a fully diluted basis.

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS

3 Months Ended

Mar. 31, 2024

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS



	March 31,		December 31,
	2024		2023
	(in millions)
Investment in unconsolidated subsidiary(a)	$	16	$	19
Receivable from affiliate(b)	$	66	$	19
Other long-term liabilities - Contingent liability (related to Carbon TerraVault JV put and call rights)	$	99	$	52

(a)Reflects our investment less losses allocated to us of $3 million and $9 million for the three months ended March 31, 2024 and the year ended December 31, 2023, respectively.


	Three months ended March 31,
	2024		2023
	(in millions)
Loss from investment in unconsolidated subsidiary	$	3	$	2
General and administrative expenses(a)	$	2	$	1

DEBT

3 Months Ended

Mar. 31, 2024

Debt Disclosure [Abstract]

DEBT

As of March 31, 2024 and December 31, 2023, our long-term debt consisted of the following:



	March 31,		December 31,
	2024		2023		Interest Rate	Maturity
	(in millions)

Revolving Credit Facility	$	—	$	—	SOFR plus 2.50%-3.50% ABR plus 1.50%-2.50%(a)	July 31, 2027(b)

Senior Notes	545		545		7.125%	February 1, 2026
Principal amount	$	545	$	545
Unamortized debt issuance costs	(4)		(5)
Long-term debt, net	$	541	$	540

(b)The Revolving Credit Facility is subject to a springing maturity to August 4, 2025 if any of our Senior Notes are outstanding on that date.

Fair Value

LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	3 Months Ended
LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	Mar. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES We are involved, in the normal course of business, in lawsuits, environmental and other claims and other contingencies that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties or injunctive or declaratory relief. We accrue reserves for currently outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserve balances for these items at March 31, 2024 and December 31, 2023 were not material to our condensed consolidated balance sheets as of such dates. We also evaluate the amount of reasonably possible losses that we could incur as a result of these matters. We believe that reasonably possible losses that we could incur in excess of reserves cannot be accurately determined. In October 2020, Signal Hill Services, Inc. defaulted on its decommissioning obligations associated with two offshore platforms. The Bureau of Safety and Environmental Enforcement (BSEE) determined that former lessees, including our former parent, Occidental Petroleum Corporation (Oxy) with a 37.5% share, are responsible for accrued decommissioning obligations associated with these offshore platforms. Oxy sold its interest in the platforms approximately 30 years ago and it is our understanding that Oxy has not had any connection to the operations since that time and was challenging BSEE's order. Oxy notified us of the claim under the indemnification provisions of the Separation and Distribution Agreement between us and Oxy. In September 2021, we accepted the indemnification claim from Oxy and are challenging the order from BSEE. In March 2024, we entered into a cost sharing agreement with former lessees to share in ongoing maintenance costs during the pendency of the challenge to the BSEE order. We estimate our ongoing share of maintenance costs for the platforms could approximate $5 million to $8 million per year. Due to the preliminary stage of the process, no cost estimates to abandon the offshore platforms have been determined.

DERIVATIVES

3 Months Ended

Mar. 31, 2024

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVES

Summary of Derivative Contracts

We held the following Brent-based contracts as of March 31, 2024:


	Q2 2024		Q3 2024		Q4 2024		1H 2025		2H 2025
Sold Calls
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	90.07	$	90.07	$	90.07	$	86.88	$	86.90

Purchased Puts
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	65.17	$	65.17	$	65.17	$	61.43	$	61.45

Swaps
Barrels per day	8,875		8,875		5,500		3,500		3,250
Weighted-average price per barrel	$	79.28	$	80.10	$	77.45	$	72.81	$	72.50

The outcomes of the derivative positions are as follows:

•Sold calls – we make settlement payments for prices above the indicated weighted-average price per barrel.

•Purchased puts – we receive settlement payments for prices below the indicated weighted-average price per barrel.

At March 31, 2024, we also held the following swaps to hedge purchased natural gas used in our operations as shown in the table below.


	Q2 2024		Q3 2024		Q4 2024
Swaps:
MMBtu per day	10,000		10,000		10,000
Weighted-average price per MMBtu	$	5.65	$	5.65	$	5.65

Fair Value of Derivatives


	Three months ended March 31,
	2024		2023
(in millions)
Non-cash commodity derivative (loss) gain	$	(59)	$	107


Settlements and premiums	(12)		(65)

Net (loss) gain from commodity derivatives	$	(71)	$	42

The following tables present the fair values of our outstanding commodity derivatives as of March 31, 2024 and December 31, 2023:


March 31, 2024
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	11	$	(11)	$	—
Other noncurrent assets	24		(24)		—

Current liabilities	(46)		11		(35)
Noncurrent liabilities	(38)		24		(14)
	$	(49)	$	—	$	(49)


December 31, 2023
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	39	$	(18)	$	21
Other noncurrent assets	38		(32)		6

Current liabilities	(26)		18		(8)
Noncurrent liabilities	(34)		32		(2)
	$	17	$	—	$	17

INCOME TAXES

3 Months Ended

Mar. 31, 2024

Income Tax Disclosure [Abstract]

INCOME TAXES

The following table presents the components of our total income tax provision:


	Three months ended March 31,
	2024		2023
	(in millions)
(Loss) income before income taxes	$	(19)	$	376

Current income tax provision	—		28
Deferred income tax (benefit) provision	(9)		47
Total income tax (benefit) provision	$	(9)	$	75


	Three months ended March 31,
	2024		2023
U.S federal statutory tax rate	21	%	21	%
State income taxes, net	7		7
Other	3		—
Annual effective tax rate	31	%	28	%
Discrete items:
Stock compensation and other	16		—
Change in the valuation allowance	—		(8)
Effective tax rate	47	%	20	%

DIVESTITURES AND ACQUISITIONS	3 Months Ended
DIVESTITURES AND ACQUISITIONS	Mar. 31, 2024
Acquisitions And Divestitures [Abstract]
DIVESTITURES AND ACQUISITIONS	DIVESTITURES AND ACQUISITIONS Divestitures Fort Apache in Huntington Beach In March 2024, we sold our 0.9-acre Fort Apache real estate property in Huntington Beach, California for a purchase price of $10 million and recognized a $6 million gain. Ventura Basin Transactions During 2021 and 2022, we entered into transactions to sell our Ventura basin assets. The transaction contemplates multiple closings that are subject to customary closing conditions. The closing of the sale of our remaining assets in the Ventura basin is subject to final approval from the State Lands Commission, which we expect could occur in 2024. These remaining assets, consisting of property, plant and equipment, and associated asset retirement obligations are classified as held for sale on our condensed consolidated balance sheets at March 31, 2024 and December 31, 2023. See Part II, Item 8 – Financial Statements and Supplementary Data, Note 8 Divestitures and Acquisitions in our 2023 Annual Report for additional information on the Ventura basin transactions. Other During the three months ended March 31, 2023, we sold a non-producing asset in exchange for the assumption of liabilities, recognizing a $7 million gain related to the liability reduction. Acquisitions In 2022, we acquired properties for carbon management activities for approximately $17 million. We intend to divest a portion of these assets and recorded these assets at fair value recognizing an impairment of $3 million in the first quarter of 2023. The fair value, using Level 3 inputs in the fair value hierarchy, declined during the first quarter of 2023 due to market conditions (including inflation and rising interest rates). The assets being divested are classified as held for sale as of March 31, 2024 on our condensed consolidated balance sheet.

STOCKHOLDERS' EQUITY

3 Months Ended

Mar. 31, 2024

Equity [Abstract]

STOCKHOLDERS' EQUITY

Share Repurchase Program


	Total Number of Shares Purchased	Total Value of Shares Purchased		Average Price Paid per Share
	(number of shares)	(in millions)		($ per share)
Three months ended March 31, 2023	1,423,764	$	59	$	41.25
Three months ended March 31, 2024	1,065,764	$	58	$	53.26




Inception of Program (May 2021) through March 31, 2024	15,929,679	$	662	$	41.39

Dividends

Our Board of Directors declared the following cash dividends for each of the periods presented.


	Total Dividend		Rate Per Share
	(in millions)		($ per share)

Three months ended March 31, 2024	$	21	$	0.31




Three months ended March 31, 2023	$	20	$	0.2825

Warrants

In October 2020, we reserved an aggregate 4,384,182 shares of our common stock for warrants which are exercisable at $36 per share through October 26, 2024.

See Part II, Item 8 – Financial Statements and Supplementary Data, Note 10 Stockholders' Equity in our 2023 Annual Report for additional information on the terms of our warrants.

EARNINGS PER SHARE

3 Months Ended

Mar. 31, 2024

Earnings Per Share [Abstract]

EARNINGS PER SHARE

The following table presents the calculation of basic and diluted EPS, for the three months ended March 31, 2024 and 2023:


	Three months ended March 31,
	2024		2023
	(in millions, except per-share amounts)
Numerator for Basic and Diluted EPS
Net (loss) income	$	(10)	$	301





Denominator for Basic EPS
Weighted-average shares	69.0		71.3

Potential common shares, if dilutive:
Warrants	—		0.5
Restricted stock units	—		0.9
Performance stock units	—		0.8

Denominator for Diluted EPS
Weighted-average shares	69.0		73.5

EPS
Basic	$	(0.14)	$	4.22
Diluted	$	(0.14)	$	4.09

The following table presents potentially dilutive weighted-average common shares which were excluded from the denominator for diluted EPS in periods of losses:


	Three months ended March 31,
	2024	2023
(in millions)
Shares issuable upon exercise of warrants	4.2	—
Shares issuable upon settlement of RSUs	0.9	—
Shares issuable upon settlement of PSUs	1.1	—
Total antidilutive shares	6.2	—

SUPPLEMENTAL ACCOUNT BALANCES

3 Months Ended

Mar. 31, 2024

SUPPLEMENTAL INFORMATION [Abstract]

SUPPLEMENTAL ACCOUNT BALANCES

The following table provides disaggregated revenue for sales of produced oil, natural gas and NGLs to customers:



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	348	$	390
Natural gas	32		263
NGLs	49		62
Oil, natural gas and NGL sales	$	429	$	715



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	20	$	—
Natural gas	48		184
NGLs	6		3
Revenue from marketing of purchased commodities	$	74	$	187



	March 31,		December 31,
	2024		2023
	(in millions)
Materials and supplies	$	68	$	68
Finished goods	2		4
Inventories	$	70	$	72

Other current assets, net — Other current assets, net include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Net amounts due from joint interest partners(a)	$	40	$	43

Fair value of commodity derivative contracts	—		21
Prepaid expenses	29		19
Greenhouse gas allowances	6		12

Income tax receivable	4		—
Other	16		18
Other current assets, net	$	95	$	113

(a)Included in the March 31, 2024 and December 31, 2023 net amounts due from joint interest partners are allowances of $3 million.

Other noncurrent assets — Other noncurrent assets include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Operating lease right-of-use assets	$	85	$	73
Deferred financing costs - Revolving Credit Facility	10		11
Emission reduction credits	11		11
Prepaid power plant maintenance	2		34
Fair value of commodity derivative contracts	—		6
Deposits and other	15		13
Other noncurrent assets	$	123	$	148

Accrued liabilities — Accrued liabilities include the following:


	March 31,		December 31,
	2024		2023
	(in millions)
Employee-related costs	$	48	$	82
Taxes other than on income	50		35
Asset retirement obligations	90		99
Interest	8		18
Operating lease liability	19		15
Fair value of derivative contracts	35		8
Premiums due on commodity derivative contracts	13		21
Liability for settlement payments on commodity derivative contracts	5		8
Amounts due under production-sharing contracts	10		5
Signal Hill maintenance	13		12
Income taxes payable	—		18

Other	47		45
Accrued liabilities	$	338	$	366

Other long-term liabilities — Other long-term liabilities includes the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Compensation-related liabilities	$	33	$	38
Postretirement benefit plan	35		36
Operating lease liability	56		55
Fair value of commodity derivative contracts	14		2
Premiums due on commodity derivative contracts	10		10
Contingent liability (related to Carbon TerraVault JV put and call rights)	99		52
Other	6		8
Other long-term liabilities	$	253	$	201


	Three months ended March 31,
	2024		2023
	(in millions)
Exploration and production, corporate and other	$	55	$	62
Carbon management business	2		3
Total general and administrative expenses	$	57	$	65

SUPPLEMENTAL CASH FLOW INFORMATION	3 Months Ended
SUPPLEMENTAL CASH FLOW INFORMATION	Mar. 31, 2024
Supplemental Cash Flow Elements [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	SUPPLEMENTAL CASH FLOW INFORMATION We made U.S. federal and state income tax payments of $22 million during the three months ended March 31, 2024. We did not make U.S. federal or state income tax payments during the three months ended March 31, 2023. Interest paid, net of capitalized amounts, was $20 million and $21 million for the three months ended March 31, 2024 and 2023, respectively. Interest income was $6 million and $3 million for the three months ended March 31, 2024 and 2023, respectively. Non-cash investing activities in the three months ended March 31, 2023 included $2 million related to our share of capital calls by the Carbon TerraVault JV. See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV. Non-cash financing activities in the three months ended March 31, 2024 included approximately $87 million related to the issuance of shares for our stock-based compensation awards. Non-cash financing activities in the three months ended March 31, 2024 also included approximately $1 million related to dividend equivalents accrued for stock-based compensation awards and approximately $1 million related to an excise tax on share repurchases. Non-cash financing activities in the three months ended March 31, 2023 included an insignificant amount, for dividend equivalents accrued for stock-based compensation awards and approximately $1 million related to an excise tax on share repurchases.

CONDENSED CONSOLIDATING FINANCIAL INFORMATION

3 Months Ended

Mar. 31, 2024

Organization, Consolidation and Presentation of Financial Statements [Abstract]

CONDENSED CONSOLIDATING FINANCIAL INFORMATION

Condensed Consolidating Balance Sheets

As of March 31, 2024 and December 31, 2023


	As of March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	428	$	67	$	344	$	—	$	839
Total property, plant and equipment, net	13		16		2,764		—		2,793
Investments in consolidated subsidiaries	2,358		(17)		1,328		(3,669)		—
Deferred tax asset	139		—		—		—		139
Investment in unconsolidated subsidiary	—		16		—		—		16
Other assets	12		50		61		—		123
TOTAL ASSETS	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910

Total current liabilities	82		15		497		—		$	594
Long-term debt	541		—		—		—		541
Asset retirement obligations	—		—		429		—		429
Other long-term liabilities	71		122		60		—		253
Amounts due to (from) affiliates	163		24		(187)		—		—
Total equity	2,093		(29)		3,698		(3,669)		2,093
TOTAL LIABILITIES AND EQUITY	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910


	As of December 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	511	$	20	$	398	$	—	$	929
Total property, plant and equipment, net	14		12		2,744		—		2,770
Investments in consolidated subsidiaries	2,311		(11)		1,347		(3,647)		—
Deferred tax asset	132		—		—		—		132
Investment in unconsolidated subsidiary	—		19		—		—		19
Other assets	12		36		100		—		148
TOTAL ASSETS	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Total current liabilities	142		13		461		—		$	616
Long-term debt	540		—		—		—		540
Asset retirement obligations	—		—		422		—		422
Other long-term liabilities	79		73		49		—		201

Total equity	2,219		(10)		3,657		(3,647)		2,219
TOTAL LIABILITIES AND EQUITY	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Condensed Consolidating Statement of Operations

For the three months ended March 31, 2024 and 2023


	Three months ended March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	6	$	—	$	457	$	(9)	$	454
Total costs and other	60		10		403		(9)		464
Gain on asset divestitures	—		—		6		—		6
Non-operating (loss) income	(12)		(4)		1		—		(15)
(LOSS) INCOME BEFORE INCOME TAXES	(66)		(14)		61		—		(19)
Income tax benefit	9		—		—		—		9
NET (LOSS) INCOME	$	(57)	$	(14)	$	61	$	—	$	(10)


	Three months ended March 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	4	$	—	$	1,020	$	—	$	1,024
Total costs and other	50		8		580		—		638
Gain on asset divestitures	—		—		7		—		7
Non-operating (loss) income	(15)		(3)		1		—		(17)
(LOSS) INCOME BEFORE INCOME TAXES	(61)		(11)		448		—		376
Income tax provision	(75)		—		—		—		(75)
NET (LOSS) INCOME	$	(136)	$	(11)	$	448	$	—	$	301

SUBSEQUENT EVENTS	3 Months Ended
SUBSEQUENT EVENTS	Mar. 31, 2024
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS Dividend On May 7, 2024, our Board of Directors declared a quarterly cash dividend of $0.31 per share of common stock. The dividend is payable to shareholders of record at the close of business on May 31, 2024 and is expected to be paid on June 14, 2024.

Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended
Pay vs Performance Disclosure - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023
Pay vs Performance Disclosure
NET (LOSS) INCOME	$ (10)	$ 301

Insider Trading Arrangements	3 Months Ended
Insider Trading Arrangements	Mar. 31, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

BASIS OF PRESENTATION (Policies)	3 Months Ended
BASIS OF PRESENTATION (Policies)	Mar. 31, 2024
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation	We are an independent oil and natural gas exploration and production and carbon management company operating properties exclusively within California. We are committed to energy transition and have some of the lowest carbon intensity production in the United States. We are in the early stages of permitting several carbon capture and storage (CCS) projects in California. Our carbon management business, which we refer to as Carbon TerraVault, is expected to build, install, operate and maintain CO2 capture equipment, transportation assets and storage facilities in California. In August 2022, we entered into a joint venture with BGTF Sierra Aggregator LLC (Brookfield) to pursue carbon management and storage activities (Carbon TerraVault JV). See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV. Except when the context otherwise requires or where otherwise indicated, all references to ‘‘CRC,’’ the ‘‘Company,’’ ‘‘we,’’ ‘‘us’’ and ‘‘our’’ refer to California Resources Corporation and its subsidiaries. In the opinion of our management, the accompanying unaudited financial statements contain all adjustments necessary to fairly present our financial position, results of operations, comprehensive income, equity and cash flows for all periods presented. We have eliminated all significant intercompany transactions and accounts. We account for our share of oil and natural gas producing activities, in which we have a direct working interest, by reporting our proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on our condensed consolidated financial statements. In applying the equity method of accounting, our investment in an unconsolidated subsidiary (Carbon TerraVault JV HoldCo, LLC) was initially recognized at cost and then adjusted for our proportionate share of income or loss in addition to contributions and distributions. We have prepared this report in accordance with generally accepted accounting principles (GAAP) in the United States and the rules and regulations of the U.S. Securities and Exchange Commission applicable to interim financial information which permit the omission of certain disclosures to the extent they have not changed materially since the latest annual financial statements. We believe our disclosures are adequate to make the information presented not misleading. The preparation of financial statements in conformity with GAAP requires management to select appropriate accounting policies and make informed estimates and judgments regarding certain types of financial statement balances and disclosures. Actual results could differ. Management believes that these estimates and judgments provide a reasonable basis for the fair presentation of our condensed consolidated financial statements. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto in our Annual Report on Form 10-K for the year ended December 31, 2023 (2023 Annual Report). The carrying amounts of cash, cash equivalents and on-balance sheet financial instruments, other than debt, approximate fair value.

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS (Tables)

3 Months Ended

Mar. 31, 2024

Equity Method Investments and Joint Ventures [Abstract]

Schedule of Equity Method Investment Unconsolidated Subsidiary



	March 31,		December 31,
	2024		2023
	(in millions)
Investment in unconsolidated subsidiary(a)	$	16	$	19
Receivable from affiliate(b)	$	66	$	19
Other long-term liabilities - Contingent liability (related to Carbon TerraVault JV put and call rights)	$	99	$	52

(a)Reflects our investment less losses allocated to us of $3 million and $9 million for the three months ended March 31, 2024 and the year ended December 31, 2023, respectively.


	Three months ended March 31,
	2024		2023
	(in millions)
Loss from investment in unconsolidated subsidiary	$	3	$	2
General and administrative expenses(a)	$	2	$	1

DEBT (Tables)

3 Months Ended

Mar. 31, 2024

Debt Disclosure [Abstract]

Schedule of Long-term Debt

As of March 31, 2024 and December 31, 2023, our long-term debt consisted of the following:



	March 31,		December 31,
	2024		2023		Interest Rate	Maturity
	(in millions)

Revolving Credit Facility	$	—	$	—	SOFR plus 2.50%-3.50% ABR plus 1.50%-2.50%(a)	July 31, 2027(b)

Senior Notes	545		545		7.125%	February 1, 2026
Principal amount	$	545	$	545
Unamortized debt issuance costs	(4)		(5)
Long-term debt, net	$	541	$	540

(b)The Revolving Credit Facility is subject to a springing maturity to August 4, 2025 if any of our Senior Notes are outstanding on that date.

DERIVATIVES (Tables)

3 Months Ended

Mar. 31, 2024

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Open Derivative Contracts

We held the following Brent-based contracts as of March 31, 2024:


	Q2 2024		Q3 2024		Q4 2024		1H 2025		2H 2025
Sold Calls
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	90.07	$	90.07	$	90.07	$	86.88	$	86.90

Purchased Puts
Barrels per day	30,000		30,000		29,000		28,000		27,500
Weighted-average price per barrel	$	65.17	$	65.17	$	65.17	$	61.43	$	61.45

Swaps
Barrels per day	8,875		8,875		5,500		3,500		3,250
Weighted-average price per barrel	$	79.28	$	80.10	$	77.45	$	72.81	$	72.50

At March 31, 2024, we also held the following swaps to hedge purchased natural gas used in our operations as shown in the table below.


	Q2 2024		Q3 2024		Q4 2024
Swaps:
MMBtu per day	10,000		10,000		10,000
Weighted-average price per MMBtu	$	5.65	$	5.65	$	5.65

We report gains and losses on our derivative contracts which hedge commodity price risk related to our oil production and our marketing activities in operating revenue on our consolidated statements of operations as shown in the table below:


	Three months ended March 31,
	2024		2023
(in millions)
Non-cash commodity derivative (loss) gain	$	(59)	$	107


Settlements and premiums	(12)		(65)

Net (loss) gain from commodity derivatives	$	(71)	$	42

Schedule of Fair Value of Derivatives

The following tables present the fair values of our outstanding commodity derivatives as of March 31, 2024 and December 31, 2023:


March 31, 2024
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	11	$	(11)	$	—
Other noncurrent assets	24		(24)		—

Current liabilities	(46)		11		(35)
Noncurrent liabilities	(38)		24		(14)
	$	(49)	$	—	$	(49)


December 31, 2023
Classification	Gross Amounts at Fair Value		Netting		Net Fair Value
	(in millions)
Other current assets, net	$	39	$	(18)	$	21
Other noncurrent assets	38		(32)		6

Current liabilities	(26)		18		(8)
Noncurrent liabilities	(34)		32		(2)
	$	17	$	—	$	17

INCOME TAXES (Tables)

3 Months Ended

Mar. 31, 2024

Income Tax Disclosure [Abstract]

Schedule of Differences Between the U.S. Federal Income Tax Rate and the Company's Effective Tax Rate

The following table presents the components of our total income tax provision:


	Three months ended March 31,
	2024		2023
	(in millions)
(Loss) income before income taxes	$	(19)	$	376

Current income tax provision	—		28
Deferred income tax (benefit) provision	(9)		47
Total income tax (benefit) provision	$	(9)	$	75


	Three months ended March 31,
	2024		2023
U.S federal statutory tax rate	21	%	21	%
State income taxes, net	7		7
Other	3		—
Annual effective tax rate	31	%	28	%
Discrete items:
Stock compensation and other	16		—
Change in the valuation allowance	—		(8)
Effective tax rate	47	%	20	%

STOCKHOLDERS' EQUITY (Tables)

3 Months Ended

Mar. 31, 2024

Equity [Abstract]

Schedule of Shares Repurchased

The following is a summary of our share repurchases, which is held as treasury stock, for the periods presented:


	Total Number of Shares Purchased	Total Value of Shares Purchased		Average Price Paid per Share
	(number of shares)	(in millions)		($ per share)
Three months ended March 31, 2023	1,423,764	$	59	$	41.25
Three months ended March 31, 2024	1,065,764	$	58	$	53.26




Inception of Program (May 2021) through March 31, 2024	15,929,679	$	662	$	41.39

Schedule of Dividends Declared

Our Board of Directors declared the following cash dividends for each of the periods presented.


	Total Dividend		Rate Per Share
	(in millions)		($ per share)

Three months ended March 31, 2024	$	21	$	0.31




Three months ended March 31, 2023	$	20	$	0.2825

EARNINGS PER SHARE (Tables)

3 Months Ended

Mar. 31, 2024

Earnings Per Share [Abstract]

Schedule of Calculation of Basic and Diluted EPS

The following table presents the calculation of basic and diluted EPS, for the three months ended March 31, 2024 and 2023:


	Three months ended March 31,
	2024		2023
	(in millions, except per-share amounts)
Numerator for Basic and Diluted EPS
Net (loss) income	$	(10)	$	301





Denominator for Basic EPS
Weighted-average shares	69.0		71.3

Potential common shares, if dilutive:
Warrants	—		0.5
Restricted stock units	—		0.9
Performance stock units	—		0.8

Denominator for Diluted EPS
Weighted-average shares	69.0		73.5

EPS
Basic	$	(0.14)	$	4.22
Diluted	$	(0.14)	$	4.09

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share

The following table presents potentially dilutive weighted-average common shares which were excluded from the denominator for diluted EPS in periods of losses:


	Three months ended March 31,
	2024	2023
(in millions)
Shares issuable upon exercise of warrants	4.2	—
Shares issuable upon settlement of RSUs	0.9	—
Shares issuable upon settlement of PSUs	1.1	—
Total antidilutive shares	6.2	—

SUPPLEMENTAL ACCOUNT BALANCES (Tables)

3 Months Ended

Mar. 31, 2024

SUPPLEMENTAL INFORMATION [Abstract]

Schedule of Disaggregated Revenue

The following table provides disaggregated revenue for sales of produced oil, natural gas and NGLs to customers:



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	348	$	390
Natural gas	32		263
NGLs	49		62
Oil, natural gas and NGL sales	$	429	$	715



	Three months ended March 31,
	2024		2023
	(in millions)
Oil	$	20	$	—
Natural gas	48		184
NGLs	6		3
Revenue from marketing of purchased commodities	$	74	$	187

Schedule of Inventories

Inventories, by category, are as follows:



	March 31,		December 31,
	2024		2023
	(in millions)
Materials and supplies	$	68	$	68
Finished goods	2		4
Inventories	$	70	$	72

Schedule of Other Current Assets, Net

Other current assets, net include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Net amounts due from joint interest partners(a)	$	40	$	43

Fair value of commodity derivative contracts	—		21
Prepaid expenses	29		19
Greenhouse gas allowances	6		12

Income tax receivable	4		—
Other	16		18
Other current assets, net	$	95	$	113

(a)Included in the March 31, 2024 and December 31, 2023 net amounts due from joint interest partners are allowances of $3 million.

Schedule of Other Noncurrent Assets

Other noncurrent assets include the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Operating lease right-of-use assets	$	85	$	73
Deferred financing costs - Revolving Credit Facility	10		11
Emission reduction credits	11		11
Prepaid power plant maintenance	2		34
Fair value of commodity derivative contracts	—		6
Deposits and other	15		13
Other noncurrent assets	$	123	$	148

Schedule of Accrued Liabilities

Accrued liabilities include the following:


	March 31,		December 31,
	2024		2023
	(in millions)
Employee-related costs	$	48	$	82
Taxes other than on income	50		35
Asset retirement obligations	90		99
Interest	8		18
Operating lease liability	19		15
Fair value of derivative contracts	35		8
Premiums due on commodity derivative contracts	13		21
Liability for settlement payments on commodity derivative contracts	5		8
Amounts due under production-sharing contracts	10		5
Signal Hill maintenance	13		12
Income taxes payable	—		18

Other	47		45
Accrued liabilities	$	338	$	366

Schedule of Other Long-term Liabilities

Other long-term liabilities includes the following:



	March 31,		December 31,
	2024		2023
	(in millions)
Compensation-related liabilities	$	33	$	38
Postretirement benefit plan	35		36
Operating lease liability	56		55
Fair value of commodity derivative contracts	14		2
Premiums due on commodity derivative contracts	10		10
Contingent liability (related to Carbon TerraVault JV put and call rights)	99		52
Other	6		8
Other long-term liabilities	$	253	$	201

Schedule of General and Administrative Expenses

The table below shows G&A expenses for our exploration and production business (including unallocated corporate overhead and other) separately from our carbon management business. The amounts shown for our carbon management business are net of amounts invoiced by us under the MSA with the Carbon TerraVault JV. See Note 3 Investment in Unconsolidated Subsidiary and Related Party Transactions for more information on the Carbon TerraVault JV.


	Three months ended March 31,
	2024		2023
	(in millions)
Exploration and production, corporate and other	$	55	$	62
Carbon management business	2		3
Total general and administrative expenses	$	57	$	65

CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Tables)

3 Months Ended

Mar. 31, 2024

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Condensed Financial Statements

The financial information may not necessarily be indicative of the financial condition and results of operations had the Unrestricted Subsidiaries operated as independent entities.

Condensed Consolidating Balance Sheets

As of March 31, 2024 and December 31, 2023


	As of March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	428	$	67	$	344	$	—	$	839
Total property, plant and equipment, net	13		16		2,764		—		2,793
Investments in consolidated subsidiaries	2,358		(17)		1,328		(3,669)		—
Deferred tax asset	139		—		—		—		139
Investment in unconsolidated subsidiary	—		16		—		—		16
Other assets	12		50		61		—		123
TOTAL ASSETS	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910

Total current liabilities	82		15		497		—		$	594
Long-term debt	541		—		—		—		541
Asset retirement obligations	—		—		429		—		429
Other long-term liabilities	71		122		60		—		253
Amounts due to (from) affiliates	163		24		(187)		—		—
Total equity	2,093		(29)		3,698		(3,669)		2,093
TOTAL LIABILITIES AND EQUITY	$	2,950	$	132	$	4,497	$	(3,669)	$	3,910


	As of December 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total current assets	$	511	$	20	$	398	$	—	$	929
Total property, plant and equipment, net	14		12		2,744		—		2,770
Investments in consolidated subsidiaries	2,311		(11)		1,347		(3,647)		—
Deferred tax asset	132		—		—		—		132
Investment in unconsolidated subsidiary	—		19		—		—		19
Other assets	12		36		100		—		148
TOTAL ASSETS	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Total current liabilities	142		13		461		—		$	616
Long-term debt	540		—		—		—		540
Asset retirement obligations	—		—		422		—		422
Other long-term liabilities	79		73		49		—		201

Total equity	2,219		(10)		3,657		(3,647)		2,219
TOTAL LIABILITIES AND EQUITY	$	2,980	$	76	$	4,589	$	(3,647)	$	3,998

Condensed Consolidating Statement of Operations

For the three months ended March 31, 2024 and 2023


	Three months ended March 31, 2024
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	6	$	—	$	457	$	(9)	$	454
Total costs and other	60		10		403		(9)		464
Gain on asset divestitures	—		—		6		—		6
Non-operating (loss) income	(12)		(4)		1		—		(15)
(LOSS) INCOME BEFORE INCOME TAXES	(66)		(14)		61		—		(19)
Income tax benefit	9		—		—		—		9
NET (LOSS) INCOME	$	(57)	$	(14)	$	61	$	—	$	(10)


	Three months ended March 31, 2023
	Parent		Combined Unrestricted Subsidiaries		Combined Restricted Subsidiaries		Eliminations		Consolidated
	(in millions)
Total revenues	$	4	$	—	$	1,020	$	—	$	1,024
Total costs and other	50		8		580		—		638
Gain on asset divestitures	—		—		7		—		7
Non-operating (loss) income	(15)		(3)		1		—		(17)
(LOSS) INCOME BEFORE INCOME TAXES	(61)		(11)		448		—		376
Income tax provision	(75)		—		—		—		(75)
NET (LOSS) INCOME	$	(136)	$	(11)	$	448	$	—	$	301

BASIS OF PRESENTATION (Details) - USD ($) $ in Millions	3 Months Ended
BASIS OF PRESENTATION (Details) - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023
Interest and other revenue
Reclassification [Line Items]
Revenue not from contract with customer	$ 7	$ 12
Interest and other revenue \| Reclassification adjustment
Reclassification [Line Items]
Revenue not from contract with customer		(3)
Revenue from marketing of purchased commodities
Reclassification [Line Items]
Revenue not from contract with customer	74	$ 187
Revenue from marketing of purchased commodities \| Reclassification adjustment
Reclassification [Line Items]
Revenue not from contract with customer	$ 3

PENDING AERA MERGER (Details) - USD ($) $ in Millions		3 Months Ended
PENDING AERA MERGER (Details) - USD ($) $ in Millions	Feb. 07, 2024	Mar. 31, 2024	Mar. 31, 2023
Business Acquisition [Line Items]
Bridge loan commitment and debt amendment costs		$ 8	$ 0
Bridge Loan Facility \| Line of Credit
Business Acquisition [Line Items]
Term of loan facility	364 days
Line of credit facility, maximum borrowing capacity	$ 500
Bridge loan commitment and debt amendment costs		$ 8
Aera Energy, LLC
Business Acquisition [Line Items]
Long-term indebtedness assumed in connection with merger	$ 950
Ownership percentage as a result of merger	77.00%
Aera Energy, LLC \| Aera Energy, LLC
Business Acquisition [Line Items]
Ownership percentage as a result of merger	23.00%
Aera Energy, LLC \| Common Stock
Business Acquisition [Line Items]
Common stock issued in connection with merger (in shares)	21,170,357

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS - Narrative (Details) MT in Millions, $ in Millions	1 Months Ended		3 Months Ended		12 Months Ended
	Mar. 31, 2024 USD ($)	Aug. 31, 2022 USD ($) installment MT	Mar. 31, 2024 USD ($)	Mar. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2023 USD ($)
Schedule of Equity Method Investments [Line Items]
Contingent liability (related to Carbon TerraVault JV put and call rights)	$ 253		$ 253			$ 201
Related Party
Schedule of Equity Method Investments [Line Items]
Contingent liability (related to Carbon TerraVault JV put and call rights)	99		99			52
Carbon TerraVault JV
Schedule of Equity Method Investments [Line Items]
Interest in joint venture		51.00%
Carbon TerraVault JV \| Related Party
Schedule of Equity Method Investments [Line Items]
Contingent liability (related to Carbon TerraVault JV put and call rights)	99		99			$ 52
Carbon TerraVault JV \| Brookfield
Schedule of Equity Method Investments [Line Items]
Interest in joint venture		49.00%
Committed amount		$ 500
Initial investment		$ 137
Number of installments \| installment		3
Number of installments subject to certain milestones \| installment		2
Contribution from noncontrolling interest	$ 46				$ 46
Metric tons of carbon per annum \| MT		5
Elk Hills
Schedule of Equity Method Investments [Line Items]
Reimbursement for abandonment work			$ 4	$ 1

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS - Equity Method Investment Unconsolidated Subsidiary, Balance Sheet (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated subsidiary	$ 16		$ 19
Receivable from affiliate	66		19
Other long-term liabilities	253		201
Loss from investment in unconsolidated subsidiary	3	$ 2
Related Party
Schedule of Equity Method Investments [Line Items]
Receivable from affiliate	66		19
Other long-term liabilities	99		52
Carbon TerraVault JV
Schedule of Equity Method Investments [Line Items]
Investment in unconsolidated subsidiary	16		19
Loss from investment in unconsolidated subsidiary	3	$ 2	9
Carbon TerraVault JV \| Related Party
Schedule of Equity Method Investments [Line Items]
Receivable from affiliate	66		19
Other long-term liabilities	99		52
Carbon TerraVault JV \| Management Services Agreement
Schedule of Equity Method Investments [Line Items]
Equity method investments, distributed to satisfy future capital calls	63		17
Carbon TerraVault JV \| Management Services Agreement \| Related Party
Schedule of Equity Method Investments [Line Items]
Receivable from affiliate	$ 3		$ 2

INVESTMENT IN UNCONSOLIDATED SUBSIDIARY AND RELATED PARTY TRANSACTIONS - Equity Method Investment Unconsolidated Subsidiary, Income Statement (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Schedule of Equity Method Investments [Line Items]
Loss from investment in unconsolidated subsidiary	$ 3	$ 2
Carbon TerraVault JV
Schedule of Equity Method Investments [Line Items]
Loss from investment in unconsolidated subsidiary	3	2	$ 9
General and administrative expense	$ 2	$ 1

DEBT - Long-Term Debt (Details) - USD ($) $ in Millions		3 Months Ended
DEBT - Long-Term Debt (Details) - USD ($) $ in Millions	Apr. 26, 2023	Mar. 31, 2024	Dec. 31, 2023
Debt
Principal amount		$ 545	$ 545
Unamortized debt issuance costs		(4)	(5)
Long-term debt, net		541	540
Senior Notes (Unsecured)
Debt
Principal amount		$ 545	545
Interest rate		7.125%
Revolving Credit Facility \| Line of Credit
Debt
Principal amount		$ 0	$ 0
Revolving Credit Facility \| Line of Credit \| SOFR
Debt
Interest rate added to variable rate basis	1.00%
Revolving Credit Facility \| Line of Credit \| SOFR \| Minimum
Debt
Interest rate added to variable rate basis		2.50%
Revolving Credit Facility \| Line of Credit \| SOFR \| Maximum
Debt
Interest rate added to variable rate basis		3.50%
Revolving Credit Facility \| Line of Credit \| Alternative Base Rate \| Minimum
Debt
Interest rate added to variable rate basis		1.50%
Revolving Credit Facility \| Line of Credit \| Alternative Base Rate \| Maximum
Debt
Interest rate added to variable rate basis		2.50%
Revolving Credit Facility \| Line of Credit \| Federal Funds Rate
Debt
Interest rate added to variable rate basis	0.50%
Revolving Credit Facility \| Line of Credit \| Credit Spread Adjustment
Debt
Interest rate added to variable rate basis	0.10%
Revolving Credit Facility \| Line of Credit \| ABR Applicable Margin \| Minimum
Debt
Interest rate added to variable rate basis	1.50%
Revolving Credit Facility \| Line of Credit \| ABR Applicable Margin \| Maximum
Debt
Interest rate added to variable rate basis	2.50%
Revolving Credit Facility \| Line of Credit \| Term SOFR Loans, Applicable Margin \| Minimum
Debt
Interest rate added to variable rate basis	2.50%
Revolving Credit Facility \| Line of Credit \| Term SOFR Loans, Applicable Margin \| Maximum
Debt
Interest rate added to variable rate basis	3.50%

DEBT - Revolving Credit Facility - Narrative (Details) - Line of Credit - USD ($) $ in Millions	Mar. 31, 2024	Feb. 28, 2024	Oct. 30, 2023
Revolving Credit Facility
Debt instrument
Line of credit facility, maximum borrowing capacity	$ 630
Line of credit facility, remaining borrowing capacity	477
Borrowing base	1,500	$ 1,200	$ 1,200
Aggregate commitment	1,100	$ 630
Letters of Credit
Debt instrument
Line of credit facility, maximum borrowing capacity	250
Letters of credit issued	$ 153

DEBT - Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Debt Disclosure [Abstract]
Fair value of debt	$ 549	$ 554

LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES - Narrative (Details) $ in Millions	1 Months Ended
	Oct. 31, 2020 platform	Mar. 31, 2024 USD ($)
Other Commitments [Line Items]
Number of offshore platforms with decommissioning obligations defaulted \| platform	2
Offshore platforms with decommissioning obligations defaulted percentage	37.50%
Offshore platforms with decommissioning obligations defaulted period since interest sold	30 years
Minimum
Other Commitments [Line Items]
Estimated share of maintenance costs		$ 5
Maximum
Other Commitments [Line Items]
Estimated share of maintenance costs		$ 8

DERIVATIVES - Commodity Price Risk (Details)	3 Months Ended
DERIVATIVES - Commodity Price Risk (Details)	Mar. 31, 2024 $ / barrel bbl
Q2 2024
Derivatives
Daily volume (in Bbl) \| bbl	10,000
Weighted-average price (in dollars per barrel) \| $ / barrel	5.65
Q3 2024
Derivatives
Daily volume (in Bbl) \| bbl	10,000
Weighted-average price (in dollars per barrel) \| $ / barrel	5.65
Q4 2024
Derivatives
Daily volume (in Bbl) \| bbl	10,000
Weighted-average price (in dollars per barrel) \| $ / barrel	5.65
Crude Oil \| Calls \| Q2 2024
Derivatives
Daily volume (in Bbl) \| bbl	30,000
Weighted-average price (in dollars per barrel) \| $ / barrel	90.07
Crude Oil \| Calls \| Q3 2024
Derivatives
Daily volume (in Bbl) \| bbl	30,000
Weighted-average price (in dollars per barrel) \| $ / barrel	90.07
Crude Oil \| Calls \| Q4 2024
Derivatives
Daily volume (in Bbl) \| bbl	29,000
Weighted-average price (in dollars per barrel) \| $ / barrel	90.07
Crude Oil \| Calls \| 1H 2025
Derivatives
Daily volume (in Bbl) \| bbl	28,000
Weighted-average price (in dollars per barrel) \| $ / barrel	86.88
Crude Oil \| Calls \| 2H 2025
Derivatives
Daily volume (in Bbl) \| bbl	27,500
Weighted-average price (in dollars per barrel) \| $ / barrel	86.90
Crude Oil \| Puts \| Purchased \| Q2 2024
Derivatives
Daily volume (in Bbl) \| bbl	30,000
Weighted-average price (in dollars per barrel) \| $ / barrel	65.17
Crude Oil \| Puts \| Purchased \| Q3 2024
Derivatives
Daily volume (in Bbl) \| bbl	30,000
Weighted-average price (in dollars per barrel) \| $ / barrel	65.17
Crude Oil \| Puts \| Purchased \| Q4 2024
Derivatives
Daily volume (in Bbl) \| bbl	29,000
Weighted-average price (in dollars per barrel) \| $ / barrel	65.17
Crude Oil \| Puts \| Purchased \| 1H 2025
Derivatives
Daily volume (in Bbl) \| bbl	28,000
Weighted-average price (in dollars per barrel) \| $ / barrel	61.43
Crude Oil \| Puts \| Purchased \| 2H 2025
Derivatives
Daily volume (in Bbl) \| bbl	27,500
Weighted-average price (in dollars per barrel) \| $ / barrel	61.45
Crude Oil \| Swaps \| Q2 2024
Derivatives
Daily volume (in Bbl) \| bbl	8,875
Weighted-average price (in dollars per barrel) \| $ / barrel	79.28
Crude Oil \| Swaps \| Q3 2024
Derivatives
Daily volume (in Bbl) \| bbl	8,875
Weighted-average price (in dollars per barrel) \| $ / barrel	80.10
Crude Oil \| Swaps \| Q4 2024
Derivatives
Daily volume (in Bbl) \| bbl	5,500
Weighted-average price (in dollars per barrel) \| $ / barrel	77.45
Crude Oil \| Swaps \| 1H 2025
Derivatives
Daily volume (in Bbl) \| bbl	3,500
Weighted-average price (in dollars per barrel) \| $ / barrel	72.81
Crude Oil \| Swaps \| 2H 2025
Derivatives
Daily volume (in Bbl) \| bbl	3,250
Weighted-average price (in dollars per barrel) \| $ / barrel	72.50

DERIVATIVES - Schedule of Gain (Loss) On Derivative Contracts (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Non-cash commodity derivative gain (loss)	$ (59)	$ 107
Settlements and amortized premiums	(12)	(65)
Net (loss) gain from commodity derivatives	$ (71)	$ 42

DERIVATIVES - Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Fair Value of Derivatives
Derivative Liability, Statement of Financial Position [Extensible Enumeration]	Total current liabilities	Total current liabilities
Commodity Contracts
Fair Value of Derivatives
Total derivatives	$ 0	$ 0
Commodity Contracts \| Other current assets, net
Fair Value of Derivatives
Netting	(11)	(18)
Commodity Contracts \| Other noncurrent assets
Fair Value of Derivatives
Netting	(24)	(32)
Commodity Contracts \| Current liabilities
Fair Value of Derivatives
Netting	11	18
Commodity Contracts \| Noncurrent liabilities
Fair Value of Derivatives
Netting	24	32
Gross Amounts at Fair Value \| Commodity Contracts
Fair Value of Derivatives
Total derivatives	(49)	17
Gross Amounts at Fair Value \| Commodity Contracts \| Other current assets, net
Fair Value of Derivatives
Gross Amounts at Fair Value	11	39
Gross Amounts at Fair Value \| Commodity Contracts \| Other noncurrent assets
Fair Value of Derivatives
Gross Amounts at Fair Value	24	38
Gross Amounts at Fair Value \| Commodity Contracts \| Current liabilities
Fair Value of Derivatives
Gross Amounts at Fair Value	(46)	(26)
Gross Amounts at Fair Value \| Commodity Contracts \| Noncurrent liabilities
Fair Value of Derivatives
Gross Amounts at Fair Value	(38)	(34)
Net Fair Value \| Commodity Contracts
Fair Value of Derivatives
Total derivatives	(49)	17
Net Fair Value \| Commodity Contracts \| Other current assets, net
Fair Value of Derivatives
Net Fair Value	0	21
Net Fair Value \| Commodity Contracts \| Other noncurrent assets
Fair Value of Derivatives
Net Fair Value	0	6
Net Fair Value \| Commodity Contracts \| Current liabilities
Fair Value of Derivatives
Net Fair Value	(35)	(8)
Net Fair Value \| Commodity Contracts \| Noncurrent liabilities
Fair Value of Derivatives
Net Fair Value	$ (14)	$ (2)

DERIVATIVES - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
DERIVATIVES - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2024	Mar. 31, 2023
Derivatives
Non-cash commodity derivative gain (loss)	$ 59	$ (107)
Net (loss) gain from commodity derivatives	(71)	42
Settlements and amortized premiums	12	$ 65
Natural Gas
Derivatives
Non-cash commodity derivative gain (loss)	1
Net (loss) gain from commodity derivatives	1
Settlements and amortized premiums	$ 2

INCOME TAXES - Income Tax Provision (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Income Tax Disclosure [Abstract]
(Loss) income before income taxes	$ (19)	$ 376
Current income tax provision	0	28
Deferred income tax (benefit) provision	(9)	47
Total income tax (benefit) provision	$ (9)	$ 75

INCOME TAXES - Income Tax Expense (Benefit) (Details)	3 Months Ended
INCOME TAXES - Income Tax Expense (Benefit) (Details)	Mar. 31, 2024	Mar. 31, 2023
Total income tax expense (benefit) differs from the U.S. federal income tax rate to pre-tax income (loss)
U.S federal statutory tax rate	21.00%	21.00%
State income taxes, net	7.00%	7.00%
Other	3.00%	0.00%
Annual effective tax rate	31.00%	28.00%
Stock compensation and other	16.00%	0.00%
Change in the valuation allowance	0.00%	(8.00%)
Effective tax rate	47.00%	20.00%

INCOME TAXES - Narrative (Details)	3 Months Ended
INCOME TAXES - Narrative (Details)	Mar. 31, 2024	Mar. 31, 2023
Income Tax Disclosure [Abstract]
Effective tax rate	31.00%	28.00%
U.S federal statutory tax rate	21.00%	21.00%
Stock compensation and other	16.00%	0.00%

DIVESTITURES AND ACQUISITIONS - Narrative (Details) $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Mar. 31, 2024 USD ($) a	Mar. 31, 2024 USD ($)	Mar. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Business Acquisition [Line Items]
Proceeds from asset divestitures, net		$ 10	$ 0
Gain on asset divestitures		$ 6	7
Other Acquisitions
Business Acquisition [Line Items]
Business combination, consideration transferred				$ 17
Impairment recognized			3
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Other Divestitures
Business Acquisition [Line Items]
Gain on asset divestitures			$ 7
Disposal Group, Disposed of by Sale, Not Discontinued Operations \| Fort Apache In Huntington Beach
Business Acquisition [Line Items]
Number of acres sold \| a	0.9
Proceeds from asset divestitures, net	$ 10
Gain on asset divestitures	$ 6

STOCKHOLDERS' EQUITY - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Oct. 31, 2020
Equity [Abstract]
Stock repurchase program authorized amount	$ 1,350
Payments on equity-settled awards	$ 4	$ 0
Shares reserved for future issuance (in shares)			4,384,182
Investment warrants, exercise price (in dollars per share)			$ 36
Warrant outstanding (in shares)	4,163,670
Shares issued in exchange for warrants (in shares)	18,851

STOCKHOLDERS' EQUITY - Share Repurchases (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		35 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Mar. 31, 2024
Equity [Abstract]
Share repurchase (in shares)	1,065,764	1,423,764	15,929,679
Stock repurchase	$ 58	$ 59	$ 662
Average price (in dollar per share)	$ 53.26	$ 41.25	$ 41.39
Stock repurchase, excise tax	$ 1	$ 1

STOCKHOLDERS' EQUITY - Dividends Declared (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Equity [Abstract]
Total Dividend	$ 21	$ 20
Rate per share (in dollars per share)	$ 0.31	$ 0.2825

EARNINGS PER SHARE - Calculation of EPS (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Numerator for Basic and Diluted EPS
NET (LOSS) INCOME	$ (10)	$ 301
Denominator for Basic EPS
Weighted-average common shares outstanding — basic (in shares)	69.0	71.3
Weighted-average common shares outstanding — diluted (in shares)	69.0	73.5
EPS
Basic (in dollars per share)	$ (0.14)	$ 4.22
Diluted (in dollars per share)	$ (0.14)	$ 4.09
Warrants
Potential common shares, if dilutive:
Incremental common shares attributable to dilutive effect of share-based payment arrangements (in shares)	0.0	0.5
Restricted stock units
Potential common shares, if dilutive:
Incremental common shares attributable to dilutive effect of share-based payment arrangements (in shares)	0.0	0.9
Performance stock units
Potential common shares, if dilutive:
Incremental common shares attributable to dilutive effect of share-based payment arrangements (in shares)	0.0	0.8

EARNINGS PER SHARE - Potentially Dilutive Common Shares (Details) - shares	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total antidilutive shares (in shares)	6,200,000	0
Warrants
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total antidilutive shares (in shares)	4,200,000	0
Restricted stock units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total antidilutive shares (in shares)	900,000	0
Performance stock units
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Total antidilutive shares (in shares)	1,100,000	0

SUPPLEMENTAL ACCOUNT BALANCES - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Disaggregation of revenue
Oil, natural gas and NGL sales	$ 429	$ 715
Oil
Disaggregation of revenue
Oil, natural gas and NGL sales	348	390
Revenue not from contract with customer	20	0
Natural gas
Disaggregation of revenue
Oil, natural gas and NGL sales	32	263
Revenue not from contract with customer	48	184
NGLs
Disaggregation of revenue
Oil, natural gas and NGL sales	49	62
Revenue not from contract with customer	6	3
Revenue from marketing of purchased commodities
Disaggregation of revenue
Revenue not from contract with customer	$ 74	$ 187

SUPPLEMENTAL ACCOUNT BALANCES - Inventories (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
SUPPLEMENTAL INFORMATION [Abstract]
Materials and supplies	$ 68	$ 68
Finished goods	2	4
Inventories	$ 70	$ 72

SUPPLEMENTAL ACCOUNT BALANCES - Other Current Assets (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Supplemental Information [Line Items]
Fair value of commodity derivative contracts	$ 0	$ 21
Prepaid expenses	29	19
Greenhouse gas allowances	6	12
Income tax receivable	4	0
Other	16	18
Other current assets, net	95	113
Due from joint interest partners, allowances	3	3
Joint Interest Partners
Supplemental Information [Line Items]
Other current assets, net	40	43
Nonrelated Party
Supplemental Information [Line Items]
Other current assets, net	$ 95	$ 113

SUPPLEMENTAL ACCOUNT BALANCES - Other Noncurrent Assets (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
SUPPLEMENTAL INFORMATION [Abstract]
Operating lease right-of-use assets	$ 85	$ 73
Deferred financing costs - Revolving Credit Facility	10	11
Emission reduction credits	11	11
Prepaid power plant maintenance	2	34
Fair value of commodity derivative contracts	0	6
Deposits and other	15	13
Other noncurrent assets	$ 123	$ 148

SUPPLEMENTAL ACCOUNT BALANCES - Accrued Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Accrued liabilities current [abstract]
Employee-related costs	$ 48	$ 82
Taxes other than on income	50	35
Asset retirement obligations	90	99
Interest	8	18
Operating lease liability	19	15
Fair value of derivative contracts	35	8
Premiums due on commodity derivative contracts	13	21
Liability for settlement payments on commodity derivative contracts	5	8
Amounts due under production-sharing contracts	10	5
Signal Hill maintenance	13	12
Income taxes payable	0	18
Other	47	45
Accrued liabilities	$ 338	$ 366

SUPPLEMENTAL ACCOUNT BALANCES - Other Long-Term Liabilities (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Supplemental Information [Line Items]
Compensation-related liabilities	$ 33	$ 38
Postretirement benefit plan	35	36
Operating lease liability	56	55
Fair value of commodity derivative contracts	14	2
Premiums due on commodity derivative contracts	10	10
Contingent liability (related to Carbon TerraVault JV put and call rights)	253	201
Other	6	8
Related Party
Supplemental Information [Line Items]
Contingent liability (related to Carbon TerraVault JV put and call rights)	99	52
Nonrelated Party
Supplemental Information [Line Items]
Contingent liability (related to Carbon TerraVault JV put and call rights)	$ 253	$ 201

SUPPLEMENTAL ACCOUNT BALANCES - General and Administrative Expenses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Supplemental Information [Line Items]
General and administrative expenses	$ 57	$ 65
Exploration and production, corporate and other
Supplemental Information [Line Items]
General and administrative expenses	55	62
Carbon management business
Supplemental Information [Line Items]
General and administrative expenses	$ 2	$ 3

SUPPLEMENTAL ACCOUNT BALANCES - Other Operating Expenses, Net (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Supplemental Information [Line Items]
General and administrative expenses	$ 57	$ 65
Exploration and production, corporate and other
Supplemental Information [Line Items]
General and administrative expenses	55	62
Carbon management business
Supplemental Information [Line Items]
General and administrative expenses	$ 2	$ 3

SUPPLEMENTAL CASH FLOW INFORMATION - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Supplemental Cash Flow Elements [Line Items]
Taxes paid	$ 22	$ 0
Interest paid, net of capitalized amounts	20	21
Interest income	6	3
Issuance of shares	87
Dividends accrued for stock-based compensation awards	1
Excise tax on share repurchases	$ 1	1
Carbon TerraVault JV
Supplemental Cash Flow Elements [Line Items]
Non-cash investing activities, capital call		$ 2

CONDENSED CONSOLIDATING FINANCIAL INFORMATION - Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023	Mar. 31, 2023	Dec. 31, 2022
ScheduleOfCondensedFinancialStatements [Line Items]
Total current assets	$ 839	$ 929
Total property, plant and equipment, net	2,793	2,770
Investments in consolidated subsidiaries	0	0
Deferred tax asset	139	132
Investment in unconsolidated subsidiary	16	19
Other assets	123	148
TOTAL ASSETS	3,910	3,998
Total current liabilities	594	616
Long-term debt	541	540
Asset retirement obligations	429	422
Other long-term liabilities	253	201
Amounts due to (from) affiliates	0
Total equity	2,093	2,219	$ 2,092	$ 1,864
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	3,910	3,998
Eliminations
ScheduleOfCondensedFinancialStatements [Line Items]
Total current assets	0	0
Total property, plant and equipment, net	0	0
Investments in consolidated subsidiaries	(3,669)	(3,647)
Deferred tax asset	0	0
Investment in unconsolidated subsidiary	0	0
Other assets	0	0
TOTAL ASSETS	(3,669)	(3,647)
Total current liabilities	0	0
Long-term debt	0	0
Asset retirement obligations	0	0
Other long-term liabilities	0	0
Amounts due to (from) affiliates	0
Total equity	(3,669)	(3,647)
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	(3,669)	(3,647)
Parent \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total current assets	428	511
Total property, plant and equipment, net	13	14
Investments in consolidated subsidiaries	2,358	2,311
Deferred tax asset	139	132
Investment in unconsolidated subsidiary	0	0
Other assets	12	12
TOTAL ASSETS	2,950	2,980
Total current liabilities	82	142
Long-term debt	541	540
Asset retirement obligations	0	0
Other long-term liabilities	71	79
Amounts due to (from) affiliates	163
Total equity	2,093	2,219
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	2,950	2,980
Combined Unrestricted Subsidiaries \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total current assets	67	20
Total property, plant and equipment, net	16	12
Investments in consolidated subsidiaries	(17)	(11)
Deferred tax asset	0	0
Investment in unconsolidated subsidiary	16	19
Other assets	50	36
TOTAL ASSETS	132	76
Total current liabilities	15	13
Long-term debt	0	0
Asset retirement obligations	0	0
Other long-term liabilities	122	73
Amounts due to (from) affiliates	24
Total equity	(29)	(10)
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	132	76
Combined Restricted Subsidiaries \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total current assets	344	398
Total property, plant and equipment, net	2,764	2,744
Investments in consolidated subsidiaries	1,328	1,347
Deferred tax asset	0	0
Investment in unconsolidated subsidiary	0	0
Other assets	61	100
TOTAL ASSETS	4,497	4,589
Total current liabilities	497	461
Long-term debt	0	0
Asset retirement obligations	429	422
Other long-term liabilities	60	49
Amounts due to (from) affiliates	(187)
Total equity	3,698	3,657
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 4,497	$ 4,589

CONDENSED CONSOLIDATING FINANCIAL INFORMATION - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
ScheduleOfCondensedFinancialStatements [Line Items]
Total revenues	$ 454	$ 1,024
Total costs and other	464	638
Gain on asset divestitures	6	7
Non-operating (loss) income	(15)	(17)
(LOSS) INCOME BEFORE INCOME TAXES	(19)	376
Income tax provision	(9)	75
NET (LOSS) INCOME	(10)	301
Eliminations
ScheduleOfCondensedFinancialStatements [Line Items]
Total revenues	(9)	0
Total costs and other	(9)	0
Gain on asset divestitures	0	0
Non-operating (loss) income	0	0
(LOSS) INCOME BEFORE INCOME TAXES	0	0
Income tax provision	0	0
NET (LOSS) INCOME	0	0
Parent \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total revenues	6	4
Total costs and other	60	50
Gain on asset divestitures	0	0
Non-operating (loss) income	(12)	(15)
(LOSS) INCOME BEFORE INCOME TAXES	(66)	(61)
Income tax provision	(9)	75
NET (LOSS) INCOME	(57)	(136)
Combined Unrestricted Subsidiaries \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total revenues	0	0
Total costs and other	10	8
Gain on asset divestitures	0	0
Non-operating (loss) income	(4)	(3)
(LOSS) INCOME BEFORE INCOME TAXES	(14)	(11)
Income tax provision	0	0
NET (LOSS) INCOME	(14)	(11)
Combined Restricted Subsidiaries \| Reportable Legal Entities
ScheduleOfCondensedFinancialStatements [Line Items]
Total revenues	457	1,020
Total costs and other	403	580
Gain on asset divestitures	6	7
Non-operating (loss) income	1	1
(LOSS) INCOME BEFORE INCOME TAXES	61	448
Income tax provision	0	0
NET (LOSS) INCOME	$ 61	$ 448

SUBSEQUENT EVENTS - Narrative (Details) - $ / shares		3 Months Ended
SUBSEQUENT EVENTS - Narrative (Details) - $ / shares	May 07, 2024	Mar. 31, 2024	Mar. 31, 2023
Subsequent Event [Line Items]
Dividends declared, common stock (in dollars per share)		$ 0.31	$ 0.2825
Subsequent Event
Subsequent Event [Line Items]
Dividends declared, common stock (in dollars per share)	$ 0.31

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CRCQW California Resources Corporation (PK)