California Resources Corp

Condensed Consolidated Balance Sheets

As of March 31, 2026 and December 31, 2025

(in millions, except share data)

Condensed Consolidated Statements of Operations (unaudited)

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

Condensed Consolidated Statements of Comprehensive (Loss) Income (unaudited)

(a) Tax effects of the amortization of prior service cost credit were insignificant for the three months ended March 31, 2026 and 2025.

Condensed Consolidated Statements of Stockholders' Equity (unaudited)

Condensed Consolidated Statements of Cash Flows (unaudited)

Notes to the Condensed Consolidated Financial Statements (Unaudited)

March 31, 2026

NOTE 1 BASIS OF PRESENTATION

We are an independent energy and carbon management company advancing the energy transition. We are committed to environmental stewardship while safely providing local, responsibly sourced energy. We are also focused on maximizing the value of our land, mineral ownership, and energy expertise for decarbonization by developing carbon capture and storage (CCS) and other emissions-reducing projects.

On December 18, 2025, pursuant to the Agreement and Plan of Merger, dated as of September 14, 2025 (the Berry Merger Agreement), we obtained all of the ownership interests in Berry Corporation (bry) (Berry) in an all-stock transaction (Berry Merger). Our consolidated results of operations for the three months ended March 31, 2026 include the full-quarter results of Berry, while the comparable prior-year period does not include any results of Berry. Accordingly, the Berry Merger significantly impacts the comparability of our financial results for the three months ended March 31, 2026 as compared to the same period in 2025. See Note 2, Business Combination, for additional information.

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 as of the date presented.

In the opinion of our management, the accompanying unaudited condensed consolidated 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 investments in our unconsolidated subsidiaries are initially recognized either at cost, as is the case with Carbon TerraVault JV HoldCo, LLC, or at fair value if acquired in a business combination, as was the case for Midway Sunset Cogeneration Company. These investments are 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, 2025 (2025 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.

Recently Issued but not Adopted Accounting and Disclosure Changes

In November 2024, the FASB issued new disclosure requirements to enhance disclosure of certain costs and expenses. The rules are effective for fiscal years beginning after December 15, 2026 and interim periods beginning after December 15, 2027, early adoption is permitted. We expect that the adoption of these rules will impact our disclosures and have no impact to our results of operations, cash flows and financial condition.

NOTE 2 BUSINESS COMBINATION

Berry Merger

On September 14, 2025, we entered into an agreement to combine with Berry in the Berry Merger. Berry was an independent upstream energy company that explored for and produced oil and natural gas in California, primarily in the San Joaquin basin, and in the Uinta basin in Utah. Berry also provided well servicing and abandonment services, which is included in our oil and natural gas segment. The Berry Merger added high quality, oil-weighted, mostly conventional proved developed reserves and sustainable cash flows to our operations.

Pursuant to the Berry Merger Agreement, on the effective date of the merger, December 18, 2025, we issued 5,572,115 shares of our common stock, which was calculated as 0.0718 shares of our common stock for each outstanding share of Berry stock as of December 17, 2025. As of December 18, 2025, and immediately following the closing of the Berry Merger, the former Berry stockholders owned 6% of CRC. We paid cash or issued replacement equity awards in settlement of certain Berry restricted and performance units. Upon closing of the Berry Merger, Berry's outstanding debt was repaid and the underlying credit agreements were terminated. We repaid a significant portion of this indebtedness with proceeds from our 2034 Senior Notes. For more information on the 2034 Senior Notes, refer to Note 4 Debt.

At the date of this filing, our assessment of the fair value of assets acquired and liabilities assumed remains preliminary. Certain data necessary to complete the purchase price allocation is not yet available, and includes, but is not limited to, final appraisals of Berry's property, plant and equipment, evaluation of Berry's materials and supplies inventory, valuation of certain assets and liabilities, determination of Berry's asset retirement obligations and preparation of tax returns that will provide underlying tax basis of the assets acquired and liabilities assumed.

We expect to complete the purchase price allocation during the 12-month period subsequent to the Berry Merger closing date and adjustments may be made to the provisional amounts recorded as of March 31, 2026.

We measured assets and liabilities at acquisition date fair value on a nonrecurring basis.

The following table summarizes the consideration transferred:

The following table presents the preliminary purchase price allocation to the identifiable assets acquired and the liabilities assumed based on their estimated fair values as of the closing date of the Berry Merger:

Supplemental Unaudited Pro Forma Financial Information

The following supplemental unaudited pro forma financial information presents the total operating revenue, net income and earnings per share for the three months ended March 31, 2025 as if the Berry Merger had occurred on January 1, 2025.

The pro forma information is presented for illustration purposes only and is not necessarily indicative of the operating results that would have occurred had the Berry Merger been completed on January 1, 2025, nor is it necessarily indicative of future operating results of the combined entity. The pro forma financial information for the three months ended March 31, 2025 is a result of combining our three months statements of operations with Berry's pre-merger results for the three months ended March 31, 2025 and the pro forma adjustments include estimates and assumptions based on currently available information. The pro forma results do not reflect any cost savings anticipated as a result of the Berry Merger and exclude the impact of any severance. The pro forma results include adjustments to depreciation, depletion and amortization (DD&A) based on the purchase price allocated to property, plant, and equipment and the estimated useful lives as well as adjustments to interest and accretion expense. We also included pro forma adjustments for certain compensation-related costs and transaction costs we incurred related to the Berry Merger. Management believes the estimates and assumptions are reasonable, and the relative effects of the Berry Merger are properly reflected. Future results may vary significantly from the results reflected in the following pro forma information.

NOTE 3 INVESTMENT IN UNCONSOLIDATED SUBSIDIARIES AND RELATED PARTY TRANSACTIONS

As of March 31, 2026 and December 31, 2025, our investments in unconsolidated subsidiaries was$102 million and$111 million, respectively. The following tables present changes to our investment in unconsolidated subsidiaries for the periods presented:

Carbon TerraVault JV

In August 2022, we entered into a joint venture with BGTF Sierra Aggregator LLC (Brookfield) for the further development of a carbon management business in California (Carbon TerraVault JV). We hold a 51% interest in the Carbon TerraVault JV and Brookfield holds a 49% interest. The Carbon TerraVault JV holds rights to inject CO 2 into the 26R reservoir in our Elk Hills field for permanent CO 2 storage (26R reservoir). Brookfield has contributed $92 million to date. The remaining amount of Brookfield's initial investment is based on the permitted storage capacity, subject to certain contractual adjustments. This remaining amount will be contributed to the joint venture upon entering into contracts for the injection of specified volumes with respect to the 26R reservoir.

Although we determined that the Carbon TerraVault JV is a variable interest entity (VIE), 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.

Because the parties have certain put and call rights (repurchase features) with respect to the 26R reservoir if certain milestones are not met, 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$120 million at March 31, 2026 and$117 million at December 31, 2025, inclusive of interest. The amount payable to Brookfield under the put and call rights, if exercised, includes additional capital contributions made by Brookfield to develop the 26R storage reservoir, inclusive of interest. This payment would differ from the contingent liability currently recognized because the contingent liability reported in other long-term liabilities on our condensed consolidated balance sheet relates solely to the initial investment by Brookfield and does not include capital contributions made for ongoing development activities of the 26R reservoir.

The table below presents the summarized financial information related to our equity method investment in the Carbon TerraVault JV (and does 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.

(a)At March 31, 2026, the amount of $7 million includes the remaining $4 million of Brookfield's first and second installments of their initial investment which is available to us and $3 million related to the Master Service Agreement (MSA) and vendor reimbursements. At December 31, 2025, the amount of $14 million includes $8 million remaining of Brookfield's first and second installment of their initial investment which is available to us and $6 million related to the MSA and vendor reimbursements.

(b)Other long-term liabilities include the contingent liability related to the Carbon TerraVault JV put and call rights.

We recognized a loss of $1 million for both the three months ended March 31, 2026 and 2025 related to our investment in the Carbon TerraVault JV.

We are also performing well abandonment work at our Elk Hills field to prepare our 26R reservoir for injection of CO 2. During the three months ended March 31, 2026 and 2025, we performed well abandonment work and sought reimbursement for an insignificant amount and $2 million, respectively, from the Carbon TerraVault JV. We recorded these reimbursements as a reduction to property, plant and equipment, net on our condensed consolidated balance sheets.

Midway Sunset Cogeneration Company

The Aera Merger led to our partial ownership of Midway Sunset Cogeneration Company, which is a partnership designed to own, manage, and operate a cogeneration facility in Kern County, California. We hold a 50% interest in Midway Sunset Cogeneration Company and an affiliate of Middle River Power, LLC (MRP), holds a 50% interest. We determined that Midway Sunset Cogeneration Company is a voting interest entity, where we share decision-making power with MRP on all matters that most significantly impact the economic performance of Midway Sunset Cogeneration Company. Therefore, we account for our investment in Midway Sunset Cogeneration Company under the equity method of accounting. There are no significant transactions between us and Midway Sunset Cogeneration Company.

In the three months ended March 31, 2026, we received a distribution of $10 million from the Midway Sunset Cogeneration Company.

NOTE 4 DEBT

As of March 31, 2026 and December 31, 2025, our long-term debt consisted of the following:

(a)Refer to Note 15 Subsequent Events for more information on a recent amendment to the Revolving Credit Facility that reduced our interest rate pricing by 25 basis points and an additional 10 basis point incremental savings through the elimination of the SOFR credit spread adjustment.

Revolving Credit Facility

Our Amended and Restated Credit Agreement, dated April 26, 2023 (Revolving Credit Facility), consists of a senior revolving loan facility with an aggregate commitment of $1.46 billion. The amount we are able to borrow under our Revolving Credit Facility is limited to the amount of these commitments. Our Revolving Credit Facility also includes a sub-limit of $300 million for the issuance of letters of credit. As of March 31, 2026, $184 million letters of credit were issued to support ordinary course marketing, insurance, regulatory and other matters. As of March 31, 2026, we had $1,251 million of availability on our Revolving Credit Facility after taking into account $184 million in letters of credit outstanding and a $25 million borrowing. Our borrowing base of $1.5 billion is redetermined semi-annually and was re-affirmed in April 2026 as part of our recent amendment. See Note 15 Subsequent Events for more information on a recent amendment to our Revolving Credit Facility.

Fair Value

As shown in the table below, we estimate the fair value of our fixed rate 2029 Senior Notes and 2034 Senior Notes based on known prices from market transactions (using Level 1 inputs on the fair value hierarchy).

2034 Senior Notes and Follow-On Offering

On October 8, 2025 we completed a private offering of $400 million in an aggregate principal amount of 7.000% senior notes due 2034 (2034 Senior Notes). The terms of the 2034 Senior Notes are governed by the Indenture, dated as of October 8, 2025, by and among us, the guarantors and Wilmington Trust, National Association, as trustee, as amended and supplemented by the First Supplemental Indenture, dated as of January 16, 2026 (2034 Senior Notes Indenture).

On March 23, 2026, we completed a follow-on offering of an additional $350 million in aggregate principal of 2034 Senior Notes. The net proceeds from this offering of $347 million, after $2 million of debt premium and $5 million of debt issuance costs, were used to redeem a portion of our 8.250% senior unsecured notes due 2029 (2029 Senior Notes). The 2034 Senior Notes issued on March 23, 2026 are governed under the 2034 Senior Notes Indenture.

2029 Senior Notes Redemption

In March 2026, we redeemed $350 million in face value of our 2029 Senior Notes for $367 million, resulting in a loss on extinguishment of debt in the amount of $21 million, which includes a $17 million premium paid and $4 million write-off of unamortized debt issuance costs. Following the redemption, $550 million in principal amount of the 2029 Senior Notes remained outstanding.

Other

As of March 31, 2026, we were in compliance with all financial and other debt covenants under our Revolving Credit Facility, 2029 Senior Notes and 2034 Senior Notes.

NOTE 5 LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES

We are party to various legal and/or regulatory proceedings from time to time arising in the ordinary course of business. We accrue reserves for currently outstanding lawsuits, claims and proceedings when we determine it is probable that a liability has been incurred and the liability can be reasonably estimated. Reserve balances for these items at March 31, 2026 and December 31, 2025 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 withtwo 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 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. In September 2025, the parties amended the cost sharing agreement to include well abandonment work. As of March 31, 2026, we had a liability of approximately $18 million included in accrued liabilities in our condensed consolidated balance sheet related to this abandonment work. For the three months ended March 31, 2026, other operating expenses, net on our condensed consolidated statement of operations includes $10 million, for our ongoing share of maintenance costs and well abandonment work. We continue to challenge the BSEE order.

In 2023 and 2024, the California Geologic Energy Management Division (CalGEM) plugged and abandoned approximately 120 "orphaned" oil and gas wells located in Cat Canyon, Santa Barbara County, at an aggregate cost of approximately $25 million. A subsidiary of our predecessor entity sold these wells to the defunct operator prior to CRC's formation and are therefore in our chain of title. CalGEM is seeking to recover these costs from us due to our prior operatorship of the wells, and we are disputing these claims. In connection with this dispute, we were required to remit approximately $25 million to CalGEM under protest pending the outcome of this matter. We have filed a complaint against CalGEM to reclaim the $25 million that we paid in June 2025.

NOTE 6 DERIVATIVES

We enter into commodity derivative contracts to help protect our cash flows, margins and capital program from the volatility of commodity prices. We primarily hedge a portion of our forecasted oil production and a portion of our purchased natural gas used in our steamflood operations. We did not have any derivative instruments designated as accounting hedges as of and for the three months ended March 31, 2026 and 2025. 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 for our forecasted oil production as of March 31, 2026:

At March 31, 2026, we also held the following swaps to hedge purchased natural gas used in our operations as shown in the table below.

In the three months ended March 31, 2026, we also had a limited number of derivative contracts related to our natural gas marketing activities that were intended to lock in locational price spreads. These derivative contracts were not significant to our results of operations or financial statements taken as a whole.

The outcomes of the derivative positions shown in the tables above 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 – with respect to swaps for crude oil, 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. With respect to swaps for purchased natural gas, we receive settlement payments for prices above the indicated weighted-average price per MMBtu and we make settlement payments for prices below the weighted-average price per MMBtu.

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 related to our oil production and our marketing activities in operating revenue on our consolidated statements of operations as shown in the table below:

We report gains and losses on our commodity derivative contracts related to purchases of natural gas in operating expenses on our condensed consolidated statements of operations as shown in the table below:

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, 2026 and December 31, 2025.

NOTE 7 INCOME TAXES

The following table presents the components of our income tax (benefit) provision and effective tax rate:

Our income tax (benefit) provision 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. Our annual effective tax rate for the three months ended March 31, 2026 differed from the U.S. statutory rate of 21% primarily due to nondeductible compensation and tax credits. For the three months ended March 31, 2025, the difference between the U.S. statutory rate of 21% and our effective tax rate is primarily due to state taxes.

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 SEGMENT INFORMATION

We conduct our business primarily throughtwo reportable segments: (1) oil and natural gas and (2) carbon management. We identified these segments based on the nature of their activities, the types of products sold and services to be provided. Our oil and natural gas segment explores for, develops, and produces oil and condensate, natural gas liquids and natural gas. Our carbon management segment, that we refer to as Carbon TerraVault, is primarily expected to build, install, operate and maintain CO 2 capture equipment, transportation assets and storage facilities. Our oil and natural gas segment operates assets located in California and Utah. Our carbon management segment operates exclusively in California.

Revenues related to sales of produced natural gas to our Elk Hills power plant are included in oil, natural gas and natural gas liquids sales in the table below. Direct labor-related costs are allocated to our reportable segments based on job function and activity. General and administrative expenses are allocated to a segment if they directly support a segment's activities. We do not allocate income taxes to our segments. We use proportionate consolidation to account for our share of oil and natural gas producing activities.

The following tables provide segment profit or loss and reconciliations of segment profit or loss to total operating revenues and consolidated income before income taxes for the three months ended March 31, 2026 and 2025.

(a)Other revenues and income includes net loss from commodity derivatives, revenue from marketing of purchased commodities, electricity sales and unallocated interest and other revenue.

(a)Other segment expenses for our oil and natural gas segment includes transportation costs, accretion expense, and other operating expenses, net. Other segment expenses for our carbon management segment primarily includes operating lease costs. Other segment expenses for Corporate/Eliminations/Other includes transportation costs from marketing activities, severance as well as merger and integration costs that are not allocated to a segment.

(a)Other revenues and income includes net gain from commodity derivatives, revenue from marketing of purchased commodities, electricity revenue and unallocated interest and other revenue.

(a)Other segment expenses for our oil and natural gas segment includes transportation costs, accretion expense, and other operating expenses, net. Other segment expenses for our carbon management segment primarily includes operating lease costs. Other segment expenses for Corporate/Eliminations/Other includes transportation costs from marketing activities and other operating expenses, net that are not allocated to a segment.

The following table provides capital investment by segment and a reconciliation to our consolidated capital investment for the three months ended March 31, 2026 and 2025. We do not provide total assets by segment because it is not used by our Chief Operating Decision Maker. See Note 3 Investment in Unconsolidated Subsidiaries and Related Party Transactions for information on our investment in the Carbon TerraVault JV, which is part of our carbon management segment.

NOTE 9 STOCKHOLDERS' EQUITY

Share Repurchase Program

Our Board of Directors authorized a Share Repurchase Program to acquire up to $1.78 billion of our common stock through December 31, 2027. The total value of shares that may yet be purchased under the Share Repurchase Program totaled $600 million as of March 31, 2026. 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 table summarizes our share repurchases, for the periods presented.

Note: The total value of shares purchased includes accrued excise taxes, which are generally paid in the year following the share repurchase. 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.

In addition to dividends on our common stock shown in the table above, we paid$2 million of dividend equivalents on equity-settled stock-based compensation awards in thethree months ended March 31, 2026 and$1 million of dividend equivalents in the three months ended March 31, 2025. 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 15 Subsequent Events for information on future cash dividends.

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, 2026 and 2025. 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, 2026 and 2025:

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

NOTE 11 PENSION AND POSTRETIREMENT BENEFIT PLANS

The following table sets forth the components of the net periodic benefit costs for our defined benefit pension and postretirement benefit plans for the three months ended March 31, 2026 and 2025:

Contributions to our pension benefit plans were insignificant during thethree months ended March 31, 2026 and the three months ended March 31, 2025. We do not expect to need to make any contributions to our qualified pension plans to satisfy minimum funding requirements during the remainder of 2026. We expect to contribute an insignificant amount to fund our non-qualified pension benefit distributions during the remainder of 2026.

NOTE 12 SUPPLEMENTAL ACCOUNT BALANCES

Restricted cash — Cash and cash equivalents includes restricted cash of $15 million at both March 31, 2026 and December 31, 2025. Restricted cash primarily includes funds held in an escrow account established to secure oil field well and infrastructure abandonment and habitat restoration at an oil and gas field previously owned by Aera. The Aera Merger Agreement provides that 50% of the amount of released funds exceeding the cumulative abandonment and habitat restoration expenditures from January 1, 2024 onward is payable to the prior owners of Aera. We do not expect this return of excess cash to be significant.

Revenues — We derive most of our revenue from sales of oil, natural gas and natural gas liquids, with the remaining revenue primarily generated from sales of electricity and revenue from resource adequacy contracts in addition to revenue from marketing activities related to storage and managing excess pipeline capacity. The following table provides disaggregated revenue for sales of produced oil, natural gas and natural gas liquids to customers:

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 statements 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 marketing oil sales that have resulted from third-party purchases. The following table provides disaggregated revenue for sales to customers related to our marketing activities:

Inventory — Materials and supplies, which primarily consist of well equipment and tubular goods used in our oil and natural gas operations and critical spares related to our cogeneration power plants, are valued at weighted-average cost and are reviewed periodically for obsolescence. Finished goods include produced oil and natural gas liquids in storage, which are valued at the lower of cost or net realizable value. Inventory, by category, is as follows:

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

(a)The amounts due from joint interest partners include $1 million and $2 million of allowances for credit losses for the three months ended March 31, 2026 and 2025, respectively.

Other noncurrent assets —Other noncurrent assets include the following:

Accrued liabilities —Accrued liabilities include the following:

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

(a) See Note 3 Investment in Unconsolidated Subsidiaries and Related Party Transactions for information on the contingent liability related to the Carbon TerraVault JV.

NOTE 13 SUPPLEMENTAL CASH FLOW INFORMATION

Supplemental disclosures to our condensed consolidated statements of cash flows are presented below:

NOTE 14 CONDENSED CONSOLIDATING FINANCIAL INFORMATION

We have designated certain of our subsidiaries as Unrestricted Subsidiaries under the indenture governing our 2029 Senior Notes (2029 Senior Notes Indenture) and 2034 Senior Notes (2034 Senior Notes Indenture). Unrestricted Subsidiaries (as defined in the 2029 Senior Notes Indenture and 2034 Senior Notes Indenture) are subject to fewer restrictions under the indentures. We are required under the 2029 Senior Notes Indenture and 2034 Senior Notes Indenture to present the financial condition and results of operations of CRC and its Restricted Subsidiaries (as defined in the 2029 Senior Notes Indenture and 2034 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, 2026 and December 31, 2025 and the condensed consolidating statements of operations for the three months ended March 31, 2026 and 2025, as applicable, reflect the condensed consolidating financial information of 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. In the three months ended March 31, 2026, we adjusted the Unrestricted Subsidiaries under the 2029 Senior Notes Indenture and the 2034 Senior Notes Indenture. The Unrestricted Subsidiaries and Restricted Subsidiaries for prior periods have not been conformed to the current presentation.

Condensed Consolidating Balance Sheets

As of March 31, 2026 and December 31, 2025

Condensed Consolidating Statement of Operations

NOTE 15 SUBSEQUENT EVENTS

Ninth Amendment to the Revolving Credit Facility

On April 14, 2026, we entered into the ninth amendment to our Revolving Credit Facility to, among other things, amend the pricing grid to reduce interest margin by 0.25%, remove the 0.10% Term SOFR adjustment, and other technical amendments. Our borrowing base of $1.5 billion was reaffirmed as part of this amendment.

Dividend

On May 5, 2026, our Board of Directors declared a quarterly cash dividend of $0.4050 per share of common stock. The dividend is payable to shareholders of record at the close of business on May 29, 2026 and is expected to be paid on June 18, 2026.