California Resources Corp (CRC)
SIC breadcrumb: Mining > SIC Major Group 13 > SIC 1311 Crude Petroleum & Natural Gas
SEC company page: https://www.sec.gov/edgar/browse/?CIK=1609253. Latest filing source: 0001609253-26-000051.
Selected Fundamentals
| Metric | Value | Unit | FY | Filed |
|---|---|---|---|---|
| Revenue | 3,669,000,000 | USD | 2025 | 2026-03-02 |
| Net income | 363,000,000 | USD | 2025 | 2026-03-02 |
| Assets | 7,403,000,000 | USD | 2025 | 2026-03-02 |
Financials
Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-03-02. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001609253.json. Derived margins are computed from the extracted annual SEC facts.
| Metric | 2014 | 2015 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Revenue | 1,547,000,000 | 2,006,000,000 | 3,064,000,000 | 2,634,000,000 | 1,889,000,000 | 2,707,000,000 | 2,801,000,000 | 3,198,000,000 | 3,669,000,000 | |||
| Net income | 279,000,000 | -266,000,000 | 328,000,000 | -28,000,000 | 1,889,000,000 | 612,000,000 | 524,000,000 | 564,000,000 | 376,000,000 | 363,000,000 | ||
| Operating income | -293,000,000 | 73,000,000 | 769,000,000 | 429,000,000 | -1,779,000,000 | 293,000,000 | 812,000,000 | 808,000,000 | 620,000,000 | 598,000,000 | ||
| Diluted EPS | 6.76 | -6.26 | 6.77 | -0.57 | 40.42 | 7.37 | 6.75 | 7.78 | 4.62 | 4.15 | ||
| Assets | 6,354,000,000 | 6,207,000,000 | 7,158,000,000 | 6,958,000,000 | 3,288,000,000 | 3,846,000,000 | 3,967,000,000 | 3,998,000,000 | 7,135,000,000 | 7,403,000,000 | ||
| Stockholders' equity | -557,000,000 | -814,000,000 | -361,000,000 | -389,000,000 | 1,269,000,000 | 1,688,000,000 | 1,864,000,000 | 2,219,000,000 | 3,538,000,000 | 3,674,000,000 | ||
| Cash and cash equivalents | 14,000,000 | 12,000,000 | 12,000,000 | 20,000,000 | 203,000,000 | 305,000,000 | 307,000,000 | 496,000,000 | 372,000,000 | 132,000,000 | ||
| Net margin | 18.03% | -13.26% | 10.70% | -1.06% | 32.40% | 19.36% | 20.14% | 11.76% | 9.89% | |||
| Operating margin | -18.94% | 3.64% | 25.10% | 16.29% | 15.51% | 30.00% | 28.85% | 19.39% | 16.30% |
Financial Charts
Quarterly
Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-05-06. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0001609253.json.
| Quarter | End Date | Revenue | Net Income | Diluted EPS | Method |
|---|---|---|---|---|---|
| 2022-Q2 | 2022-06-30 | 2.41 | reported discrete quarter | ||
| 2022-Q3 | 2022-09-30 | 5.58 | reported discrete quarter | ||
| 2023-Q1 | 2023-03-31 | 4.09 | reported discrete quarter | ||
| 2023-Q2 | 2023-06-30 | 591,000,000 | 97,000,000 | 1.35 | reported discrete quarter |
| 2023-Q3 | 2023-09-30 | 460,000,000 | -22,000,000 | -0.32 | reported discrete quarter |
| 2023-Q4 | 2023-12-31 | 726,000,000 | 188,000,000 | derived Q4 = FY annual - nine-month YTD | |
| 2024-Q1 | 2024-03-31 | 454,000,000 | -10,000,000 | -0.14 | reported discrete quarter |
| 2024-Q2 | 2024-06-30 | 514,000,000 | 8,000,000 | 0.11 | reported discrete quarter |
| 2024-Q3 | 2024-09-30 | 1,353,000,000 | 345,000,000 | 3.78 | reported discrete quarter |
| 2024-Q4 | 2024-12-31 | 877,000,000 | 33,000,000 | derived Q4 = FY annual - nine-month YTD | |
| 2025-Q1 | 2025-03-31 | 912,000,000 | 115,000,000 | 1.26 | reported discrete quarter |
| 2025-Q2 | 2025-06-30 | 978,000,000 | 172,000,000 | 1.92 | reported discrete quarter |
| 2025-Q3 | 2025-09-30 | 855,000,000 | 64,000,000 | 0.76 | reported discrete quarter |
| 2025-Q4 | 2025-12-31 | 924,000,000 | 12,000,000 | derived Q4 = FY annual - nine-month YTD | |
| 2026-Q1 | 2026-03-31 | 119,000,000 | -711,000,000 | -8.02 | reported discrete quarter |
Quarterly Charts
Macro Cross-References
- CPIAUCSL - Consumer Price Index for All Urban Consumers: All Items in U.S. City Average
- UNRATE - Unemployment Rate
- FEDFUNDS - Federal Funds Effective Rate
- CES0500000003 - Average Hourly Earnings of All Employees, Total Private
- DFEDTARU - Federal Funds Target Range - Upper Limit
- DFEDTARL - Federal Funds Target Range - Lower Limit
- DGS3MO - Market Yield on U.S. Treasury Securities at 3-Month Constant Maturity
- DGS2 - Market Yield on U.S. Treasury Securities at 2-Year Constant Maturity
- DGS10 - Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity
- DGS30 - Market Yield on U.S. Treasury Securities at 30-Year Constant Maturity
- T10Y2Y - 10-Year Treasury Constant Maturity Minus 2-Year Treasury Constant Maturity
- CPILFESL - Consumer Price Index for All Urban Consumers: All Items Less Food and Energy
- CPIUFDSL - Consumer Price Index for All Urban Consumers: Food
- CPIENGSL - Consumer Price Index for All Urban Consumers: Energy
- CUSR0000SAH1 - Consumer Price Index for All Urban Consumers: Shelter
- PCEPI - Personal Consumption Expenditures: Chain-type Price Index
- PCEPILFE - Personal Consumption Expenditures Excluding Food and Energy: Chain-type Price Index
- PPIACO - Producer Price Index by Commodity: All Commodities
- T10YIE - 10-Year Breakeven Inflation Rate
- U6RATE - Total Unemployed, Plus All Marginally Attached Workers Plus Total Employed Part Time for Economic Reasons
- PAYEMS - All Employees, Total Nonfarm
- CIVPART - Labor Force Participation Rate
- EMRATIO - Employment-Population Ratio
- UNEMPLOY - Unemployed
- CE16OV - Employment Level
- ICSA - Initial Claims
- JTSJOL - Job Openings: Total Nonfarm
- JTSQUR - Quits: Total Nonfarm
- GDPC1 - Real Gross Domestic Product
- A191RL1Q225SBEA - Real Gross Domestic Product: Percent Change from Preceding Period
- INDPRO - Industrial Production: Total Index
- TCU - Capacity Utilization: Total Index
- HOUST - New Privately-Owned Housing Units Started: Total Units
- PERMIT - New Privately-Owned Housing Units Authorized in Permit-Issuing Places: Total Units
- RSAFS - Advance Retail Sales: Retail Trade
- PCE - Personal Consumption Expenditures
- DSPIC96 - Real Disposable Personal Income
- PSAVERT - Personal Saving Rate
- M2SL - M2
- BOPGSTB - U.S. International Trade in Goods and Services: Balance
- MSPUS - Median Sales Price of Houses Sold for the United States
- HSN1F - New One Family Houses Sold: United States
- RHORUSQ156N - Homeownership Rate in the United States
- TTLCONS - Total Construction Spending: Total Construction in the United States
- RRVRUSQ156N - Rental Vacancy Rate in the United States
- TOTALSL - Total Consumer Credit Owned and Securitized
- REVOLSL - Revolving Consumer Credit Owned and Securitized
- DRCCLACBS - Delinquency Rate on Credit Card Loans, All Commercial Banks
- GDP - Gross Domestic Product
- GPDI - Gross Private Domestic Investment
- GCE - Government Consumption Expenditures and Gross Investment
- PCEC - Personal Consumption Expenditures
- NETEXP - Net Exports of Goods and Services
- GFDEBTN - Federal Debt: Total Public Debt
- GFDEGDQ188S - Federal Debt: Total Public Debt as Percent of Gross Domestic Product
- FYFSD - Federal Surplus or Deficit
- FGRECPT - Federal Government Current Receipts
- FGEXPND - Federal Government: Current Expenditures
- MANEMP - All Employees, Manufacturing
- USCONS - All Employees, Construction
- USTRADE - All Employees, Retail Trade
- USFIRE - All Employees, Financial Activities
- USGOVT - All Employees, Government
- AWHAETP - Average Weekly Hours of All Employees, Total Private
- DGORDER - Manufacturers' New Orders: Durable Goods
- NEWORDER - Manufacturers' New Orders: Nondefense Capital Goods Excluding Aircraft
- BUSINV - Total Business Inventories
- EXPGS - Exports of Goods and Services
- IMPGS - Imports of Goods and Services
- IR - Import Price Index (End Use): All Commodities
- PPIFIS - Producer Price Index by Commodity: Final Demand
Latest quarter (10-Q)
Latest 10-Q source: 0001609253-26-000106.
Item 2Management’s Discussion and Analysis of Financial Condition and Results of Operations General 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. 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 consolidated subsidiaries as of the date presented. Business Environment and Industry Outlook Commodity Prices Our operating results, and those of the oil and natural gas industry, are heavily influenced by commodity prices. Oil and natural gas prices and differentials can fluctuate significantly due to various market-related factors, making it challenging to predict realized prices reliably. We may respond to changing economic conditions by adjusting the amount and allocation of our capital program or by pursuing additional cost reductions. Significant changes in oil and natural gas prices may also affect the quantities of reserves that we can economically produce over the longer term. Global oil prices increased significantly towards the end of the three months ended March 31, 2026 and continuing to date through the second quarter due to military conflicts and geopolitical tensions. In March 2026, oil prices escalated sharply as Middle East crude and product flows from the region were interrupted due to damage to regional energy infrastructure and the effective closure of the Strait of Hormuz. Additionally, oil prices were affected to a lesser extent by Ukrainian military strikes that significantly impacted Russian export capabilities. We expect oil prices to remain volatile as these geopolitical circumstances continue to evolve. Refer to Results of Our Oil and Natural Gas Operations, Production, 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, December 31, 2026 2025 Brent oil ($/Bbl) $ 77.90 $ 63.08 WTI oil ($/Bbl) $ 71.93 $ 59.14 NYMEX Henry Hub ($/MMBtu) $ 5.04 $ 3.55 Supply Chain and Inflation We continued to experience relatively flat pricing from our suppliers during the first three months of 2026 compared to the prior year. U.S. tariff policy regarding both country of origin and material type remains highly uncertain and subject to future changes. During 2025, the United States significantly expanded tariff rates on imported goods, including increasing Section 232 tariffs on steel and aluminum to 50% and adding copper at the same rate. In February 2026, the Supreme Court ruled that the President's use of emergency powers under the International Emergency Economic Powers Act to impose country-specific "reciprocal" tariffs was unconstitutional; however, Section 232 metals tariffs were not affected by this ruling. In April 2026, the Federal government further restructured the Section 232 metals tariffs establishing a tiered rate structure based on metal content and applying tariffs to the full customs value of imported articles rather than only the embedded metal content. 30 These expanded and restructured tariff rates are expected to increase our cost of oilfield goods and extend delivery lead times over the longer term. The shift to full-value assessment for derivative articles, in particular, may increase duty burdens on certain imported components and assemblies beyond prior levels. Overall, we expect a slight impact from tariffs on our supply chain in 2026. We believe we can mitigate a portion of these cost increases through bulk purchases, domestic sourcing, and ongoing review of product classifications and supplier origin. However, the evolving nature of tariff policy — including the potential for future modifications, legal challenges, and new product inclusions — creates continued uncertainty that may limit our ability to fully offset these impacts. High fuel costs are adversely impacting transportation and equipment prices, and high oil prices are impacting oil-based products such as chemicals and lubricants. At current oil prices, we expect these costs to increase by $6 million to $8 million for the remainder of 2026. Marketing Arrangements In early 2026 Valero ceased purchasing crude oil for its Benicia refinery and it is reported that the refinery ceased operations in April 2026. While we have historically sold a portion of our crude oil to this refinery, we have not experienced difficulty in selling our production to the remaining refineries in California or any negative impact on pricing or realizations as a result of this closure. In March 2026, the United States Secretary of Energy issued an order under the authority of the Defense Production Act of 1950 directing Sable Offshore Corp. (Sable) to restart oil and gas production at the San Ynez Unit, located in Federal offshore waters, and to facilitate the movement of offshore crude oil into California via the Las Flores pipeline. The State of California and other non-governmental organizations have filed suit against the United States Secretary of Energy and Sable, the owner of the San Ynez Unit, to block transportation of this crude oil into California. However, Sable has indicated that it is currently producing crude oil and has the potential to increase production to approximately 60,000 barrels per day. We expect that this additional production could strain existing pipeline transportation capacity required to reach refiners, which could require us to find alternative routes to market that may be limited or more costly. In addition, we expect that this production will have the potential to compete with our crude oil production in the California refining market. Regulatory Updates Well Permitting During the three months ended March 31, 2026, we received permits for 66 new oil and gas wells, 21 workovers and 2 sidetracks. We currently hold sufficient permits to support a seven rig program, which includes 6 rigs in California and 1 rig in Utah, in the second half of 2026. Water Injection Our operations in the Wilmington Oil Field use injection wells to reinject produced water under approved waterflooding plans. CalGEM has issued a directive to reduce the injection well pressure in a gradual manner in accordance with a five-year injection reduction work plan. The first phase of reduction commenced July 1, 2024, and a second reduction began in January 2025. We expect that the next phase of reduction will remain on hold until the fall of 2026 while we evaluate the impact of the previously implemented reductions together with CalGEM. We currently estimate a negligible impact on production and reserves under the existing work plan. However, material changes to the existing plan could require revisions to these estimates. CA Cap-and-Invest (AB 1207 and SB 840) In January 2026, the California Air Resources Board released proposed amendments to update its existing Cap-and-Invest program. The rulemaking process is ongoing, and the final terms and requirements of any proposed amendments have not yet been determined. We are actively monitoring these developments and potential impacts to our business. 31 Statements of Operations Analysis Our consolidated results of operations include the results of Berry beginning on December 18, 2025, the closing date of the Berry Merger. For more information on the Berry Merger, see Part I, Item 1 – Financial Statements, Note 2 Business Combination. The Berry Merger affected the comparability of our financial results for the three months ended March 31, 2026 to the prior comparative period. Consolidated Results of Operations Three months ended March 31, 2026 compared to December 31, 2025 The following table presents our consolidated operating revenues for the periods indicated: Three months ended March 31, 2026 December 31, 2025 (in millions) Oil, natural gas and natural gas liquids sales $ 905 $ 679 Net (loss) gain from commodity sales derivatives (848) 126 Revenue from marketing of purchased commodities 41 60 Electricity revenue 11 52 Other revenue 10 7 Total operating revenues $ 119 $ 924 Oil, natural gas and natural gas liquids sales — Oil, natural gas and natural gas liquids sales, excluding the effects of cash settlements on our commodity derivative contracts, were $905 million for the three months ended March 31, 2026, which was an increase of $226 million compared to $679 million for the three months ended December 31, 2025. Oil, natural gas and natural gas liquids sales included $131 million and $18 million for the three months ended March 31, 2026 and December 31, 2025, respectively, related to sales of additional production from the Berry properties following the completion of the Berry Merger on December 18, 2025. The following table shows changes in oil, natural gas and natural gas liquids sales for the three months ended March 31, 2026 compared to the three months ended December 31, 2025: Oil NGLs Natural Gas Total Operations (in millions) Three months ended December 31, 2025 $ 614 $ 39 $ 26 $ 679 Changes in realized prices 134 2 (4) 132 Changes in production and other 86 1 2 89 Changes in intersegment revenues — — 5 5 Three months ended March 31, 2026 $ 834 $ 42 $ 29 $ 905 Note: See Production for volumes by commodity type and Prices and Realizations for index and realized prices for comparative periods. 32 Net (loss) gain from commodity sales derivatives — We report gains and losses on our derivative contracts related to sales of our oil and marketing activities in operating revenues. Net loss from commodity sales derivatives was $848 million for the three months ended March 31, 2026 compared to a net gain of $126 million for the three months ended December 31, 2025. The change primarily resulted from the non-cash changes in the fair value of our outstanding commodity derivatives from the positions held at the end of each measurement period. Oil prices significantly increased as of March 31, 2026 compared to December 31, 2025. For instance, the Brent forward curve for the twelve months following March 31, 2026 increased by approximately 40% to $83.66 compared to $60.30 at December 31, 2025. As of March 31, 2026, we have hedges on approximately 65% of our expected oil production for the remainder of 2026 at a weighted average floor price of $64.99. Gains and losses from our commodity derivative contracts are shown in the table below: Three months ended March 31, 2026 December 31, 2025 (in millions) Non-cash (loss) gain from commodity sales derivatives $ (792) $ 95 Net settlements and premiums (56) 31 Net (loss) gain from commodity sales derivatives $ (848) $ 126 Revenue from marketing of purchased commodities — Revenue from marketing of purchased commodities was $41 million for the three months ended March 31, 2026 compared to $60 million for the three months ended December 31, 2025. The decrease was related to lower natural gas prices in California resulting from high storage levels. Electricity revenue — Electricity revenue decreased by $41 million to $11 million for the three months ended March 31, 2026 compared to $52 million for the three months ended December 31, 2025. This decrease was primarily a result of reduced resource adequacy revenues as well as less electricity generated in response to market conditions during the three months ended March 31, 2026 compared to the three months ended December 31, 2025. 33 The following table pr [Excerpt truncated for page length; source filing is linked above.]