California Resources (US:CRC)2026-03-02 21:35Reserves and Production - As of December 31, 2025, the company reported proved reserves totaling an estimated 654 MMBoe, including 541 MMBbl of crude oil and condensate reserves, 37 MMBbl of NGL reserves, and 455 Bcf of natural gas reserves[15]. - The company achieved average net production of approximately 138 MBoe/d for the year ended December 31, 2025, with 79% of this production being oil[15]. - Total net production for the year ended December 31, 2025, was 50 MMBoe, with an average daily net production of 138 MBoe/d, representing a significant increase from 40 MMBoe and 110 MBoe/d in 2024[44]. - Proved reserves as of December 31, 2025, totaled 654 MMBoe, with oil comprising 83% of these reserves, including 541 MMBbl of oil and 455 Bcf of natural gas[21]. - The company operates 68 producing fields, with 38 in the San Joaquin basin alone[21]. - The company drilled and completed 43 net wells in 2025, with an average of 2 drilling rigs in operation[21]. - The average daily net production for oil in Belridge decreased from 34 MBbl/d in 2024 to 32 MBbl/d in 2025, while Elk Hills remained stable at 14 MBbl/d for both years[45]. - Total daily net production for Elk Hills increased from 30 MBoe/d in 2024 to 32 MBoe/d in 2025, while Belridge decreased from 34 MBoe/d in 2024 to 32 MBoe/d in 2025[45]. Financial Performance - For the year ended December 31, 2025, the company generated $363 million of net income and $865 million of net cash provided by operating activities[20]. - The company maintains $1,401 million of liquidity, consisting of $1,284 million available for borrowing and $117 million in cash, with long-term indebtedness of $1,300 million as of December 31, 2025[20]. - Oil sales for the year ended December 31, 2025, amounted to $2,647 million, while total sales of oil, natural gas, and NGLs reached $2,910 million[80]. - The average realized price for oil with derivative settlements in 2025 was $67.51 per Bbl, compared to $75.66 per Bbl in 2024[44]. - Operating costs per Boe for 2025 were $25.42, slightly higher than $24.51 in 2024[44]. - Operating costs for 2025 were reported at $1,280 million, with a cost per Boe of $25.42, compared to $983 million and $24.51 per Boe in 2024[47]. - Excess costs attributable to PSCs were $47 million in 2025, impacting the overall operating costs per Boe[47]. Mergers and Acquisitions - The Berry Merger, completed on December 18, 2025, added 56 MMBoe of proved developed reserves and included the acquisition of C&J Well Services, enhancing operational capabilities[18]. - The Berry Merger, completed on December 18, 2025, added significant production and reserves, including operations in the San Joaquin basin[21]. - The company is targeting annual run-rate synergies of $80 million to $90 million within twelve months post-Berry Merger, primarily from reduced operating costs and administrative expenses[20]. - The company expects to recognize a charge of approximately $22 million in other operating expenses due to a reduction in force following the Berry Merger[124]. Carbon Management and Environmental Initiatives - The company aims to advance carbon management solutions, with plans to capture emissions at its Elk Hills field in early 2026 for permanent sequestration[20]. - The Carbon TerraVault segment focuses on carbon capture and sequestration (CCS) projects, with expectations to inject CO2 into subsurface reservoirs for permanent storage[99]. - The EPA issued Class VI permits for CO2 injection at the Elk Hills field, effective February 6, 2025, with additional permit applications under review[100]. - The company aims for a 20% reduction in average carbon intensity of oil and gas production by 2035, as part of its Responsible Net Zero goal to achieve at least an 80% reduction in Scope 1 and 2 emissions by 2045[106]. - The Inflation Reduction Act increased the maximum tax credit for carbon dioxide capture to $85 per metric ton for industrial and power generation facilities, and $180 per metric ton for direct air capture facilities[155]. - The Kern County Board of Supervisors approved conditional use permits for the Carbon TerraVault I (CTV I) project on October 21, 2024, but ongoing litigation challenges the project's environmental review certification[152]. - The EPA issued Class VI underground injection control permits for four CO2 injection wells at the CTV I site, effective February 3, 2025, with the first CO2 injection anticipated in spring 2026[153]. Regulatory and Operational Challenges - The company is subject to various federal, state, and local regulations that may restrict operations or increase costs, including those related to health, safety, and environmental protection[143]. - The company is facing growing opposition to oil and gas drilling activities, which may delay or prevent development projects[141]. - The company has been impacted by litigation that challenged Kern County's oil and gas drilling activities, which has delayed operations significantly since June 2022[131]. - Future limitations or increased costs related to water management could adversely affect the company's operations in California[148]. - The current administration's reversal of climate-related actions may impact the development of carbon management projects and financial incentives[156]. Infrastructure and Development Plans - The company plans to pursue new well development in Kern County, expecting attractive return profiles and payback periods of approximately three years[20]. - The company maintains a portfolio of exploration prospects supported by extensive 3D and 2D seismic data to identify and evaluate opportunities[78]. - The company has extensive gas infrastructure, including approximately 500 miles of pipeline and a natural gas processing plant with a capacity of 25 mmcf/d[35]. - The company operates 11 power plants with a combined capacity of 855 MW, with a portion of the output used in its oil and gas operations[111]. - The Elk Hills Power Plant has a capacity of 550 MW and is expected to supply 25% to 60% of its electricity output for oil and gas operations in 2026[113]. - The company owns a 50% interest in a 240 MW cogeneration power plant and has three additional natural gas cogeneration plants with capacities of 36 MW, 18 MW, and 5 MW, generating electricity and steam for operations[119]. Workforce and Employment - The company has approximately 2,500 employees as of December 31, 2025, a significant increase from approximately 1,550 employees in 2024, primarily due to the Berry Merger[118]. - The company recorded a workforce Total Recordable Incident Rate (TRIR) of 0.40 and spilled 1,124 gross barrels of production fluids in 2025, excluding Berry operations[122].