California Resources Corporation (NYSE: CRC), an independent energy and carbon management company committed to energy transition, today reported third quarter 2023 operational and financial results.

"CRC's strong third-quarter performance demonstrates the hard work of our team and the flexibility of the Company's business strategy to create value for shareholders across various fronts. Foundational to this success has been CRC's ability to generate significant free cash flow, meaningfully advance the Company's carbon management business and demonstrate our California advantage," said Francisco Leon, CRC President and Chief Executive Officer. "We are raising our dividend for the third year in a row and have bought back $604 million of stock since the inception of our share repurchase program, and have repurchased $35 million of senior notes year to date. We see a number of new and exciting developments for CRC as we continue to build a different kind of energy company."

Primary Highlights

• Generated net cash provided by operating activities of $104 million or $129 million of net cash provided by operating activities before changes in operating assets and liabilities, net¹, and delivered $71 million of free cash flow¹ during the third quarter
• Generated net cash provided by operating activities of $522 million and delivered $403 million of free cash flow¹ year to date
• Returned approximately 52% or $207 million of its free cash flow¹ generated year to date to CRC's stakeholders, including $143 million in share repurchases, $5 million in debt repurchases (excluding an additional $30 million of post 3Q repurchases) and $59 million in dividends
• Increased CRC's quarterly dividend by 10% to $0.31 per share payable on December 15, 2023, to shareholders of record on December 1, 2023
• On path to achieve at least $55 million in annual run rate reductions to operating and overhead costs from CRC's business transformation initiative
• Announcing CTV's first capture to storage project at one of the CRC's gas processing plants, Elk Hills cryogenic gas plant, in Kern County, California. This new project is expected to begin to remove and permanently store 100,000 metric tons per annum (MTPA) of CO₂ in the CTV I reservoir by year end 2025
• Signed a storage-only Carbon Dioxide Management Agreement (CDMA)² with NLC Energy LLC (NLCE) with a minimum volume commitment of 150,000 MTPA of CO₂ injection at CTV I reservoir. See CTV's 3Q23 Update for additional information on CMB projects

Quarterly Financial Highlights

• Reported a net loss of $22 million, or $0.32 per diluted share. When adjusted for items analysts typically exclude from estimates (including mark-to-market adjustments of $109 million, and one-time costs of $24 million and adjusting for taxes of $37 million), the Company’s adjusted net income¹ was $74 million, or $1.02 per diluted share
• Generated adjusted EBITDAX¹ of $187 million
• Ended the quarter with $479 million of cash and cash equivalents, an undrawn Revolving Credit Facility and $958 million of total liquidity³

Quarterly Operational Highlights

• Reservoirs performed in line with expectations; total daily gross production of 101,000 gross barrels of oil equivalent per day (Boe/d) during the third quarter
• Produced an average of 85,000 net Boe/d, including 51,000 net barrels of oil per day (MBo/d), with $24 million of drilling and workover capital during the third quarter
• Third quarter average daily net oil production includes a negative impact of 1 net MBo/d related to CRC's production-sharing contracts (PSCs) at the Wilmington field
• Quarter over quarter, operating costs of $24.96 per Boe increased $1.25 per Boe primarily due to higher energy operating costs as electricity and natural gas prices in California markets increased between quarters
• Operated 1 drilling rig in the LA Basin; drilled 9 wells and brought 8 wells online during the third quarter
• Operated 31 maintenance rigs in the third quarter

Total Year 2023 Guidance and Capital Program⁴

CRC is narrowing its guidance range for average daily total net production from 85 to 91 Mboe/d⁴ to 85 and 87 MBoe/d⁴ (~60 % oil) for the full year 2023 to reflect the previously announced and anticipated 5% to 7% entry to exit decline in production.

The Company is lowering its guidance range for the 2023 capital program from $200 to $245 million to $185 to $210 million due to the timing of projects and the availability of permits. The program includes $180 to $200 million of adjusted E&P, corporate and other adjusted capital⁵ and $5 to $10 million of adjusted CMB capital⁵ for carbon management projects. On average for 2023, CRC plans to execute a 1 to 1.5 rig development program. Activity will focus on drilling new locations where CRC has permits and high return workovers. The capital plan also includes procuring critical components for planned maintenance of power and gas processing facilities in 2024 as well as incremental spending to advance CRC's carbon management business.

CRC increased its guidance for natural gas marketing margin for the full year 2023 from $135 to $150 million to $155 to $185 million range to reflect the Company's performance through the first three quarters of the year. The Company also narrowed its 2023 guidance for net electricity margin to $80 to $110 million and narrowed the range for taxes other than on income to $170 to $180 million. CRC's transportation expense guidance increased $10 million to a range of $60 to $80 million. Similarly, CRC's 2023 commodity realizations guidance were adjusted to reflect the Company's expected results.

CRC anticipates additional investment for subsurface land easements during the fourth quarter of 2023 to expand its carbon management business and has increased its guidance for CMB adjusted free cash flow¹ for the full year 2023 from ($60) to ($80) million to ($70) to ($90) million. Additionally, CRC's E&P, Corporate and Other free cash flow¹ guidance was narrowed from $460 to $520 million to $470 to $510 million. As a result, CRC narrowed its total 2023 free cash flow¹ guidance from $380 to $460 million to $380 to $440 million. See Attachment 2 for further information on CRC's total year 2023 guidance.

Fourth Quarter 2023 Guidance and Capital Program⁴

CRC expects its fourth quarter 2023 total capital to range between $70 to $76 million under current operating conditions. This includes $5 to $10 million of adjusted CMB capital⁵ as well as procuring critical components for planned maintenance at a power plant and a gas processing facility at Elk Hills in 2024.

At this level of spending, CRC expects average net total production between 82 and 85 net MBoe/d⁴ (~60% oil) in the fourth quarter of 2023, running a 1 drilling rig program in the Los Angeles basin. See Attachment 2 for further information on CRC's 4Q23 guidance.

During the fourth quarter of 2023, CRC expects to invest approximately $10 to $20 million for additional land easements to expand its carbon management business.

Third Quarter Financial Results

Balance Sheet and Liquidity Update

The aggregate commitment under CRC's Revolving Credit Facility was $627 million as of September 30, 2023. On October 30, 2023, the borrowing base for the Revolving Credit Facility was reaffirmed at $1.2 billion as part of CRC's semi-annual redetermination and the aggregate commitment amount increased to $630 million.

As of September 30, 2023, CRC had liquidity of $958 million, which consisted of $479 million in cash and cash equivalents plus $479 million of available borrowing capacity under its Revolving Credit Facility (which is net of $148 million of issued letters of credit).

Reorganization

In August 2023, CRC implemented organizational changes that resulted in a headcount reduction of 75 employees. These actions were taken to better align CRC's resources to its strategic priorities and improve its operational efficiency. As a result, CRC recognized a charge of $7 million in other operating expenses, net for the three months ended September 30, 2023, primarily related to severance benefits. For the nine months ended September 30, 2023, CRC recognized a severance charge of $10 million. CRC expects these actions, along with other initiatives taken to streamline its operations, to result in at least $55 million of savings in operating and overhead costs on an annualized basis.

Shareholder Return and Deleveraging Strategy

CRC continues to prioritize shareholder returns and therefore dedicates a significant portion of its free cash flow to shareholders in the form of dividends, share repurchases and debt repurchases.

On November 1, 2023, CRC's 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 December 1, 2023 and is expected to be paid on December 15, 2023.

During the third quarter of 2023, CRC repurchased 0.4 million shares for approximately $20 million at an average price of $54.75 per share. Since the inception of the Share Repurchase Program in May 2021 through September 30, 2023, 14,863,915 shares have been repurchased for $604 million at an average price of $40.53 per share, including commissions and excise taxes. These total repurchases represent ~18% of CRC’s shares outstanding since December 31, 2020.

CRC repurchased $5 million in face value of its senior notes at par in the third quarter and an additional $30 million of its senior notes at an average price of 100.50% of par in October 2023. After these repurchases, the remaining principal amount of CRC’s senior notes is $565 million due February 1, 2026.

CRC has returned $739 million of cash to its stakeholders, including $604 million in share repurchases, $5 million in debt repurchases and $132 million of dividends since December 31^st, 2020, through September 30, 2023. These figures exclude $30 million of senior notes repurchased subsequent to quarter end and $21 million of dividends expected to be paid on December 15, 2023.

Upcoming Investor Conference Participation

CRC's executives will be participating in the following events:

• Bank of America Energy Conference on November 14 and 15 in Houston, TX
• Mizuho Energy & Infrastructure Conference on November 27 to 29 in New York City, NY
• Stone X Natural Resource Day on December 7 in New York City, NY
• Goldman Sachs Global Energy and Clean Tech Conference on January 3 to 5 in Miami, FL
• UBS Global Energy and Utilities Conference on January 8 to 10 in Park City, UT
• TD Global Energy Conference on January 8 to 10 in London, UK

CRC’s presentation materials will be available the day of the events on the Events and Presentations page in the Investor Relations section on www.crc.com.

Conference Call Details

To participate in the conference call scheduled for November 2, 2023, at 1:00 p.m. Eastern Time, please dial (877) 315-5411 (International calls please dial +1 (412) 902-6739) or access via webcast at www.crc.com 15 minutes prior to the scheduled start time to register. Participants may also pre-register for the conference call at https://dpregister.com/sreg/10182061/fa45058ce0. A digital replay of the conference call will be archived for approximately 90 days and supplemental slides for the conference call will be available online in the Investor Relations section of www.crc.com.

¹ See Attachment 3 for the non-GAAP financial measures of operating costs per BOE (excluding effects of PSCs), adjusted net income (loss), adjusted net income (loss) per share - basic and diluted, net cash provided by operating activities before changes in operating assets and liabilities, net, free cash flow, adjusted free cash flow, adjusted G&A and adjusted capital, including reconciliations to their most directly comparable GAAP measure, where applicable. For the full year 2023 and 3Q23 estimates of the non-GAAP measure of free cash flow, adjusted free cash flow, adjusted G&A and adjusted capital, including reconciliations to their most directly comparable GAAP measure, see Attachment 3.

² The CDMA frames the contractual terms between parties by outlining the material economics and terms of the project and includes conditions precedent to close. The CDMA provides a path for the parties to reach final definitive documents and FID.

³ Calculated as $479 million of available cash plus $627 million of capacity on CRC's Revolving Credit Facility less $148 million in outstanding letters of credit.

⁴ Current guidance assumes a 2023 Brent price of $84.16 per barrel of oil, NGL realizations as a percentage of Brent consistent with prior years and a NYMEX gas price of $2.77 per mcf and a 4Q23 Brent price of $90.46 per barrel of oil, NGL realizations as a percentage of Brent consistent with prior years and a NYMEX gas price of $3.00 per mcf. CRC's share of production under PSC contracts decreases when commodity prices rise and increases when prices fall.

⁵ Adjusted E&P Capital and Adjusted CMB Capital are Non-GAAP measures. These measures reflect the reclassification of certain E&P, Corporate & Other Capital to CMB Capital related to the investment in facilities to advance carbon sequestration activities. For the full year 2023 and 4Q23 estimates of the non-GAAP measure of free cash flow, including reconciliations to their most directly comparable GAAP measure, see Attachment 2.

⁶ CMB Expenses includes lease cost for sequestration easements, advocacy, and other startup related costs.

About Carbon TerraVault

Carbon TerraVault Holdings, LLC (CTV), a subsidiary of CRC, provides services that include the capture, transport and storage of carbon dioxide for its customers. CTV is engaged in a series of CCS projects that inject CO₂ captured from industrial sources into depleted underground reservoirs and permanently store CO₂ deep underground. For more information about CTV, please visit www.carbonterravault.com.

About California Resources Corporation

California Resources Corporation (CRC) is an independent energy and carbon management company committed to energy transition. CRC produces some of the lowest carbon intensity oil in the US and is focused on maximizing the value of its land, mineral and technical resources for decarbonization efforts. For more information about CRC, please visit www.crc.com.

Forward-Looking Statements

This document contains statements that CRC believes 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 CRC's 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" or "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.

Although CRC believes the expectations and forecasts reflected in its 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 CRC's 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 CRC's actual results to be materially different than those expressed in its forward-looking statements include:

• fluctuations in commodity prices, including supply and demand considerations for CRC's 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 wars in Ukraine and Israel and oil sanctions on Russia, Iran and others;
• regulatory actions and changes that affect the oil and gas industry generally and CRC in particular, including (1) the availability or timing of, or conditions imposed on, permits and approvals necessary for drilling or development activities or CRC's 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 CRC's products;
• the impact of inflation on future expenses and changes generally in the prices of goods and services;
• changes in business strategy and CRC's capital plan;
• lower-than-expected production or higher-than-expected production decline rates;
• changes to CRC's estimates of reserves and related future cash flows, including changes arising from CRC's 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 CRC operates;
• CRC's 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 CRC's counterparties, including financial institutions, operating partners, CCS project participants and other parties;
• reorganization or restructuring of CRC's operations;
• CRC's ability to claim and utilize tax credits or other incentives in connection with its CCS projects;
• CRC's ability to realize the benefits contemplated by its energy transition strategies and initiatives, including CCS projects and other renewable energy efforts;
• CRC's 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;
• CRC's ability to convert it's CDMAs to definitive agreements and enter into other offtake agreements;
• CRC's ability to maximize the value of its carbon management business and operate it on a stand-alone basis;
• CRC's ability to successfully develop infrastructure projects and enter into third party contracts on contemplated terms;
• uncertainty around the accounting of emissions and CRC's ability to successfully gather and verify emissions data and other environmental impacts;
• changes to CRC's dividend policy and Share Repurchase Program, and its ability to declare future dividends or repurchase shares under its debt agreements;
• limitations on CRC's financial flexibility due to existing and future debt;
• insufficient cash flow to fund CRC's capital plan and other planned investments and return capital to shareholders;
• changes in interest rates, and CRC's access to and the terms of credit in commercial banking and capital markets, including its ability to refinance its debt or obtain separate financing for its carbon management business;
• changes in state, federal or international tax rates, including CRC's ability to utilize its net operating loss carryforwards to reduce its income tax obligations;
• effects of hedging transactions;
• the effect of CRC's 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 CRC's 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 CRC's Annual Report on Form 10-K and its other SEC filings available at www.crc.com.

CRC cautions you not to place undue reliance on forward-looking statements contained in this document, which speak only as of the filing date, and CRC undertakes 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 CRC has not independently verified them and do not warrant the accuracy or completeness of such third-party information.

See Attachment 3 for management's disclosure of its use of these non-GAAP measures and how these measures provide useful information to investors about CRC's results of operations and financial condition. CRC has supplemented its non-GAAP measures of consolidated free cash flow with free cash flow from CRC's exploration and production and corporate items (free cash flow from E&P, Corporate & Other) which CRC believes is a useful measure for investors to understand the results of its core oil and gas business. CRC defines free cash flow from E&P, Corporate & Other as consolidated free cash flow less free cash flow attributable to CMB.