Cal Resources (CRC) Q3 2026 Earnings Call Transcript

California Resources reported Q3 2026 production of 152,000 barrels of oil equivalent per day, adjusted EBITDAX of $341 million, and $142 million of free cash flow before working-capital changes; full-year adjusted EBITDAX guidance is about $1.34 billion at $92 Brent. The company raised its dividend 4% to $0.42 per share, repurchased $30 million of stock, closed the $63 million Crimson Midstream acquisition, and agreed to sell Uinta assets for an estimated $90 million. Management targets $450 million-$475 million of 2027 drilling and workover capital to maintain flat gross production, while pursuing power and carbon-storage projects; a court ruling setting aside approval of the CTV I project creates uncertainty, though management said it does not expect a material impact on results or financial condition.

Analysis

The near-term underwriting case for CRC is operational and commercial—not the headline carbon/data-center optionality. A successful San Pablo Bay restart could improve upstream netbacks as well as pipeline economics; management’s estimate that each 1-point realization gain is worth roughly $40 million of annual EBITDA makes execution and shipment ramp the key 2027 earnings catalyst. That sensitivity is company-provided and should be tested against actual realized prices and transport costs. The second-order benefit is greater market access for other California producers, potentially improving the value of CRC’s infrastructure beyond its own barrels.

The counterweight is that the emerging power and storage platform remains long-duration and approval-dependent. The CTV I court ruling raises execution and reputational risk for carbon-linked projects; a new permit application is not an approved project. Golden Valley’s 12–18 month review and the Bloom MOU precede customer contracts and financing commitments. Bloom Energy (BE) may gain a route to projects, but CRC’s plan for third-party ownership means CRC’s economics—and BE’s eventual equipment revenue—are not yet established.

Over the next 1–3 months, verify fourth-quarter realization progress and the Uinta sale proceeds’ allocation. In 2027, watch the pipeline restart, definitive commercial agreements, and permitting. Over 6–18 months, cost-review savings and power/CCS projects could broaden CRC’s multiple, but should not be capitalized as secured cash flow yet. The contrarian risk is treating the integrated-platform narrative as already monetized; the nearer-term value is more plausibly in core production economics, logistics, and capital discipline.

Key Decisions for Investors

• Favor a measured long in CRC for improving logistics/netbacks and capital returns, but underwrite it on E&P cash generation rather than data-center or CCS value. Reassess if the San Pablo Bay restart slips beyond Q1 2027 or oil realizations fail to improve from the guided 92% of Brent.
• Treat the pipeline restart as the primary 2027 catalyst: monitor actual throughput, realized crude pricing, transportation expense, and third-party tariff earnings. A restart alone is not proof of the projected upstream uplift.
• Keep BE on watch rather than buying the MOU as contracted backlog. Upgrade only after disclosed customer commitments, project financing, and equipment delivery schedules establish revenue visibility.
• Do not assign full value to CRC’s carbon platform until the CTV I ruling’s consequences are clearer and permits advance. A material adverse final ruling or delays to other projects would weaken the longer-term optionality thesis.
• Track CRC’s cost base and capital allocation alongside oil prices: higher gas and diesel costs can offset realization gains, while the 2027 flat-production plan depends on execution of the six-rig program. Falsifiers include sustained cost inflation, weaker-than-guided production, or buybacks displacing higher-return reinvestment.