Earnings call transcript: California Resources Q4 2025 results reveal revenue surprise, EPS miss

CRC reported Q4 2025 revenue of $924.0M, beating the $789.1M consensus by 17.1%, while EPS of $0.47 missed forecasts by 19.55% (consensus $0.5842). Q4 adjusted EBITDAX was $251M and free cash flow $115M; the company returned ~94% of 2025 FCF to shareholders, added $430M to its buyback authorization, and the stock rose ~2.77% pre-market (now $66.96, YTD +50.75%, market cap $5.94B, P/E 15.87). Management guided FY2026 EPS $2.43 and revenue $3.659B, expects ~155k boe/d (≈+12% YoY) and ~ $1B adj. EBITDA at $65 Brent, highlighted significant CCS and power progress, and cited a corporate breakeven near $60 Brent.

Analysis

CRC’s integrated upstream + CCS + power strategy creates a structural mismatch versus peers that simply produce hydrocarbons. By controlling both point-source CO2 capture and adjacent storage, CRC can compress unit transport/marketing risk and sell firm, lower‑carbon electrons that command different contract tenors and counterparty credit assumptions than merchant oil; that changes cash flow optionality from commodity spot to contracted utility-style annuities over multi‑year horizons.

The biggest regime risks are regulatory sequencing and market adoption timing. EPA and coastal permitting cadence will determine whether CCS becomes a near-term revenue stream or a multi‑year optionality; Resource Adequacy and PPA pricing volatility create an asymmetric earnings lever—positive shocks (heat waves, plant retirements) could re-rate margins quickly, while prolonged regulatory delays or RA normalization would strip most of the premium investors are placing on the integrated narrative.

Operationally, the synergy runway and scale‑driven procurement savings are real second‑order advantages that will widen barriers to entry in California if executed. That said, the path to crystallize value is binary enough that a staged exposure (equity plus defined‑risk options) is the prudent way to capture upside while protecting against a regulatory or execution reversal over the next 6–24 months.

Key Decisions for Investors

• Buy CRC equity (size 2–4% of portfolio) on current levels or a small pullback; target +30–35% over 12 months driven by CCS de‑risking and PPA wins; hard stop -15% (or hedge with puts). Reward/risk ≈ 2:1 assuming one material positive milestone within 12 months.
• Buy a defined‑risk LEAP call spread to express asymmetric upside: long CRC Jan‑2027 lower‑strike call, short Jan‑2027 higher‑strike call (width sized to limit max loss to 1–2% of portfolio). This captures multi‑year optionality in CCS/power with capped capital at risk and ~3:1 upside on success.
• Pair trade (relative): Long CRC / Short a regional pure‑play E&P without CCS exposure (size 1–2% net). Thesis: capture multiple expansion on integrated cash flow conversion while hedging oil price cycles. Timeframe 6–12 months; target relative outperformance ~15%; risk is integration execution miss.
• If concerned about a regulatory binary, buy 3–6 month protection (puts) equal to 25–50% of long equity exposure to cap downside from an adverse EPA/Coastal Commission outcome that could re‑rate CRC by 20–30% within weeks.