Q4 2025 Earnings: Mid-Cap E&Ps and the Diversification Dividend
APA, Murphy Oil, Talos Energy, CNX Resources, Epsilon Energy
Source filings: SEC EDGAR 8-K press releases, Q4/FY 2025
Published: March 25, 2026
The mid-cap tier of U.S. upstream E&P delivered a predictable Q4 2025 — low realized prices, disciplined capital, and a persistent theme that the market hasn't fully priced: diversification still works. While Permian gas was effectively worthless ($0.15/Mcf for APA's U.S. gas portfolio), operators with international exposure, offshore optionality, or Appalachian hedging programs posted surprisingly resilient cash flows. The real story in this batch isn't one quarter's numbers — it's what management teams are signaling about 2026 capital posture, portfolio reshaping, and where the next growth levers are hiding.
APA Corporation: Inventory Vindicated, U.S. Gas a Drag
APA closed Q4 with 459,767 BOE/d reported production (387,119 BOE/d adjusted, stripping Egypt NCI and tax barrels). The headline that matters: U.S. oil production snapped back to 132,001 BOPD — a 9% sequential improvement driven by better run-time and mild weather — after a weaker Q3. That's the production base management wants to sustain heading into a year where it's guiding 120,000–122,000 BOPD, implying modest voluntary decline as they right-size the Permian capital program.
Free cash flow hit $425 million in Q4 — respectable given APA's portfolio breadth — but the full-year $1.0 billion FCF number has to be viewed in context: the company spent $2.1 billion in upstream capital and still carries nearly $4.0 billion in net debt. The balance sheet is improving (total debt below $4.5 billion year-end, down materially from the Callon acquisition hangover), but APA isn't in a position to be aggressive with buybacks. $640 million returned to shareholders in 2025 represented over 60% of FCF — solid discipline — but the absolute quantum is modest for a company of this production scale.
The most analytically interesting disclosure was the Permian inventory audit: APA validated approximately 10 years of economic inventory at current cost structure, with "substantial technical upside." That language matters. APA has spent two years under a cloud of concerns about Permian depth-of-inventory after the Callon deal; this report is management drawing a line under that narrative. Whether investors believe it will depend on execution at $2.1 billion of 2026 capital — a 10% reduction year-over-year, with $1.2 billion deployed to Permian development and $100 million toward LOE reduction projects.
Egypt and international remain APA's pricing savior. Egypt gross gas production grew approximately 10% year-over-year; adjusted Egypt production held at 77,173 BOE/d with realized oil above $62/bbl — a $2/bbl premium to U.S. realizations. North Sea added another $63.18/bbl. While those volumes decline in 2026 guidance (North Sea shrinkage, some asset sales), the Suriname GranMorgu development ($230 million planned in 2026) is the long-dated growth card APA is carefully turning over.
Data gap: Standalone 2026 capex and production guidance split by segment was not fully extracted from the 8-K press release summary; supplemental financial data at apacorp.com contains granular quarterly cadencing.
Murphy Oil: Vietnam Is the Story, Eagle Ford Is the Engine
Murphy's Q4 number — 181,431 BOE/d total, with 87,044 BOPD of oil — came in above the midpoint of quarterly guidance, capping a full year at 182,294 BOE/d, at the high end of annual guidance. The operational execution is tight. What makes Murphy analytically interesting right now isn't the production delivery — it's the exploration portfolio burning through capital to define the next five years.
The Hai Su Vang-2X appraisal result in Vietnam is significant. A 12,000 BOPD combined flow rate from the primary reservoir, with the midpoint of the resource estimate now toward the high end of the previous 170–430 MMBoe range. That's a material deepwater discovery for a company with a $1.3 billion capital program. The Lac Da Vang (Golden Camel) development is on track for first oil in Q4 2026 — offshore Vietnam is going to be a production contributor inside 12 months.
In the Gulf of America, Murphy drilled discoveries at both Cello #1 and Banjo #1 post-quarter — 30 feet and 50 feet of net pay, respectively. These are incremental, not transformational, but they demonstrate the exploration machine continues to run.
The financial picture is more nuanced. Q4 FCF was $109.6 million on $340.8 million of capex — the company spent heavily in Q4 on exploration. Full-year FCF was $301.3 million against $286 million returned to shareholders. That's a nearly 95% return ratio, aggressive for a mid-cap with a significant development pipeline and meaningful debt. Murphy upsized its revolver to $2.0 billion post-quarter and issued $500 million of 6.5% senior notes due 2034 — locking in long-term funding, but the cost of capital is visible.
2026 guidance: 167,000–175,000 BOE/d at $1.2–$1.3 billion capex. The 8% dividend increase to $1.40/share annualized is management's statement of confidence. The question is whether the Vietnam timeline and GoA exploration success sustains the valuation premium Murphy has historically carried in this tier.
Data gap: Per-unit realized oil/gas/NGL prices for Q4 2025 not extracted in full from the truncated press release; detailed pricing tables available in the Quarterly Stockholder Update on murphyoilcorp.com. Q4 production excludes NCI (MP GOM 20% noncontrolling interest).
Talos Energy: Offshore Purity, Non-Cash Noise, Real Cash Flow
Talos produced 89.2 MBoe/d in Q4 (64.9 MBo/d, 73% oil) and 94.6 MBoe/d for the full year. The GAAP net loss of $202.6 million — or $1.19/share — is almost entirely explained by a $170.4 million non-cash ceiling test impairment charge triggered by lower trailing 12-month commodity prices. Investors who know the full-cost accounting method will look straight through it; those who don't will misprice the stock. The adjusted EBITDA of $240.1 million and adjusted FCF of $21.3 million in Q4 tell a different story — a company generating real cash, just at lower prices than the prior year.
The full-year picture is better: $417.7 million of adjusted FCF, $935.8 million of operating cash, and $498.6 million of capital invested. That's nearly $420 million of genuine cash generation on a ~$1.25 billion debt load. Net leverage at 0.7x is the lowest Talos has carried in years, and the January 2026 credit facility extension to 2030 — at the same $700 million borrowing base — removes near-term refinancing risk.
Talos's Optimal Performance Plan is worth watching. The company set a $25 million FCF enhancement target for 2025 and delivered $72 million — nearly 3x the goal. The 2026 target is $100 million. If that program continues overperforming, it structurally changes the FCF profile at current commodity prices.
The exploration pipeline is building. Daenerys (discovered August 2025, Walker Ridge) has an appraisal well planned in Q2 2026. Cardona came online early 2026 under budget and ahead of schedule. CPN was drilled under budget in Q1 2026. On the non-operated side, Monument (Beacon-operated) is a multi-well development consuming roughly 40% of 2026 capital.
2026 guidance: 85–90 MBoe/d (62–66 MBo/d oil) at $500–550 million capex. The production midpoint is slightly below 2025's full-year average — the Genovesa SCSSV failure (expected offline until Q3 2026) is a known headwind, costing roughly 3 MBoe/d while the workover is completed. Excluding Genovesa, the underlying production trajectory is flat to modest growth.
LOE at $18.07/Boe in Q4 is elevated versus the $15.83/Boe full-year average, partly reflecting workover activity. Talos's offshore cost structure is inherently higher than onshore peers, and the pure-play offshore strategy requires sustained capital efficiency to justify.
CNX Resources: The Hedged Gas Machine
CNX is almost its own category. This isn't a company chasing higher commodity prices — it's a company that has systematically locked in prices and is executing against a long-dated capital return program. Q4 2025 production: 152.3 Bcfe (1,654.8 MMcfe/d), headlined by 130.5 Bcf from Appalachian shale and 9.4 Bcf from CBM. Quarterly gas revenues came in at $476.6 million; realized natural gas price of $3.12/Mcf before hedge settlements, dropping to $2.75/Mcfe all-in after a $58 million Q4 derivative loss (settled).
Net income in Q4 was $196.3 million ($1.28 diluted) — a strong number, substantially boosted by $72 million in unrealized derivative gains as forward gas prices rose. CNX generated $297 million of operating cash flow and invested $174 million of capex in Q4, implying approximately $123 million of quarterly FCF.
The 2026 guidance is the analytical centerpiece: 605–620 Bcfe production, ~$550 million FCF at current strip, $556–586 million capex. The FCF yield on market cap is compelling at current share prices. CNX is ~81% hedged for 2026 at a realized price that works out to approximately $2.75/Mcf all-in — a hedge book that was set at lower prices than the current strip (~$4.07/MMBtu NYMEX as of guidance date). That's a mixed blessing: downside protection is real, but CNX won't fully capture the gas price recovery it has arguably engineered through years of capital discipline and hedging.
The Apex acquisition (completed Q1 2025, ~$517.6 million) expanded CNX's Utica Shale rights, extending runway in the Central Pennsylvania Appalachian (CPA) area. Three Utica wells are planned in 2026, alongside 24 SWPA Marcellus TILs. The model is slow and steady: sub-$1.75/Mcfe all-in cash cost, systematic buybacks ($523.6 million repurchased in 2025), and a perpetual hedge book that insulates cash flow.
The critique of CNX is always the same: the hedge book suppresses upside participation in a rising gas price environment. With Henry Hub trading materially above CNX's 2026 average locked-in price, this is a live debate. Management's counter — that the predictable FCF enables an accelerated buyback and debt reduction — has merit. CNX's share count has declined substantially over the past three years.
Epsilon Energy: Transformational Pivot, Muted Data
Epsilon (EPSN) doesn't fit neatly into a Q4 2025 earnings summary because the company was structurally restructuring during the quarter. In November 2025, Epsilon closed the acquisition of the Peak Companies — Peak Exploration & Production LLC and Peak BLM Lease LLC — adding operated Powder River Basin (PRB) assets in Wyoming to its existing Appalachian gas, Texas, New Mexico, and Alberta portfolio. The deal involved issuance of 5.68 million shares plus a $50.5 million credit facility draw, with up to 2.5 million additional shares contingent on Wyoming regulatory approvals.
The strategic logic is reasonable for a company of Epsilon's size: PRB adds oil exposure, diversifies away from Appalachian gas basis risk, and provides operated development upside in a basin with improving cost structures. CEO Jason Stabell described it as "transformational." For a company trading at sub-$300 million market cap, adding a new operated basin is genuinely material.
The complication for analysts: no standalone Q4 2025 earnings press release was filed via 8-K by the time of this research. The acquisition complexity — new employees, new systems, regulatory approvals pending — likely compressed the typical reporting cycle. The most recent detailed earnings disclosure available is Q2 2025. Investors seeking Q3 or Q4 2025 operational and financial results should reference the company's 10-Q and 10-K filings when posted.
Data gap: Standalone Q4 2025 production, realized prices, FCF, and 2026 guidance for EPSN unavailable from reviewed EDGAR filings — no Q3/Q4 2025 earnings press release 8-K found. Results expected in 10-K/10-Q annual and quarterly filings. Post-acquisition combined entity metrics not yet publicly disclosed in structured form.
Key Takeaways
The diversification premium is real. APA's Egypt and North Sea realizations ran $2–5/bbl above U.S. oil prices while Permian gas hit a new low. Murphy's GoA oil base — 51,000 BOPD at $58+/bbl — carried the quarter. In an environment of WTI at $58–65/bbl and weak gas, geographic and commodity diversification isn't a luxury; it's a cash flow stabilizer.
Offshore is showing structural strength. Talos at 0.7x leverage with $418 million of full-year FCF, Talos's Daenerys discovery, Murphy's Gulf of America exploration results, and APA's GranMorgu development all point to the offshore basin capturing capital that onshore is releasing. The cost curve on deepwater has compressed; the FCF math works.
Appalachian gas needs the strip to cooperate. CNX's earnings quality is excellent, but the company's hedge book locks in below-strip prices for 2026. If Henry Hub stays above $4/MMBtu, CNX will underperform on earnings despite disciplined execution. The buyback program partially mitigates this optically, but there's no escaping the hedge math.
Mid-cap capital allocation is increasingly shareholder-return focused. MUR returned 95% of FCF. APA returned 60%+. Talos is buying back up to 50% of FCF. CNX spent over $500 million on buybacks in 2025. For a sub-scale tier historically discounted for reinvestment risk, this is a structural shift.
Watch Vietnam. Murphy's Hai Su Vang appraisal result deserves more attention than it's received. A 12,000 BOPD flow rate on the high end of a 170–430 MMBoe resource range is material for a ~$3 billion market cap company. First production from Lac Da Vang (Golden Camel) in Q4 2026 brings this closer.
Research compiled from SEC EDGAR 8-K filings: APA Corporation (filed 2026-02-25), Murphy Oil Corporation (filed 2026-01-28), Talos Energy Inc. (filed 2026-02-25), CNX Resources Corp (filed 2026-01-29), Epsilon Energy Ltd. (filings through 2025-11-14). All financial figures in USD unless noted. Non-GAAP measures (FCF, EBITDAX, adjusted production) as defined by respective company filings.
Crude Intelligence Report is an independent upstream oil and gas intelligence publication. Content is for informational purposes only and does not constitute investment advice, financial advice, or a recommendation to buy or sell any security. Always conduct your own due diligence before making investment decisions. The author and publisher hold no positions in any companies mentioned in this article. © 2026 Crude Intelligence Report. All rights reserved.
