Murphy Oil Corporation (MUR) Q4 2025 earnings review
Strong Operations Undercut by Weak Pricing and Exploration Risk
Murphy Oil delivered Q4 production (181.4 MBOEPD) above expectations and achieved its lowest operating expense in over a year ($9.16/BOE). However, sharply lower realized oil prices (down $7/bbl sequentially to $59.21/bbl) overshadowed operational excellence, causing Adjusted EBITDA to fall 24% sequentially to $298.1M and Adjusted EPS to collapse to $0.14. Despite successful appraisal in Vietnam and new discoveries in the Gulf of America, the company guided FY 2026 production down 6% (midpoint), reflecting reduced onshore activity and higher Canadian gas royalties. Murphy increased its dividend by 8% to $0.35/share, confirming its commitment to capital returns.
🐂 Bull Case
Successful appraisal at Hai Su Vang (Vietnam) reinforces a major discovery, and discoveries at Cello #1/Banjo #1 (GOM) de-risk future tie-back production. These projects create a long-term growth runway outside the North American shale decline curve.
Full-year LOE fell 20% to $10.89/BOE. Continued onshore capital efficiency (EFS CAPEX down 25% in FY26) lowers the corporate breakeven, insulating cash flow from moderate price drops.
The company increased its dividend by 8% and maintains strong liquidity and a manageable balance sheet ($1.0B net debt), enabling continued execution of the 50%+ adjusted FCF shareholder return framework.
🐻 Bear Case
Q4 Adjusted EBITDA fell 24% sequentially, demonstrating acute sensitivity to commodity price weakness. Operational wins (low costs, production beat) failed to prevent a sharp earnings contraction.
FY 2026 production is guided to decline 6% YoY, driven by reduced gas volumes (Tupper Montney) and a decision to prioritize capital efficiency over short-term volume growth in Eagle Ford Shale.
The high-risk exploration strategy resulted in the Civette-1X (Côte d’Ivoire) dry hole. The value proposition is increasingly reliant on subsequent risky frontier wells (Caracal, Bubale, Morocco entry).
⚖️ Verdict: ⚪
Neutral. The company successfully executed operationally, achieved major exploration milestones, and strengthened its balance sheet. However, the immediate earnings volatility, coupled with decelerating production guidance for 2026, makes the stock highly dependent on positive outcomes from its risky, long-cycle international exploration program.
Key Themes
International Exploration Success De-risks Long-Term Value
The exploration program proved successful with the Hai Su Vang-2X (HSV) appraisal in Vietnam reinforcing the large discovery, now trending towards the high end of the 170-430 MMBOE range. Additionally, discoveries at Cello #1 and Banjo #1 (GOM) are confirmed as infrastructure-led tie-backs, providing near-term stability. These successes solidify the long-term goal of building a 30-50 MBOEPD business in Vietnam by the early 2030s.
Lease Operating Expense (LOE) Continues to Decline
LOE per BOE continued its downward trajectory, dropping to $9.16/BOE in Q4, beating the full-year target of $10-$12/BOE, and reflecting a 20% YoY structural cost reduction. This is an **Accelerating** favorable trend, driven by high production rates absorbing fixed costs and ongoing efficiency gains in the Eagle Ford Shale (EFS).
Decelerating 2026 Production Guide
The 2026 production guidance midpoint of 171.0 MBOEPD implies a 6% decline from 2025 actuals. This **Decelerating** volume trend is partially strategic—prioritizing capital efficiency in EFS—but also operational, reflecting anticipated lower net natural gas volumes at Tupper Montney due to higher royalty rates linked to expected AECO price increases.
High-Risk Exploration Loss and New Frontier Entry
The high-impact exploration strategy delivered a loss with the Civette-1X well in Côte d’Ivoire classified as a dry hole. This contrasts with the Vietnam success. Management subsequently signed a Petroleum Agreement for the Gharb Deep Offshore block in Morocco, marking a new, potentially high-risk frontier basin entry that requires monitoring.
Capital Budget Focus Shifts to Long-Cycle Development
The stable FY 2026 CAPEX guide ($1.2B - $1.3B) masks a clear shift in allocation. Onshore spending is down (EFS capital down 25%), while investment in long-cycle development (Vietnam Lac Da Vang, GOM Chinook #8) and high-impact exploration remains protected. This discipline prioritizes future cash flow over short-term shale growth.
Liquidity and Debt Profile Enhanced
Subsequent to Q4, Murphy proactively upsized its senior unsecured revolving credit facility from $1.35B to $2.0B and extended maturity to 2031. It also issued $500M in 2034 senior notes to redeem near-term maturities, bolstering liquidity and extending the maturity profile. Total debt of $1.4B remains consistent with the long-term target.
Macro: Commodity Price Volatility
The global energy market volatility remains a concern. The sharp Q4 drop in realized oil price ($59.21/bbl) instantly translated into significant profit compression, highlighting the need for cost control (which management delivered) but also vulnerability if prices stabilize below the company’s comfort range (low $60s/bbl).
Other KPIs
Adj EBITDA experienced a **Decelerating** trend, falling 24% sequentially from Q3’s peak of $390.6M. The full-year figure of $1.36B was down 10% YoY. The sharp Q4 decline was primarily a function of lower realized prices, which negated the outstanding LOE performance and production beat.
The reserve replacement ratio improved significantly from 83% in 2024, maintaining the company's 11-year reserve life. This indicates successful organic reserve additions, primarily driven by the Hai Su Vang discovery in Vietnam.
FCF was down significantly from $754M in FY 2024. Q4 FCF fell 50% sequentially to $109.6M due to the high CAPEX acceleration in the quarter ($340.8M) and lower operational earnings. This FCF funded shareholder returns of $286M (dividends + buybacks).
Guidance
This implies a 6% decline from the 2025 actual production of 182,294 BOEPD. This trend is **Decelerating** and is primarily driven by lower expected net natural gas volumes in Tupper Montney and strategic capital shifts away from short-cycle EFS growth.
The midpoint ($1.25B) is an 8% increase over FY 2025 actuals ($1.16B), showing a **Stable** commitment to the budget despite market volatility. This capital is heavily allocated to long-cycle projects: Vietnam development (9.6%), Hai Su Vang appraisal (6%), and Chinook #8 development in the GOM.
Implies a 7% **Decelerating** sequential decline from Q4 2025. This reflects the typical seasonal trough and the timing of new onshore well turn-in-lines, supporting management’s expectation of ending the year strong due to major project startups in 2H 2026 (Chinook #8, Lac Da Vang).
Key Questions
Sustaining the Low LOE Run Rate
Q4 LOE was outstanding at $9.16/BOE, but the stockholder update noted a $15M insurance reimbursement. Excluding this one-time benefit, what was the underlying, structural LOE for Q4, and what steps ensure the 2026 guidance remains competitive?
Capital Allocation Following Civette Dry Hole
With the Civette-1X result being a dry hole, how does the team balance the capital allocation between the remaining high-impact exploration wells (Caracal, Bubale) and potentially accelerating de-risked development projects like Chinook #8, especially in light of the new Morocco entry?
Montney Production Sensitivity to AECO
The FY26 production decline is attributed partly to higher royalties due to anticipated AECO price strength. What specific AECO price forecast is currently embedded in the 2026 model, and does the high realized AECO price benefit in 2026 outweigh the volume and royalty headwind?