Murphy Oil Q3 2026 Earnings: Production Beats Guidance as Profit Recovers

Murphy Oil (NYSE: MUR) reported Q3 2026 revenue from production of $849.2 million, up about 18% from $721.0 million a year earlier, while diluted EPS improved to $1.17 from a loss of $0.02. Production exceeded the upper end of guidance, and lower lease operating expense supported profitability, although $422.2 million of capital expenditures limited free cash flow to $48.2 million.

Core Financial Results

The quarter marked a clear earnings recovery. Operating income from continuing operations rose to $256.5 million from $5.8 million, helped by higher production revenue, a $35.2 million reduction in lease operating expense, and the absence of the prior-year period’s $115.0 million impairment charge.

The improvement was not limited to that impairment comparison. Adjusted net income from continuing operations increased about 173% to $158.4 million, while adjusted diluted EPS rose to $1.08. Adjusted EBITDA attributable to Murphy was $510.9 million, and adjusted EBITDAX was $543.9 million.

Adjusted earnings and free cash flow are non-GAAP measures. The consolidated GAAP statements include the noncontrolling interest in MP Gulf of Mexico, while results specifically labeled “attributable to Murphy” exclude that interest.

Business and Production Performance

Net production was 186,495 BOEPD, roughly 7,500 BOEPD above the upper end of Murphy’s 171,000–179,000 BOEPD guidance. Management attributed the outperformance to accelerated Eagle Ford activity, new-well performance and lower royalties in Tupper Montney, and minimal storm downtime in the Gulf of America.

Onshore assets produced approximately 125,400 BOEPD, while offshore operations excluding noncontrolling interest contributed 61,100 BOEPD. Offshore production had a substantially higher liquids concentration at 88%, compared with 34% for the onshore business.

Murphy brought online 14 operated and four non-operated Eagle Ford wells, along with eight Tupper Montney wells. The Chinook #8 well in the Gulf of America began production and reached a peak gross rate of approximately 15,000 BOEPD, in line with expectations.

Offshore Vietnam also reached first oil at the Lac Da Vang development. Separately, the Lac Da Trang North-1X exploration well encountered approximately 131 feet of net oil pay. In Côte d’Ivoire, the Bubale West-1X appraisal well found approximately 88 feet of net oil pay in the Turonian reservoir and additional hydrocarbons in the deeper Albian reservoir. The release did not quantify the financial contribution of these projects during the quarter.

Profitability, Cash Flow, and Balance Sheet

Lease operating expense declined to $149.2 million from $184.4 million, while continuing-operations lease operating expense was $8.20 per BOE excluding noncontrolling interest. The absence of the prior-year impairment also lowered total costs, but some expense categories moved higher: selling and general expense increased to $40.5 million from $30.9 million, and other operating expense rose to $28.6 million from $5.9 million.

Net cash provided by continuing operations increased to $540.5 million, while operating cash flow excluding working-capital adjustments was $515.0 million. Capital expenditures totaled $422.2 million, leaving non-GAAP free cash flow of $48.2 million. Murphy also paid approximately $50 million in quarterly dividends and did not repurchase shares; $550 million remained under its repurchase authorization.

Murphy ended the quarter with approximately $500 million of cash and $2.50 billion of total liquidity, including an undrawn $2.00 billion credit facility. Total debt was $1.63 billion, about $80 million higher than the prior quarter because the company recognized a finance lease for the Lac Da Vang floating storage and offloading vessel through 2039.

Production Guidance

Murphy raised its full-year 2026 production outlook to 176,000–178,000 BOEPD. The new midpoint is 6,000 BOEPD above the midpoint of its previous range, reflecting the Q3 production outperformance. The company expects full-year output to consist of approximately 48% oil and 54% total liquids.

The release also provided Q4 production and spending targets, but it did not disclose comparable prior guidance for capital expenditures or exploration expense.

Risks Investors Should Monitor

• Sustaining production performance: Q3 benefited from accelerated Eagle Ford activity, strong new wells, lower Tupper Montney royalties, and minimal storm downtime. Maintaining output within the raised full-year range depends on continued asset performance.
• Capital intensity: Quarterly operating cash generation was substantial, but $422.2 million of capital expenditures left free cash flow at $48.2 million. The full-year capital budget of $1.50–$1.60 billion keeps cash conversion sensitive to project spending.
• Higher overhead and other operating costs: Increased selling and general expense and other operating expense partly offset lower lease operating costs. Continued increases in these categories could pressure profitability.
• Debt and lease obligations: Total debt increased following recognition of the long-term Lac Da Vang vessel lease. Although Murphy reported $2.50 billion of liquidity, the additional obligation raises fixed financial commitments.
• Commodity prices and weather: Murphy identifies oil and natural gas prices and natural hazards as material operating risks. These factors can affect revenue, production availability, and cash flow even if well performance remains stable.

Summary

Murphy Oil’s Q3 2026 results were led by production above guidance, higher production revenue, and a return to GAAP profitability. Lower lease operating expense and the absence of the prior-year impairment contributed to the earnings recovery, while higher adjusted profit showed improvement beyond that accounting comparison. The raised production outlook is the main positive operating signal, but capital intensity, modest free cash flow relative to operating cash generation, and the sustainability of Q3 production drivers remain the principal areas to monitor.