10-Q: Murphy Oil Reports Q3 Net Loss Amid Lower Oil Prices, Impairments

Murphy Oil Corporation reported a net loss for the third quarter of 2025 and a significant drop in nine-month net income, primarily due to lower crude oil prices and a substantial asset impairment.

Summary

• Reported a net loss attributable to Murphy of $3.0 million for Q3 2025, a significant decline from net income of $139.1 million in Q3 2024.
• Net income attributable to Murphy for the nine months ended September 30, 2025, was $92.3 million, down from $356.8 million in the same period of 2024.
• Revenue from production decreased by $32.2 million in Q3 2025 and $268.5 million for the nine months, mainly due to lower crude oil prices and reduced offshore production.
• Total hydrocarbon production increased by 8% to 206,936 barrels of oil equivalent per day (BOE/d) in Q3 2025 and by 2% to 189,035 BOE/d for the nine months, driven by new wells in Eagle Ford Shale and better performance in Tupper Montney.
• Incurred pretax impairment charges of $115.0 million in Q3 2025 related to the Dalmatian field in the Gulf of America due to reserve reductions.
• Lease operating expenses decreased by $38.5 million in Q3 2025 and $111.8 million for the nine months, attributed to lower workover costs, production handling fees, the BW Pioneer FPSO acquisition, and cost-saving initiatives in Eagle Ford Shale.
• Exploration expenses decreased by $61.0 million for the nine months, primarily due to no dry hole expense recorded in 2025.
• Depreciation, depletion, and amortization (DD&A) expenses increased by $59.8 million in Q3 2025 and $86.6 million for the nine months, due to higher production levels and elevated rates in the Gulf of America.
• Cash dividends per common share increased to $0.325 in Q3 2025 ($0.975 year-to-date) from $0.300 in Q3 2024 ($0.900 year-to-date).
• Repurchased $102.6 million of common stock during the nine months ended September 30, 2025, compared to $300.1 million in the prior year period.

Sentiment

Score: 3

Explanation: The company reported a net loss for the quarter and a substantial decline in net income for the nine-month period, primarily driven by lower crude oil prices, higher impairment charges, and increased depreciation. While production volumes increased and cost-saving initiatives were noted, the overall financial performance was significantly weaker year-over-year.

Positives

• Total hydrocarbon production increased by 8% in Q3 2025 to 206,936 BOE/d and by 2% for the nine months to 189,035 BOE/d, compared to prior year periods.
• Higher production in the Eagle Ford Shale was primarily the result of new wells online at Karnes and Catarina.
• Higher production in Canada Onshore relates to better well performance at Tupper Montney.
• Lease operating expenses decreased by $38.5 million in Q3 2025 and $111.8 million for the nine months, driven by lower workover costs, production handling fees, the acquisition of the BW Pioneer FPSO, and cost-savings initiatives in the Eagle Ford Shale.
• Exploration expenses decreased by $61.0 million for the nine months ended September 30, 2025, primarily due to no dry hole expense recorded in 2025.
• The Lac Da Hong-1X (Pink Camel) exploration well in Vietnam encountered 106 feet of net oil pay from one reservoir and continues to progress post-drill evaluations.
• Paid down $50.0 million of debt under the revolving credit facility (RCF) in Q3 2025.
• Increased quarterly cash dividends to $0.325 per common share, up from $0.300 in the prior year.
• Net working capital improved by $107.3 million, from a liability of $157.5 million at December 31, 2024, to $50.2 million at September 30, 2025.
• Maintained strong liquidity of approximately $1.6 billion, consisting of $426.0 million in cash and cash equivalents and $1,199.6 million available on its committed senior unsecured RCF.

Negatives

• Reported a net loss attributable to Murphy of $3.0 million for the three months ended September 30, 2025, compared to net income of $139.1 million in the same period of 2024.
• Net income attributable to Murphy for the nine months ended September 30, 2025, decreased significantly to $92.3 million from $356.8 million in the prior year period.
• Revenue from production decreased by $32.2 million in Q3 2025 and $268.5 million for the nine months, primarily due to lower crude oil prices and decreased offshore production in the Gulf of America and Canada.
• Incurred pretax impairment charges of $115.0 million in Q3 2025 related to the partial write-down of the Dalmatian field in the Gulf of America due to reserve reductions.
• Depreciation, depletion, and amortization (DD&A) expenses increased by $59.8 million in Q3 2025 and $86.6 million for the nine months, driven by higher total production levels and elevated rates in the Gulf of America.
• Interest expense, net, increased to $24.7 million in Q3 2025 from $21.3 million in Q3 2024, and to $73.3 million for the nine months from $62.3 million in the prior year period.
• The Corporate segment reported an unfavorable variance of $33.8 million for the nine months, primarily due to higher foreign exchange losses ($31.5 million) and higher interest expense.
• Net cash provided by continuing operations activities decreased by $297.3 million for the nine months ended September 30, 2025, compared to the same period in 2024.
• Net cash required by investing activities increased by $118.1 million for the nine months, primarily due to the $125.0 million purchase of an FPSO and higher development drilling in Eagle Ford Shale.

Risks

• Macro conditions in the oil and natural gas industry, including supply/demand levels, actions by major oil exporters, and resulting impacts on commodity prices.
• Geopolitical concerns, political and regulatory instability in operating markets.
• Increased volatility or deterioration in the success rate of exploration programs or ability to maintain production rates and replace reserves.
• Reduced customer demand for products due potentially to environmental, regulatory, technological, or other reasons.
• Adverse foreign exchange movements.
• Impact on operations or market from health pandemics or other natural hazards.
• Failure to obtain necessary regulatory approvals.
• Inability to service or refinance outstanding debt or to access debt markets at acceptable prices.
• Adverse developments in the U.S. or global capital markets, credit markets, banking system, or economies in general, including inflation, trade policies, tariffs, other trade restrictions, and possible economic recession.
• Exposure to numerous federal, state, local, and foreign environmental, health, and safety laws and regulations, including those related to climate change and greenhouse gas (GHG) emissions.
• Potential for significant civil and criminal penalties, injunctions, and construction bans or delays from violations of environmental laws.
• Risk of substantial expense from hazardous substance discharges, including remediation costs and third-party claims.
• Possibility of environmental expenditures at currently unidentified sites or additional expenditures at known sites.
• Uncertainty regarding the ultimate effect of tariffs on economic conditions, costs for goods and services in E&P operations, or inflation.
• Potential for material future impairment charges if commodity prices weaken or costs rise.

Future Outlook

For the fourth quarter of 2025, production is expected to average between 176.0 and 184.0 thousand barrels of oil equivalents per day, excluding noncontrolling interest. Capital expenditures for 2025 are projected to be between $1,135 million and $1,285 million, excluding noncontrolling interest, including $104 million for the BW Pioneer FPSO. The company plans a three-well exploration program in Côte d'Ivoire and will continue drilling the Hai Su Vang-2X appraisal well in Vietnam, with results anticipated in Q4 2025. Exploration wells Cello #1 and Banjo #1 in the Gulf of America will also be drilled in Q4 2025. First oil from the Lac Da Vang development project in Vietnam is anticipated in Q4 2026. The company intends to fund its capital program using operating cash flow and available cash, prioritizing share repurchases over bond repayment for any surplus cash. The OBBBA legislation, signed in July 2025, is not expected to have a material impact on financial statements for the period ended September 30, 2025, but will be monitored for future guidance.

Management Comments

• Increased production to 206,936 barrels of oil equivalent (BOE) per day (including NCI), up from 191,273 BOE per day in the third quarter of 2024, and up from 196,315 BOE per day in the second quarter of 2025.
• Paid down $50.0 million of debt under the RCF and returned $46.4 million ($0.325 per share, or $1.30 per share annualized) to shareholders through a quarterly dividend.
• Murphy also strives to create long-term shareholder value through offshore exploration and development in the Gulf of America, Vietnam and Côte d'Ivoire.
• The Company plans to utilize any surplus cash (not planned to be used by operations, investing activities, dividends or payment to noncontrolling interests) in accordance with the Company's capital allocation plan designed to allow for additional shareholder returns and debt reduction.
• Based on current market conditions and our planned exploration and appraisal program, the Company is currently more likely to use available adjusted Free Cash Flow for share repurchases than bond repayment.

Industry Context

The oil and natural gas industry continues to be significantly impacted by global commodity pricing, leading to volatile prices for crude oil and natural gas, which directly affects the company's profitability. Geopolitical uncertainties, trade policies, and tariffs also influence demand and operational costs. Regulatory oversight, particularly concerning climate change and greenhouse gas emissions, is increasing, with new EPA rules on methane emissions and the U.S. withdrawal from the Paris Agreement adding to the complex regulatory landscape. The recent first cargo of liquefied natural gas (LNG) from Shell Canada Energy's Kitimat facility could impact the natural gas-weighted Canadian market. Ongoing uncertainties surrounding U.S. tariffs and their legal challenges contribute to an unpredictable economic environment, potentially affecting costs and inflation for E&P operations.

Corporate Governance

Legal Proceedings

• Engaged in a number of routine legal proceedings, including litigation related to climate change.
• The ultimate resolution of these matters is not expected to have a material adverse effect on net income, financial condition, or liquidity in a future period.
• Not aware of environmental legal proceedings likely to exceed the $1.0 million disclosure threshold.

Stakeholder Impact

• Shareholders: Experienced a net loss for the quarter and a significant decline in nine-month net income, but received an increased quarterly dividend and benefited from ongoing share repurchases. Future returns are tied to commodity prices and exploration success.
• Employees: Cost-saving initiatives in the Eagle Ford Shale included workforce reductions at the end of 2024, impacting some employees.
• Customers: Subject to the volatility of crude oil and natural gas prices, which directly affects the cost of products.
• Creditors: Long-term debt increased by $150.7 million, but the company remains in compliance with all covenants related to its revolving credit facility, indicating continued financial stability for debt holders.
• Suppliers: The company's capital expenditure plans and cost-saving initiatives may influence demand for oilfield goods and services.

Next Steps

• Commence a three-well exploration program in Côte d'Ivoire in the fourth quarter of 2025 (Civette-1X, Caracal-1X, Bubale-1X wells).
• Continue drilling the Hai Su Vang-2X (Golden Sea Lion) appraisal well in Block 15-2/17, offshore Vietnam, with results anticipated in the fourth quarter of 2025.
• Drill the Cello #1 (Mississippi Canyon 385) and Banjo #1 (Mississippi Canyon 385) exploration wells in the Gulf of America in the fourth quarter of 2025.
• Continue field development activities in Vietnam at Lac Da Vang (Golden Camel), Block 15-1/05, with scheduled first oil anticipated in the fourth quarter of 2026.
• Monitor any subsequent regulatory guidance related to the One Big Beautiful Bill Act (OBBBA).
• Utilize any surplus cash in accordance with the company's capital allocation plan, designed for additional shareholder returns and debt reduction, with a current preference for share repurchases over bond repayment.

Key Dates

Recommendation

The company reported a net loss for the third quarter and a substantial decline in net income for the nine-month period, primarily due to lower crude oil prices and a significant asset impairment charge of $115.0 million. This indicates a challenging operating environment and impacts profitability. However, there are several mitigating factors: production volumes increased by 8% in Q3 and 2% for the nine months, driven by new wells and better performance in key onshore assets. The company also successfully implemented cost-saving initiatives, leading to lower lease operating and exploration expenses. Strategic investments, such as the BW Pioneer FPSO acquisition and ongoing exploration in Vietnam and Côte d'Ivoire, suggest future growth potential. The company maintains strong liquidity and continues to return capital to shareholders through increased dividends and an active share repurchase program. Given the mixed results—weak profitability offset by operational improvements, strategic investments, and shareholder returns—a 'hold' recommendation is appropriate. Investors should monitor commodity price trends and the success of the ongoing exploration and development projects.

Keywords

Oil and Gas, Exploration and Production, E&P, Crude Oil, Natural Gas, Natural Gas Liquids, Eagle Ford Shale, Gulf of America, Tupper Montney, Kaybob Duvernay, Vietnam, Côte d'Ivoire, FPSO, Commodity Prices, SEC Filing, 10-Q, Financial Results, Production Volumes, Capital Expenditures, Impairment, Shareholder Returns, Dividends, Share Repurchase, Liquidity, Debt, Environmental Regulations, Climate Change