10-Q: Matador Resources Q3 Profit Falls Amid Lower Oil Prices, Higher Costs

Matador Resources Company reported a significant drop in Q3 2025 net income and diluted EPS despite increased oil and natural gas production, driven by lower realized oil prices and rising operating expenses.

Summary

• Net income attributable to Matador shareholders decreased by 29% to $176.4 million in Q3 2025, compared to $248.3 million in Q3 2024.
• Diluted earnings per common share fell by 29% to $1.42 in Q3 2025, down from $1.99 in Q3 2024.
• Total oil equivalent production increased by 22% year-over-year to 209,184 BOE per day in Q3 2025.
• Oil production rose by 19% to 119,556 Bbl per day, while natural gas production increased by 26% to 537.8 MMcf per day in Q3 2025.
• Realized oil prices decreased by 14% to $64.91 per Bbl in Q3 2025, while realized natural gas prices increased by 7% to $1.95 per Mcf.
• Adjusted EBITDA attributable to Matador shareholders slightly decreased by 1.4% to $566.5 million in Q3 2025.
• The Board of Directors increased the quarterly cash dividend to $0.375 per share, payable on December 5, 2025.
• The company repurchased 1,232,828 shares of common stock for $50.7 million year-to-date under a $400.0 million share repurchase program.
• Estimated drilling, completing, and equipping (D/C/E) capital expenditures for 2025 were increased to a range of $1.47 to $1.55 billion.
• Estimated midstream capital expenditures for 2025 were adjusted to a range of $155.0 to $175.0 million.

Sentiment

Score: 4

Explanation: While operational performance shows strong production growth and the company is returning capital to shareholders through increased dividends and share repurchases, the significant decline in net income and EPS, coupled with lower realized oil prices and rising operating expenses, indicates a challenging profitability environment. The increased capital expenditure budget also adds to future financial commitments.

Positives

• Total oil equivalent production increased significantly by 22% year-over-year in Q3 2025, demonstrating strong operational growth.
• Oil production grew by 19% and natural gas production by 26% in Q3 2025 compared to Q3 2024.
• Third-party midstream services revenues increased by 14% to $43.8 million in Q3 2025, indicating robust midstream segment performance.
• The Board of Directors amended the dividend policy to increase the quarterly cash dividend to $0.375 per share, signaling confidence in future cash flows and commitment to shareholder returns.
• The company is actively executing a $400.0 million share repurchase program, having repurchased $50.7 million year-to-date.
• San Mateo Midstream's secured revolving credit facility lender commitments were increased from $800.0 million to $850.0 million, enhancing liquidity for midstream operations.
• Net cash provided by operating activities increased by $278.6 million to $1.95 billion for the nine months ended September 30, 2025, compared to the same period in 2024.
• The 'One Big Beautiful Bill Act' (OBBBA) resulted in a $26.2 million decrease in the income tax provision for Q3 2025, providing a tax benefit.

Negatives

• Net income attributable to Matador shareholders decreased by 29% to $176.4 million in Q3 2025 and by 15.5% to $566.7 million for the nine months ended September 30, 2025.
• Diluted earnings per common share decreased by 29% to $1.42 in Q3 2025 and by 16.5% to $4.54 for the nine months ended September 30, 2025.
• Realized oil prices decreased by 14% to $64.91 per Bbl in Q3 2025 compared to $75.67 per Bbl in Q3 2024.
• Operating expenses increased across multiple categories, including lease operating expenses (+24%), production taxes, transportation and processing (+14%), plant and other midstream services operating (+16%), depletion, depreciation and amortization (+26%), and general and administrative (+28%) in Q3 2025 year-over-year.
• Interest expense increased by 40% to $50.6 million in Q3 2025, primarily due to increased senior notes outstanding from the Ameredev Acquisition.
• The company recorded an unrealized loss on derivatives of $12.3 million for the nine months ended September 30, 2025, compared to an unrealized gain of $25.4 million in the prior year period.
• Increased estimated D/C/E capital expenditures for 2025 to a range of $1.47 to $1.55 billion, representing a significant increase from previous estimates.

Risks

• Commodity price volatility for oil, natural gas, and NGLs, influenced by market supply and demand, economic activity, geopolitical conflicts, and OPEC+ actions.
• Ability to replace reserves and efficiently develop current reserves, which is critical for long-term success and dependent on finding and development costs.
• Increased costs of operations due to inflation in oilfield services, including diesel, steel, labor, trucking, sand, personnel, and completion costs.
• Delays and other difficulties related to regulatory and governmental approvals and restrictions, including extensive federal, state, and local laws and regulations.
• Availability of sufficient capital to execute the business plan, including funding from future cash flows, capital markets, and borrowing capacity, which may not be available on satisfactory terms.
• Ability to integrate acquisitions, such as the Ameredev Acquisition, and manage associated significant transaction costs and potential litigation/regulatory actions.
• Impact on operations due to seismic events, weather, and environmental conditions.
• Disruption from acquisitions making it more difficult to maintain business and operational relationships.
• Risk of litigation and/or regulatory actions related to acquisitions.
• Supply chain disruptions, tariffs, and trade restrictions limiting the ability to procure necessary products and services in a timely and cost-effective manner.
• Natural production declines in oil and natural gas wells, requiring continuous drilling to offset.
• Effectiveness of risk management and hedging activities in mitigating commodity price exposure.
• Pipeline-related interruptions to oil, natural gas, or NGL production or produced water disposal, including potential NGL fractionation capacity problems.
• Potential for temporary shut-ins of high gas-oil ratio wells if negative natural gas pricing recurs.

Future Outlook

The company increased its estimated drilling, completing, and equipping capital expenditures for 2025 to a range of $1.47 to $1.55 billion and adjusted midstream capital expenditures to $155.0 to $175.0 million. The primary focus for operations and capital expenditures for the remainder of 2025 will be the development of Delaware Basin assets, with an emphasis on longer horizontal wells. The company plans to continue evaluating opportunistic acquisitions of producing properties, acreage, mineral interests, and midstream assets, principally in the Delaware Basin. It also intends to consider divesting non-core assets and monetizing other assets as value-creating opportunities arise. Capital expenditures are flexible and will be adjusted based on market conditions, commodity prices, and drilling results. Commodity derivative financial instruments will be used to mitigate exposure to price fluctuations.

Management Comments

• "Our future success in growing proved reserves and production will be highly dependent on our ability to generate operating cash flows and access outside sources of capital."
• "We have built significant optionality into our drilling program, which should generally allow us to decrease or increase the number of rigs we operate as necessary based on changing commodity prices and other factors."
• "We intend to continue evaluating the opportunistic acquisition of producing properties, acreage and mineral interests and midstream assets, principally in the Delaware Basin."
• "As we have done in recent years, we may divest portions of our non-core assets as well as consider monetizing other assets, such as certain midstream assets and mineral and royalty interests, as value-creating opportunities arise."
• "We routinely monitor and adjust our capital expenditures in response to changes in prices, availability of financing, drilling, completion and acquisition costs, industry conditions, the timing of regulatory approvals, the availability of rigs, success or lack of success in our exploration and development activities, contractual obligations, drilling plans for properties we do not operate and other factors both within and outside our control."
• "We strive to focus our efforts on increasing oil and natural gas reserves and production while controlling costs at a level that is appropriate for long-term operations."

Industry Context

The oil and natural gas industry continues to face significant commodity price volatility, influenced by global economic activity, geopolitical conflicts (Russia-Ukraine, Middle East), OPEC+ actions, and supply/demand dynamics. While natural gas prices were higher in Q3 2025, oil prices were lower, and NGL prices also declined, partially offsetting natural gas gains. The industry is also navigating regulatory changes, such as the 'One Big Beautiful Bill Act' (OBBBA) which provides tax benefits like permanent 100% bonus depreciation and delayed waste emissions charges, and evolving EPA rules on climate disclosures and methane emissions, which are currently subject to litigation and delays. Inflation in oilfield services costs (e.g., diesel, steel, labor) remains a concern, potentially impacting drilling and operating expenses. Pipeline capacity constraints, particularly the Waha-Henry Hub natural gas basis differential in the Delaware Basin, continue to affect realized prices for some producers.

Comparison to Industry Standards

• NA

Corporate Governance

Legal Proceedings

• The company is a party to several legal proceedings encountered in the ordinary course of its business, which management believes are remote to have a material adverse impact on financial condition, results of operations, or cash flows.
• Litigation challenging the SEC's climate-related disclosure rules is ongoing, with the U.S. Court of Appeals for the Eighth Circuit holding the case in abeyance after the SEC requested to proceed and then voted to end its defense of the rules.

Related Party Transactions

• San Mateo Midstream, LLC, a joint venture with a subsidiary of Five Point Infrastructure LLC, distributed $36.2 million to Matador and $34.8 million to Five Point in Q3 2025.
• For the nine months ended September 30, 2025, San Mateo distributed $101.0 million to Matador and $97.0 million to Five Point.
• Five Point paid Matador $9.2 million in performance incentives during the nine months ended September 30, 2025.
• Matador has dedicated current and certain future leasehold interests in various asset areas to San Mateo under 15-year, fixed-fee operational agreements, with a remaining minimum contractual obligation of approximately $758.2 million at September 30, 2025.

Stakeholder Impact

• Shareholders: Positively impacted by increased dividends and share repurchase program, but negatively impacted by decreased net income and EPS. Exposed to commodity price volatility.
• Employees: Positively impacted by increased compensation expenses and the addition of new employees to support company growth.
• Customers (Midstream): Positively impacted by increased third-party midstream services revenues and expanded pipeline operations.
• Creditors: Positively impacted by the company's compliance with debt covenants and the increase in San Mateo's credit facility commitments. Negatively impacted by increased interest expense.
• Joint Venture Partner (Five Point): Receives distributions from San Mateo Midstream, LLC.

Next Steps

• Continue the development of Delaware Basin assets, with a focus on drilling and completing longer horizontal wells.
• Evaluate opportunistic acquisitions of producing properties, acreage, mineral interests, and midstream assets, primarily in the Delaware Basin.
• Consider divesting non-core assets and monetizing other assets, such as certain midstream assets and mineral and royalty interests.
• Monitor and adjust capital expenditures based on market conditions, actual costs, drilling results, and other factors.
• Utilize commodity derivative financial instruments to mitigate exposure to fluctuations in oil, natural gas, and NGL prices.
• Pay the increased quarterly cash dividend of $0.375 per share on December 5, 2025.
• Adopt new accounting pronouncements, ASU 2023-09 and ASU 2024-03, in future reporting periods.

Key Dates

Recommendation

While Matador Resources demonstrates strong operational growth with increased oil and natural gas production and a commitment to shareholder returns through an increased dividend and share repurchase program, the significant decline in net income and diluted EPS for Q3 and 9M 2025 is a concern. This decline is primarily attributed to lower realized oil prices and a substantial increase in operating expenses across various categories, including interest expense. The company's increased capital expenditure budget for 2025, while aimed at growth, will require careful monitoring of returns. Given the mixed financial performance, coupled with ongoing commodity price volatility and regulatory uncertainties, a 'hold' recommendation is appropriate for a seasoned investor. The company has solid assets and strategic plans, but profitability pressures warrant caution.

Keywords

Oil and Gas, Delaware Basin, Midstream, Exploration and Production, Wolfcamp, Bone Spring, Haynesville Shale, Natural Gas Processing, Oil Transportation, Produced Water Disposal, SEC Filing, 10-Q, Financial Results, Capital Expenditures, Dividends, Share Repurchase, Commodity Prices, San Mateo Midstream, Adjusted EBITDA