10-Q: Matador Resources Reports Q2 Profit Decline Amid Lower Oil Prices, Production Soars

Matador Resources Company experienced a significant drop in net income and diluted earnings per share in the second quarter of 2025 despite robust oil and natural gas production growth and increased midstream revenues, primarily due to lower realized oil prices and rising expenses.

Summary

• Net income attributable to Matador shareholders decreased by 34.4% to $150.2 million for the three months ended June 30, 2025, compared to $228.8 million in the prior year period.
• Diluted earnings per common share fell to $1.21 for Q2 2025, down from $1.83 for Q2 2024.
• Total oil equivalent production for Q2 2025 was 19.0 million BOE, with average daily production of 209,013 BOE per day, representing a 30% year-over-year increase.
• Oil production increased 29% to 11.2 million Bbl for Q2 2025, while natural gas production rose 33% to 47.0 Bcf.
• Realized oil prices decreased by 21% to $64.34 per Bbl in Q2 2025, from $81.20 per Bbl in Q2 2024.
• Realized natural gas prices increased by 2.5% to $2.05 per Mcf in Q2 2025, from $2.00 per Mcf in Q2 2024.
• Adjusted EBITDA increased by 2.8% to $594.2 million for Q2 2025, compared to $578.1 million for Q2 2024.
• Third-party midstream services revenues grew by 29% to $42.0 million for Q2 2025.
• Total revenues increased by 5.7% to $895.3 million for Q2 2025.
• Lease operating expenses increased by 34% to $105.7 million, and depletion, depreciation, and amortization expenses rose by 34% to $302.6 million for Q2 2025.
• Interest expense increased by 48% to $53.3 million for Q2 2025.
• The company repurchased 1,095,667 shares of common stock for $44.2 million under its $400.0 million share repurchase program during Q2 2025.
• The Board declared a quarterly cash dividend of $0.3125 per share for Q3 2025, consistent with prior quarters.
• The San Mateo Credit Facility commitments were increased from $800.0 million to $850.0 million in June 2025.
• The 'One Big Beautiful Bill Act' (OBBBA), signed into law on July 4, 2025, is expected to reduce cash tax payments to 0% to 5% of income before income taxes for 2025.
• Estimated drilling, completing, and equipping (D/C/E) capital expenditures for 2025 remain $1.18 billion to $1.37 billion, and midstream capital expenditures remain $120.0 million to $180.0 million.

Sentiment

Score: 4

Explanation: While production and Adjusted EBITDA showed growth, net income and diluted EPS significantly declined due to lower realized oil prices and increased operating, depreciation, and interest expenses. The company is managing capital effectively through share repurchases and consistent dividends, and a new tax law is expected to reduce future cash tax payments. However, the core profitability metric (net income) is a concern.

Positives

• Oil production increased by 29% to 11.2 million Bbl for the three months ended June 30, 2025, demonstrating strong operational growth.
• Natural gas production increased by 33% to 47.0 Bcf for the three months ended June 30, 2025, contributing to overall volume expansion.
• Average daily oil equivalent production rose by 30% year-over-year to 209,013 BOE per day in Q2 2025.
• Adjusted EBITDA increased by 2.8% to $594.2 million for Q2 2025, indicating improved operational cash flow before non-cash items and financing costs.
• Third-party midstream services revenues grew by 29% to $42.0 million for Q2 2025, reflecting strong performance in the midstream segment.
• The Board authorized a $400.0 million share repurchase program, with $44.2 million already executed in Q2 2025, signaling confidence and returning capital to shareholders.
• Consistent quarterly cash dividends of $0.3125 per share were declared for Q1, Q2, and Q3 2025, providing stable shareholder returns.
• The San Mateo Credit Facility commitments were increased from $800.0 million to $850.0 million, enhancing liquidity for midstream operations.
• The 'One Big Beautiful Bill Act' is expected to significantly reduce cash tax payments to 0% to 5% of income before income taxes for the year ending December 31, 2025.
• The Marlan Processing Plant Expansion, a key midstream project, came online in the second quarter of 2025, expanding processing capacity.

Negatives

• Net income attributable to Matador shareholders decreased significantly by 34.4% to $150.2 million for Q2 2025, compared to $228.8 million in Q2 2024.
• Diluted earnings per common share declined by 33.8% to $1.21 for Q2 2025, from $1.83 for Q2 2024.
• Realized oil prices decreased substantially by 21% to $64.34 per Bbl in Q2 2025, from $81.20 per Bbl in Q2 2024, negatively impacting revenues.
• Lease operating expenses increased by 34% to $105.7 million for Q2 2025, driven by an increased number of operated wells and operating cost inflation.
• Depletion, depreciation, and amortization expenses rose by 34% to $302.6 million for Q2 2025, primarily due to increased production volumes.
• Interest expense increased by 48% to $53.3 million for Q2 2025, mainly due to an increase in total senior notes outstanding.
• The company reported an unrealized loss on derivatives of $37.3 million for Q2 2025, reflecting changes in the fair value of hedging instruments.
• Net cash used in financing activities for the six months ended June 30, 2025, was $230.2 million, a significant shift from net cash provided of $16.3 million in the prior year period.
• The company expects to reduce its drilling rigs from nine to eight by August 1, 2025, indicating a slight slowdown in drilling activity.

Risks

• General economic conditions can impact business success and financial results.
• Ability to execute the business plan, including the success of the drilling program, is uncertain.
• Changes in oil, natural gas, and natural gas liquids (NGL) prices and demand can significantly affect profitability.
• Ability to replace reserves and efficiently develop current reserves is critical for long-term success.
• Operating results of the midstream business, including acquiring third-party business and drilling additional salt water disposal wells, are subject to various factors.
• Costs of operations, including oilfield services, can fluctuate and impact profitability.
• Delays and other difficulties related to producing oil, natural gas, and NGLs may occur.
• Delays and other difficulties related to regulatory and governmental approvals and restrictions pose risks.
• Impact on operations due to seismic events is a potential concern.
• Availability of sufficient capital to execute the business plan, including from future cash flows, capital markets, and borrowing capacity, is not assured.
• Ability to make acquisitions on economically acceptable terms and integrate them successfully is uncertain.
• Operating results of and availability of any potential distributions from joint ventures may vary.
• Weather and environmental conditions can disrupt operations.
• Acquisitions may cause disruption, making it difficult to maintain business and operational relationships.
• Significant transaction costs may be associated with acquisitions.
• Risk of litigation and/or regulatory actions related to acquisitions exists.
• Availability of drilling and production equipment, oil storage capacity, and oil field labor can impact operations.
• Government regulation and taxation of the oil and natural gas industry can increase costs and affect profitability.
• Tariffs and trade restrictions may affect costs for and availability of raw materials, equipment, and other inputs.
• Environmental liabilities are a potential risk.
• Counterparty credit risk exists for derivative financial instruments.
• Geopolitical instability and developments in oil-producing and natural gas-producing countries, including ongoing military conflicts, can impact commodity prices.
• Commodity price volatility, including WTI oil price, NYMEX Henry Hub natural gas price, and basis differentials (Midland-Cushing, Waha-Henry Hub), is a significant risk.
• Pipeline-related interruptions to oil, natural gas, NGL production, or produced water disposal can adversely affect operations.
• Shortages of NGL fractionation capacity could arise.
• Future periods of negative natural gas pricing may necessitate temporary well shut-ins.
• Inflation in the costs of certain oilfield services (diesel, steel, labor, trucking, sand, personnel, completion) can increase operational costs.
• Supply chain disruptions can limit the ability to procure necessary products and services.
• Natural production declines from oil and natural gas wells require continuous drilling and development.
• Ability to find and develop sufficient quantities of oil and natural gas reserves at economical costs is critical.
• Litigation challenging SEC climate-related disclosure rules creates regulatory uncertainty.
• The underlying law mandating the waste emissions charge remains in effect despite the removal of EPA rules, with collection delayed until 2034.

Future Outlook

The company expects to operate eight drilling rigs by August 1, 2025, down from nine at the beginning of 2025, maintaining flexibility in its drilling program based on commodity prices. Estimated drilling, completing, and equipping capital expenditures for 2025 remain between $1.18 billion and $1.37 billion, with midstream capital expenditures projected at $120.0 million to $180.0 million. The primary focus for capital allocation will be the delineation and development of Delaware Basin assets, midstream infrastructure, and non-operated well opportunities. The company intends to continue evaluating opportunistic acquisitions and may divest non-core assets or monetize other assets. Due to the 'One Big Beautiful Bill Act,' cash tax payments for 2025 are expected to be significantly lower, ranging from 0% to 5% of income before income taxes. Future success is highly dependent on generating operating cash flows and accessing external capital, with continued use of derivative financial instruments to mitigate commodity price risk.

Management Comments

• We began 2025 operating nine drilling rigs in the Delaware Basin and expect to operate eight drilling rigs by August 1, 2025.
• 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 expect to fund our 2025 capital expenditures through a combination of cash on hand, operating cash flows and performance incentives paid to us by Five Point Infrastructure LLC or its affiliates.
• 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.
• There can be no assurance regarding the exact number of shares to be repurchased by the Company, if any.
• We believe that we were in compliance with the terms of the Credit Agreement at June 30, 2025.
• We believe that San Mateo was in compliance with the terms of the San Mateo Credit Facility at June 30, 2025.
• We expect that development of our Delaware Basin assets will be the primary focus of our operations and capital expenditures for the remainder of 2025.
• Our 2025 capital expenditures may be adjusted as business conditions warrant, and the amount, timing and allocation of such expenditures is largely discretionary and within our control.
• We now expect to make cash tax payments of approximately 0% to 5% of income before income taxes for the year ending December 31, 2025 at current commodity prices.
• Should we experience future periods of negative pricing for natural gas, as we have experienced historically, including in 2024, we may temporarily shut in certain high gas-oil ratio wells and take other actions to mitigate the impact on our realized natural gas prices and results.
• Our ability to find and develop sufficient quantities of oil and natural gas reserves at economical costs is critical to our long-term success.
• While the ultimate outcome and impact on us cannot be predicted with certainty, in the opinion of management, it is remote that these legal proceedings will have a material adverse impact on our financial condition, results of operations or cash flows.

Industry Context

Matador Resources operates within the highly volatile oil and natural gas industry, primarily focused on the Delaware Basin. The company's performance is significantly influenced by fluctuating commodity prices, which saw lower oil prices but higher natural gas prices in Q2 2025 compared to the prior year. Geopolitical instability and actions by OPEC+ continue to impact global supply and demand dynamics. The industry also faces challenges from inflation in oilfield services costs, supply chain disruptions, and tariffs. Regulatory changes, such as the 'One Big Beautiful Bill Act' impacting tax payments and ongoing litigation regarding SEC climate disclosure rules, add to the complex operating environment. The company's midstream segment, San Mateo Midstream, plays a crucial role in providing flow assurance and services to third parties, reflecting a broader industry trend towards integrated operations to manage takeaway capacity and processing needs.

Legal Proceedings

• The company is a party to several legal proceedings encountered in the ordinary course of its business.
• Management believes it is remote that these legal proceedings will have a material adverse impact on the company's financial condition, results of operations, or cash flows.
• No material changes regarding previously disclosed legal proceedings occurred during Q2 2025.
• Litigation challenging the SEC's climate-related disclosure rules is ongoing, with the SEC voluntarily delaying implementation and later voting to end the defense of the rules.
• The Environmental Protection Agency's waste emissions charge rules were nullified by a Joint Resolution of Disapproval, but the underlying law mandating the charge remains in effect, with collection delayed until 2034 by the OBBBA.

Related Party Transactions

• San Mateo Midstream, LLC, a joint venture with Five Point Infrastructure LLC, distributed $29.6 million to the company and $28.4 million to Five Point during Q2 2025.
• Five Point paid the company $6.4 million of performance incentives during Q2 2025.

Stakeholder Impact

• Shareholders: Experienced a significant decrease in net income and diluted EPS, but benefited from a consistent quarterly cash dividend of $0.3125 per share and the initiation of a $400.0 million share repurchase program.
• Employees: Increased general and administrative expenses due to increased compensation and the addition of new employees to support growth.
• Customers (Third-party midstream): Benefited from increased midstream services, with revenues from third-party natural gas gathering and processing, and oil transportation services showing growth.
• Creditors: The company maintained compliance with the terms of its Credit Agreement and San Mateo Credit Facility, and the San Mateo Credit Facility commitments were increased, indicating continued financial stability for lenders.
• Joint Venture Partner (Five Point Infrastructure LLC): Received distributions from San Mateo Midstream and paid performance incentives to Matador, indicating ongoing collaboration and financial activity within the joint venture.

Next Steps

• Operate eight drilling rigs by August 1, 2025, in the Delaware Basin.
• Focus 2025 capital expenditures on the continued delineation and development of Delaware Basin assets.
• Continue construction, installation, and maintenance of midstream assets.
• Participate in certain non-operated well opportunities.
• Evaluate opportunistic acquisitions of producing properties, acreage, mineral interests, and midstream assets, principally in the Delaware Basin.
• Consider divesting portions of 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, costs, drilling results, and other factors.
• Continue to use commodity derivative financial instruments to mitigate exposure to oil, natural gas, and NGL price volatility.
• Evaluate the full impact of the 'One Big Beautiful Bill Act' on consolidated financial statements.
• Pay a quarterly cash dividend of $0.3125 per share on September 5, 2025, to shareholders of record as of August 15, 2025.

Key Dates

Recommendation

While Matador Resources Company demonstrated strong production growth in both oil and natural gas, and increased its Adjusted EBITDA, the significant decline in net income and diluted EPS is a concern. This profitability erosion is primarily driven by lower realized oil prices and rising operating, depreciation, and interest expenses. The company's strategic financial management, including a share repurchase program and consistent dividends, provides some support. Additionally, the 'One Big Beautiful Bill Act' is expected to reduce future cash tax payments, which is a positive. However, the core challenge of translating production growth into improved bottom-line profitability, especially amidst volatile commodity prices and rising costs, suggests a 'Hold' recommendation. Investors should monitor the company's ability to improve net income margins and manage expenses in the coming quarters.

Keywords

Oil and Gas, Exploration and Production, Midstream, Delaware Basin, Wolfcamp, Bone Spring, Haynesville Shale, Natural Gas, Oil, NGLs, SEC Filing, 10-Q, Financial Results, Production Volumes, Adjusted EBITDA, Share Repurchase, Dividends, Capital Expenditures, Commodity Prices, San Mateo Midstream, Energy Sector, Corporate Governance, Risk Management