10-Q: ProPetro Q3 2025: Revenue Falls, Power Gen Segment Emerges

ProPetro Holding Corp. reports a significant revenue decline in Q3 2025 and year-to-date, driven by decreased customer activity and pricing pressure, while its new Power Generation segment begins revenue-generating activities.

Summary

• Net income for the nine months ended September 30, 2025, was $82 thousand, a substantial improvement from a net loss of $120.8 million in the prior year period.
• Net loss for the three months ended September 30, 2025, was $2.4 million, compared to a net loss of $137.1 million in the same period last year.
• Total revenue decreased by 18.6% to $293.9 million for the three months ended September 30, 2025, and by 12.8% to $979.5 million for the nine months ended September 30, 2025, primarily due to decreased customer activity and pricing pressure.
• The Hydraulic Fracturing segment, the largest revenue contributor, experienced a 23.3% revenue decrease in Q3 2025 and a 15.2% decrease year-to-date.
• The new Power Generation segment (PROPWR) commenced revenue-generating activities in Q3 2025, contributing $0.2 million in revenue for both the three and nine months ended September 30, 2025.
• Adjusted EBITDA declined by 50.6% to $35.2 million in Q3 2025 and by 31.7% to $157.5 million year-to-date.
• Capital expenditures incurred for the nine months ended September 30, 2025, totaled $210.1 million, with $139.7 million allocated to the Power Generation segment.
• Cash and cash equivalents increased to $66.5 million at September 30, 2025, from $50.4 million at December 31, 2024.
• Total liquidity, including cash and ABL Credit Facility availability, was approximately $157.6 million at September 30, 2025.
• The share repurchase program was extended through December 31, 2026, with $89.2 million remaining authorized, though no repurchases were made in Q3 or YTD 2025.
• The company sold its cementing business in Vernal, Utah, in November 2024 for a $13.0 million promissory note, recognizing an $8.2 million gain on disposal.
• The AquaProp acquisition in May 2024 contributed $41.6 million in revenues and $34.1 million in cost of services to the Hydraulic Fracturing segment for the nine months ended September 30, 2025.

Sentiment

Score: 4

Explanation: While the company achieved net income for the nine-month period and is strategically investing in lower-emissions and power generation, the significant revenue and Adjusted EBITDA declines in its core hydraulic fracturing business, coupled with a challenging market environment (lower rig count, commodity prices, inflation), indicate headwinds. The new power generation segment is still in its early, loss-making phase.

Positives

• Net income for the nine months ended September 30, 2025, was $82 thousand, a significant improvement from a net loss of $120.8 million in the prior year, indicating a return to profitability on a year-to-date basis.
• Cash and cash equivalents increased to $66.5 million at September 30, 2025, from $50.4 million at December 31, 2024, demonstrating improved cash management.
• Total liquidity, including ABL Credit Facility availability, was approximately $157.6 million at September 30, 2025, providing financial flexibility.
• The Power Generation segment (PROPWR) began revenue-generating activities in Q3 2025, marking a strategic diversification into a new growth area.
• Wireline segment revenue increased by 8.8% in Q3 2025 due to increased customer activity, showing strength in a complementary service line.
• The share repurchase program was extended through December 31, 2026, with $89.2 million remaining authorization, signaling management's confidence in the company's intrinsic value and future cash flow generation.
• The company recorded a $2.3 million unrealized gain on short-term investment for the nine months ended September 30, 2025.
• Tax refunds (net of advisory fees) totaling $2.3 million contributed to other income for the nine months ended September 30, 2025.

Negatives

• Total revenue decreased significantly by 18.6% in Q3 2025 and 12.8% year-to-date, primarily driven by decreased customer activity and pricing pressure in the core hydraulic fracturing business.
• Adjusted EBITDA saw a substantial decline of 50.6% in Q3 2025 and 31.7% year-to-date, reflecting reduced profitability from operations.
• The Hydraulic Fracturing segment's cost of services as a percentage of revenue increased to 81.3% in Q3 2025 from 73.9% in Q3 2024, indicating margin compression due to customer price decreases and general cost inflation.
• The new Power Generation segment reported a negative Adjusted EBITDA of $(4.1) million in Q3 2025 and $(7.1) million year-to-date, as initial investments and operational costs outweigh nascent revenues.
• Loss on disposal of assets increased significantly to $13.4 million for the nine months ended September 30, 2025, from $0.2 million in the prior year, due to the sale of Tier II hydraulic fracturing equipment.
• The Permian Basin rig count decreased to 251 at the end of September 2025 from 304 at the end of 2024, indicating a reduction in overall demand for completion services.
• WTI crude oil prices declined to approximately $64 per barrel in September 2025, reflecting a challenging commodity price environment.

Risks

• Changes in general economic and geopolitical conditions, including regulatory changes, prolonged government shutdowns, higher interest rates, inflation, potential economic recession, and changes in U.S. trade policy (e.g., tariffs), could adversely affect business and results of operations.
• Central bank policy actions and associated liquidity risks may impact financial stability.
• The severity and duration of world events and armed conflicts (e.g., Russian-Ukraine war, Israel-Gaza region conflicts, Middle East hostilities) could cause repercussions to oil and gas supply/demand and the economy.
• Actions taken by OPEC+ regarding oil production levels and compliance with supply limitations could impact crude oil prices.
• Governmental actions, such as executive orders or new climate-related regulations, may negatively impact future oil and natural gas production in the United States.
• Cost increases and supply chain constraints, including delays due to increased hostilities in the Middle East or increased tariffs, could affect service costs.
• Competitive conditions in the energy services industry, including pricing pressures, could impact market share and profitability.
• The ability to attract and retain employees is crucial for operations and could be challenging.
• Changes in the long-term supply of, and demand for, oil and natural gas could affect service demand.
• Actions taken by customers, suppliers, competitors, and third-party operators, and the possible loss of customers or work to competitors, pose ongoing business risks.
• Technological changes, including advancements in lower emissions energy service equipment, require continuous adaptation and investment.
• Changes in the availability and cost of capital, including higher interest rates, could impact financing and growth projects.
• The ability to successfully implement business plans, including potential mergers and acquisitions, is subject to execution risks.
• Large or multiple customer defaults, including those resulting from actual or potential insolvencies, could impact accounts receivable.
• The effects of consolidation on customers or competitors could alter market dynamics.
• The ability to complete growth projects on time and on budget is critical for strategic initiatives.
• Increases in tax rates or types of taxes specifically impacting E&P and related operations could increase tax liabilities.
• Regulatory and related policy actions intended to reduce fossil fuel use or drive renewable energy substitution may reduce demand for oil and gas services over time.
• New or expanded regulations that materially limit customer access to federal and state lands for oil and gas development could reduce demand for services in affected areas.
• Growing demand for electric vehicles could reduce demand for gasoline and, consequently, for oil and gas services.
• The ability to successfully implement technological developments and enhancements, such as new Tier IV DGB dual-fuel and FORCE electric-powered hydraulic fracturing equipment, is essential for competitive positioning.
• Successfully growing the new power generation business line (PROPWR) is subject to market acceptance and operational challenges.
• The development of alternative power generation technologies or increased grid capacity could reduce the demand for PROPWR services.
• Operating hazards, natural disasters, weather-related delays, and casualty losses, which may be self-insured or not fully covered, pose operational and financial risks.
• Exposure to cyber-security events could cause operational disruptions or reputational harm.
• Acts of terrorism, war, or political or civil unrest could impact operations and market conditions.
• The effects of current and future litigation could result in significant costs and expenses.
• Uncertainty and changes in U.S. trade policies, including the imposition of tariffs (e.g., 25% on steel imports, 10% on product imports from foreign countries), could increase material input costs and adversely affect returns on investment if not passed through to customers.
• If the Permian Basin rig count or market conditions do not improve or decline, and the company is unable to increase pricing or pass-through future cost increases to customers, there could be a material adverse impact on business, results of operations, and cash flows.
• Future cash flows are highly dependent on the drilling, completion, and production activity by customers and the demand for power generation services, which in turn is highly dependent on oil and natural gas prices.

Future Outlook

The company projects capital expenditures for 2025 to be between $270 million and $290 million, with a significant portion ($190 million) dedicated to the PROPWR power generation business. It anticipates receiving remaining power generation equipment from Q4 2025 through early 2027. The company plans to accelerate the phase-out of its Tier II diesel-only hydraulic fracturing pumping units, shortening their useful lives to no later than the end of 2027, in response to decreasing customer demand for conventional equipment. Decisions regarding equipment retirement, conversion, or addition of lower emissions equipment will be influenced by market conditions, equipment availability, supply chain, commodity prices, customer demand, and projected returns. Funding for capital expenditures is expected to come from existing cash, operating cash flows, the PROPWR Equipment Loan Agreement, other financing arrangements, and potentially the ABL Credit Facility. The company acknowledges that future cash flows are highly dependent on customer drilling, completion, and production activity, and demand for power generation services, which are sensitive to volatile oil and natural gas prices. Improved Permian Basin rig count and market conditions, including better pricing and labor availability, are expected to improve operational and financial results.

Management Comments

• We believe that our substantial market presence in the Permian Basin positions us well to capitalize on drilling and completion activity and power demand in the region.
• We believe many of our customers elect to work with us based on our operational efficiencies, productivity, equipment portfolio and quality, reliability, ability to manage multifaceted logistics challenges, commitment to safety and the ability of our people to handle the most complex Permian Basin well completions and power generation challenges.
• We have recently observed the energy industry and our customers shift to lower emissions equipment, which we believe will be an increasingly important factor in an E&P company's selection of a service provider.
• The transition to lower emissions equipment is quickly evolving and has been and will be capital intensive.
• Over time, we plan to replace our conventional Tier II diesel-only hydraulic fracturing pumping units and associated conventional assets ('Tier II Units') with lower emissions equipment.
• If the Permian Basin rig count and market conditions improve, including improved pricing for our services and labor availability, and we are able to meet our customers' lower emissions equipment demands, we believe our operational and financial results will also improve.
• Our management believes that we have recorded adequate accruals for any liabilities that may reasonably be expected to result from these matters (legal proceedings).
• Currently, we have not been fined, cited or notified of any environmental violations that would have a material adverse effect upon our financial position, liquidity or capital resources.

Industry Context

The oil and gas industry continues to be volatile, influenced by global supply and demand, commodity prices, and E&P capital investments. Geopolitical events, such as the Russian-Ukraine war and Middle East conflicts, along with OPEC+ actions, contribute to market instability. WTI crude oil prices declined to approximately $64 per barrel in September 2025, partly due to U.S. tariff policies and global supply concerns. The Permian Basin rig count decreased from 304 at the end of 2024 to 251 at the end of September 2025, indicating a broader industry slowdown in drilling and completion activity. There is an ongoing industry-wide shift towards lower emissions equipment, which is capital intensive. ProPetro is actively participating in this transition with its Tier IV DGB dual-fuel and FORCE electric fleets. The company also notes the Permian Basin's significant natural gas production as a natural market for power-intensive businesses like data centers, aligning with its new PROPWR power generation segment. Competition remains high from both large and small energy service companies.

Comparison to Industry Standards

• The company operates in a highly competitive market alongside peers such as Halliburton Company, Liberty Energy Inc., Patterson-UTI Energy Inc., ProFrac Holding Corp., Solaris Energy Infrastructure, Inc., and RPC, Inc.
• The decline in the Permian Basin rig count to 251 at the end of September 2025 reflects a broader industry trend of reduced drilling and completion activity, impacting demand for services across the sector.
• The WTI crude oil price decline to approximately $64 per barrel in September 2025 indicates a challenging commodity price environment that affects all E&P companies and their service providers.
• ProPetro's transition to approximately 75% lower emissions equipment as of September 30, 2025, aligns with the industry's evolving demand for more environmentally friendly solutions, a factor increasingly important in E&P company selection.
• The company's focus on operational efficiencies, productivity, equipment quality, reliability, and safety are key competitive factors in the energy services industry, consistent with what leading providers emphasize.

Corporate Governance

Legal Proceedings

• The company is named in various claims, lawsuits, or threatened actions in the ordinary course of business, which management intends to defend vigorously. No material adverse effect on financial position, results of operations, or cash flows is expected.
• A routine audit by the Texas Comptroller of Public Accounts for motor vehicle and other related fuel taxes (July 2015-December 2020) is substantially complete, with an estimated settlement expense of $6.0 million accrued.
• A routine audit by the Texas Comptroller of Public Accounts for gross receipt taxes (covering up to a four-year period), commenced in May 2022, is nearing completion, with an estimated settlement expense of $0.8 million accrued.

Related Party Transactions

• Rented three yards from an entity in which a director has an equity interest, incurring $18 thousand in rent expense during the nine months ended September 30, 2025.
• Provides pressure pumping, wireline, and other services to ExxonMobil (including XTO Energy Inc.), which became the owner of 16.6 million shares of ProPetro common stock after Pioneer Natural Resources merged with ExxonMobil in May 2024. Revenue from these services was $79.4 million for Q3 2025 and $223.7 million for YTD 2025.
• Accounts receivable due from ExxonMobil (including Pioneer and XTO) amounted to approximately $69.1 million as of September 30, 2025.
• Sold its cementing business in Vernal, Utah, to Big 4 Services LLC, solely owned by a former employee, for a $13.0 million promissory note. The company recorded $0.9 million in interest income from this note for the nine months ended September 30, 2025.

Stakeholder Impact

• Shareholders are impacted by the significant revenue and Adjusted EBITDA declines in the core business, but also by strategic investments in new growth areas (power generation, lower emissions equipment) and the ongoing share repurchase program. The return to year-to-date net income provides some positive signal amidst Q3 losses.
• Employees are affected by the company's strategic repositioning, such as the sale of the cementing business, and the company's ability to attract and retain talent remains a key operational factor.
• Customers are experiencing decreased activity and pricing pressures, which in turn impacts the company's revenue. The transition to lower emissions equipment aims to meet evolving customer demands.
• Suppliers face potential impacts from supply chain constraints and cost increases, and the company has minimum volume purchase agreements with sand suppliers.
• Creditors are affected by the company's debt obligations (ABL Credit Facility, PROPWR Equipment Loan Agreement) and its liquidity management, which appears stable with $157.6 million in total liquidity.

Next Steps

• Receive remaining power generation equipment under contractual arrangements from Q4 2025 through late 2026/early 2027.
• Fund projected capital expenditures for 2025, estimated between $270 million and $290 million, with a focus on the PROPWR business.
• Continue to evaluate the emissions profile of equipment and potentially convert or retire additional conventional Tier II equipment in favor of lower emissions equipment.
• Potentially repurchase shares under the extended share repurchase program through December 31, 2026, with $89.2 million remaining authorization.
• Continue to evaluate the potential impacts of the 'One Big Beautiful Bill Act' (OBBBA) tax law changes.
• Plan to adopt ASU No. 2025-05 for the fiscal year beginning January 1, 2026.
• Assess the impact of ASU No. 2023-09 and ASU No. 2024-03/2025-01 on condensed consolidated financial statements.

Key Dates

Recommendation

ProPetro is navigating a challenging market with significant revenue and Adjusted EBITDA declines in its core hydraulic fracturing business, exacerbated by lower rig counts and commodity prices. However, the company is actively executing a strategic transition towards lower-emissions equipment and a new power generation segment (PROPWR), which, while currently loss-making, represents a forward-looking diversification. The positive net income for the nine-month period, despite a Q3 loss, and healthy liquidity provide some stability. The ongoing share repurchase program also signals management's confidence. The long-term success hinges on the effective execution of the lower-emissions transition and the growth of the PROPWR business, against a backdrop of volatile industry conditions and capital intensity. Investors should hold to observe the progress of these strategic initiatives and the company's ability to improve profitability in its evolving business model.

Keywords

hydraulic fracturing, power generation, oil and gas services, Permian Basin, lower emissions equipment, financial results, Q3 2025, revenue, EBITDA, capital expenditures, share repurchase, energy services, wireline, cementing, AquaProp, PROPWR, ExxonMobil, tariffs, inflation, rig count, debt, SEC filing, 10-Q, PUMP