UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

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FORM 10-K

______________________________


☒			ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, ~~2024~~2025


☐			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-38035

______________________________

ProPetro Holding Corp.

(Exact name of registrant as specified in its charter)

______________________________


Delaware			26-3685382
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

~~303~~One WMarienfeld Place, 110 N. ~~Wall~~Marienfeld Street, Suite ~~102~~300, Midland, Texas 79701

(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code: (432) 688-0012

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock ($0.001 par value)	PUMP	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

None

______________________________________________________

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ý No ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ¨ No ý

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ý No ¨

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ý No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer ý☐ Accelerated filer ☐ý Non-accelerated filer ☐(Do not check if a smaller reporting company) Smaller reporting company ☐ Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ý

The aggregate market value of the Company’s Common Stock held by nonaffiliates on June 30, ~~2024~~2025, determined using the per share closing price on the New York Stock Exchange Composite tape of $85.6797 on that date, was approximately $~~753~~513.46 million.

The number of the registrant’s common shares, par value $0.001 per share, outstanding at February 1413, ~~2025~~2026, was ~~103~~122,~~168~~024,~~656~~047.

Documents incorporated by reference: Portions of the registrant’s definitive proxy statement relating to the registrant’s 2026 Annual Meeting of Stockholders are incorporated by reference into Part III of this annual report.

TABLE OF CONTENTS

FORWARD-LOOKING STATEMENTS			i
SUMMARY OF RISK FACTORS			iii
PART I
BUSINESS			1
RISK FACTORS			1514
UNRESOLVED STAFF COMMENTS			33
CYBERSECURITY			33
PROPERTIES			34
LEGAL PROCEEDINGS			34
MINE SAFETY DISCLOSURES			34
PART II
MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES			34
SELECTED FINANCIAL DATA			36
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS			37
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK			5254
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA			5355
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE			102
CONTROLS AND PROCEDURES			102
OTHER INFORMATION			~~103~~102
DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS			~~103~~102
PART III
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE			103
EXECUTIVE COMPENSATION			103
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS			103
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE			103
PRINCIPAL ACCOUNTING FEES AND SERVICES			103
PART IV
EXHIBITS AND FINANCIAL SCHEDULES			104
FORM 10-K SUMMARY			~~106~~107
SIGNATURES			~~107~~108

FORWARD‑LOOKING STATEMENTS

This Annual Report on Form 10-K (the “Annual Report”) contains forward‑looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities and Exchange Act of 1934, as amended (the “Exchange Act”). All statements other than statements of historical facts contained in this Form 10-K are forward-looking statements. Forward-looking statements are all statements other than statements of historical fact, and ~~given~~give our expectations or forecasts of future events as of the effective date of this Form 10-K. Words such as “may,” “could,” “plan,” “project,” “budget,” “predict,” “pursue,” “target,” “seek,” “objective,” “believe,” “expect,” “anticipate,” “intend,” “estimate,” “will,” “should,” “continue” and similar expressions are generally used to identify forward-looking statements. These statements include, but are not limited to, statements about our business strategy, industry, future profitability, future capital expenditures, our fleet conversion strategy, our ~~new~~ power generation business development strategy and our share repurchase program. Such statements are subject to risks and uncertainties., ~~Many~~many of which are difficult to predict and generally beyond our control, that could cause actual results to differ materially from those implied or projected by the forward-looking statements. Factors that could cause our actual results to differ materially from ~~those~~the results contemplated by such forward‑looking statements include:

•changes in general economic and geopolitical conditions, including ~~the~~as a result of regulatory changes by the ~~2024~~current presidential ~~election~~administration, higher interest rates, the rate of inflation, a potential economic recession and potential changes in ~~U.S~~the United States’ trade policy, including the imposition of tariffs and the resulting consequences;

•central bank policy actions, ~~bank failures~~ and associated liquidity risks and other factors;

•the severity and duration of any world events and armed conflict, including the Russian-Ukraine war, conflicts in the Israel-Gaza region and continued hostilities in the Middle East, including ~~rising~~those ~~tensions~~between ~~with~~Israel, Iran and the United States, recent events in Venezuela, and associated repercussions to supply and demand for oil and gas and the economy generally;

•the actions taken by the members of the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia (together with OPEC and other allied producing countries, “OPEC+”) with respect to oil production levels and announcements of potential changes in such levels, including the ability of the OPEC+ countries to agree on and comply with supply limitations;

•governmental actions, such as executive orders or new regulations, including climate-related regulations, that may negatively impact the future production of oil and natural gas in the United States and may adversely affect our future operations;

•the level of production and resulting market prices for crude oil, natural gas and other hydrocarbons, including a potential increase in Venezuelan oil supply and any related impact on global oil prices and domestic oil production;

•the effects of existing and future laws and governmental regulations (or the interpretation thereof) on us, our suppliers and our customers;

•cost increases and supply chain constraints related to our services, including any delays and/or supply chain disruptions due to increased hostilities in the Middle East or increased tariffs;

•competitive conditions in our industry;

•our ability to attract and retain employees;

•changes in the long-term supply of, and demand for, oil and natural gas;

•actions taken by our customers, suppliers, competitors and third-party operators and the possible loss of customers or work to our competitors;

•technological changes, including lower emissions energy service equipment and similar advancements;

•changes in the availability and cost of capital that impact the price and availability of debt and equity financing (including higher interest rates) for us and our customers;

•our ability to successfully implement our business plan, including execution of potential mergers and acquisitions;

•large or multiple customer defaults, including defaults resulting from actual or potential insolvencies;

•the effects of consolidation on our customers or competitors;

•the price and availability of debt and equity financing (including higher interest rates) for us and our customers;

•our ability to complete growth projects on time and on budget;

•increases in tax rates or types of taxes enacted that specifically impact exploration and production (“E&P”) and related operations resulting in changes in the amount of taxes owed by us;

•~~regulatory~~increases ~~and~~in ~~related~~tax ~~policy~~rates ~~actions~~or ~~intended~~types byof ~~federal,~~taxes ~~state~~enacted ~~and/or~~that ~~local~~specifically ~~governments~~impact toexploration ~~reduce~~and ~~fossil~~production ~~fuel~~(“E&P”) ~~use~~ and ~~associated~~related ~~carbon~~operations ~~emissions,~~resulting orin tochanges ~~drive~~in the ~~substitution~~amount of ~~renewable~~taxes ~~forms~~owed ofby ~~energy for oil and gas, may over time reduce demand for oil and gas and therefore the demand for our services~~us;

•regulatory and related policy actions intended by federal, state and/or local governments to reduce fossil fuel use and associated carbon emissions, or to drive the substitution of renewable forms of energy for oil and gas, that may over time reduce demand for oil and gas and therefore the demand for our services;

•new or expanded regulations that materially limit our customers’ access to federal and state lands for oil and gas development, thereby reducing demand for our services in the affected areas;

•growing demand for electric vehicles that result in reduced demand for gasoline and therefore the demand for our services;

•our ability to successfully implement technological developments and enhancements, including our new Tier IV Dynamic Gas Blending (“DGB”) dual-fuel and FORCE® electric-powered hydraulic fracturing equipment, power generation equipment, and other lower-emissions equipment we may acquire or that may be sought by our customers;

•our ability to successfully ~~launch and~~ grow our new power generation business line;

•the development of alternative power generation technologies or increased grid capacity that could reduce the demand for our services;

•the projected timing, purchase price and number of shares purchased under our share repurchase program, the sources of funds under the share repurchase program and the impacts of the share repurchase program;

•operating hazards, natural disasters, weather-related suspensions or delays, casualty losses and other matters beyond our control, such as fires, which risks may be self-insured, or may not be fully covered under our insurance programs;

•exposure to cyber-security events which could cause information theft, data corruption, operational disruptions, reputational harm and/or ~~reputational~~financial ~~harm~~loss;

•acts of terrorism, war or political or civil unrest in the United States or elsewhere; and

•the effects of current and future litigation.

Readers are cautioned not to place undue reliance on our forward‑looking statements. Although forward‑looking statements reflect our good faith beliefs at the time they are made, forward‑looking statements involve known and unknown risks, uncertainties and other factors, including the factors described under "Item 1A. Risk Factors" of this Annual Report, which may cause our actual results, performance or achievements to differ materially from anticipated future results, performance or achievements expressed or implied by such forward‑looking statements. We do not undertake, and expressly disclaim, any duty to update or revise any forward‑looking statement, whether as a result of new information, future events, changed circumstances or otherwise, except as required by applicable securities laws.

Unless the context indicates otherwise, all references to “ProPetro Holding Corp.,” “the Company,” “we,” “our” or “us” or like terms refer to ProPetro Holding Corp. and its consolidated subsidiaries, ProPetro Services, Inc., Silvertip Completion Services Operating, LLC, Aqua Prop, LLC and ProPetro Energy Solutions, LLC.

SUMMARY RISK FACTORS

Our business is subject to varying degrees of risk and uncertainty. Investors should consider the risks and uncertainties summarized below, as well as the risks and uncertainties discussed in Part I, “Item 1A. Risk Factors” of this Annual Report. Additional risks not presently known to us or that we currently deem immaterial may also affect us. If any of these risks occur, our business, financial condition or results of operations could be materially and adversely affected.

Our business is subject to the following principal risks and uncertainties:

Risks Inherent in Our Business and Industry

•Our business and financial performance depends on the historically cyclical oil and natural gas industry and particularly on the level of capital spending of ~~exploration and production (“~~E&P”) companies within the United States and in the Permian Basin, and a decline in prices for oil and natural gas may cause fluctuation in operating results or otherwise have an adverse effect on our revenue, cash flows, profitability and growth.

•~~The~~Many ~~cyclical nature~~ of ~~the~~our ~~oil~~power ~~and~~generation ~~natural~~services ~~gas~~involve ~~industry~~long ~~may~~sales ~~cause our operating results to fluctuate~~cycles.

•Our PROPWRSM business line exposes us to the significant risks and uncertainties associated with establishment of a new line of business, and such business line may not achieve the results we anticipate.

•The majority of our operations are located in the Permian Basin, making us vulnerable to risks associated with operating in one major geographic area.

•~~The~~New ~~Inflation~~technology ~~Reduction~~may ~~Act~~cause ofus ~~2022 (“IRA 2022”) could accelerate the transition~~ to abe ~~low~~less ~~carbon economy and could impose new costs on our customers’ operations~~competitive.

•Our business may be adversely affected by a deterioration in general economic conditions or a weakening of the broader energy industry.

•Our operations require substantial capital and we may be unable to obtain needed capital or financing on satisfactory terms, or at all, which could limit our ability to grow.

•Concerns over general economic, business or industry conditions may have a material adverse effect on our results of operations, liquidity and financial condition.

•Our indebtedness and liquidity needs could restrict our operations and adversely affect our financial condition.

•Restrictions in our ~~ABL~~current ~~Credit Facility (as defined herein)~~ and ~~any~~ future financing agreements may limit our ability to finance future operations or capital needs or capitalize on potential acquisitions and other business opportunities.

•We may record losses or impairment charges related to goodwill and long-lived assets, including intangible assets.

•Our operations are subject to unforeseen interruptions and hazards inherent in the oil and natural gas industry, for which we may not be adequately insured and which could cause us to lose customers and substantial revenue.

•AWe ~~terrorist~~are ~~attack,~~subject ~~armed~~to ~~conflict~~cyber orsecurity ~~political~~risks. orA ~~civil~~cyber ~~unrest~~incident could occur and result in information theft, data corruption, operational disruptions, reputational harm ~~our~~and/or ~~business.~~financial loss.

•We may bepursue ~~subject~~acquisitions, tointernal ~~claims~~expansions ~~for~~or ~~personal~~other ~~injury~~strategic transactions, and ~~property~~our ~~damage,~~failure ~~which~~to ~~could~~properly ~~materially~~plan ~~affect~~and ~~our~~manage ~~financial~~such ~~condition~~growth may ~~and~~adversely ~~results~~affect ofour ~~operations~~performance.

•We are subject to cyber security risks. A cyber incident could occur and result in information theft, data corruption, operational disruption and/or financial loss.

•We may grow through acquisitions and/or internal expansion, and our failure to properly plan and manage such growth may adversely affect our performance.

•We may be adversely affected by the effects of inflation.

Risks Related to Customers, Suppliers and Competition

•Reliance upon a few large customers may adversely affect our revenue and operating results.

~~iii~~•We expect to face significant competition in the future as the mobile and modular power industry evolves.

•WeOur ~~face~~customers ~~significant competition that~~ may ~~cause~~not uscontinue to ~~lose~~outsource ~~market~~their ~~share,~~power ~~and~~generation ~~competition in our industry has intensified as a result of customer consolidation and industry downturns~~needs.

•We are exposed to the credit risk of our customers, and any material nonpayment or nonperformance by our customers could adversely affect our business, results of operations and financial conditions.

•Our business depends upon the ability to obtain specialized equipment, parts and key raw materials, including sand and ~~chemicals~~power generation assets, balance of plant components, power distribution equipment and associated ancillary equipment, from third‑party suppliers,. ~~and~~We we may be vulnerable to supply chain disruptions, delayed deliveries and future price increases, which could adversely impact our ability to provide our services.

~~•We may be required to pay fees to certain of our sand suppliers (the “Sand Suppliers”) based on minimum volumes under long-term contracts regardless of actual volumes received.~~iii

•We may be unable to adapt our power generation technologies to meet increasing customer needs and power loads, which could result in increased downtime of our power generation offering and disruptions to the power supply to our customers.

•Distributed power generation services in some applications compete with access to the grid.

Risks Related to Employees

•We rely on a few key employees whose absence or loss could adversely affect our business.

•If we are unable to employ a sufficient number of skilled and qualified workers, our capacity and profitability could be diminished and our growth potential could be impaired.

Risks Related to Regulatory Matters

•We are subject to environmental laws and regulations, and future compliance, claims, and liabilities relating to such matters may have a material adverse effect on our results of operations, financial position or cash flows.

•Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide.

•Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

•~~Increased~~Increasing ~~attention~~trucking toregulations ~~environmental,~~may ~~social~~increase ~~and~~our ~~governance~~costs ~~(“ESG”) matters, conservation measures, commercial development~~ and ~~technological~~negatively ~~advances~~impact ~~could~~our ~~reduce~~results ~~demand~~of ~~for oil and natural gas and our services~~operations.

•Certain of our completion services, particularly our hydraulic fracturing services, are substantially dependent on the availability of water. Restrictions on our or our customers’ ability to obtain water may have an adverse effect on our financial condition, results of operations and cash flows.

Risks Related to ~~our~~ Tax Matters

•Our ability to use our net operating loss carryforwards (“NOLs”) may be limited.

•Changes to applicable tax laws and regulations or exposure to additional tax liabilities could adversely affect our operating results and cash flows.

Risks Inherent to an Investment in our Common Stock

•We are subject to certain requirements of Section 404 of the Sarbanes-Oxley Act (“Section 404”). If we or our auditors identify and report material weaknesses in internal controls over financial reporting, our investors may lose confidence in our reported information, and our stock price may be negatively affected.

•Certain provisions of our certificate of incorporation, and bylaws, as well as Delaware law, may discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.

•Our ~~certificate~~business ofcould ~~incorporation~~be ~~designates~~negatively ~~the~~affected ~~Court~~as ofa ~~Chancery~~result of the ~~State~~actions of ~~Delaware~~activist ~~as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our~~ shareholders~~, which could limit our shareholders’ ability to pursue actions in another judicial forum for disputes with us or our directors, officers, employees or agents~~.

•The market price of our common stock is subject to volatility.

•There may be future sales or other dilution of our equity, which may adversely affect the market price of our common stock.

PART I

Item 1. Business.

Our Company

We are a leading integrated energy service company, located in Midland, Texas, focused on providing innovative hydraulic fracturing, wireline, and other complementary energy and power generation services to leading upstream oil and gas companies engaged in the E&P of North American oil and natural gas resources. Our operations are primarily focused in the Permian Basin, where we have cultivated longstanding customer relationships with some of the region’s most active and well‑capitalized E&P companies. The Permian Basin is widely regarded as one of the most prolific oil and natural gas producing areas in the United States, and we believe we are one of the leading providers of energy services in the region.

In ~~the~~December ~~fourth quarter of~~ 2024, we formed a new subsidiary, ProPetro Energy Solutions, LLC, doing business as ~~PROPWRSM~~PROPWR, towhich ~~provide~~provides turnkey power generation services to oil and gas producers and for general industrial projects and data centers. ~~PROPWR~~using ~~has~~mobile ~~ordered~~power generation equipment, ~~but~~installed ~~has~~at ~~not~~customers’ ~~yet~~sites. ~~begun~~This subsidiary began revenue-generating activities during the third quarter of fiscal year 2025 and has entered into contractual arrangements with equipment manufacturers to purchase mobile natural gas-fueled power generation equipment, including turbine generator sets, reciprocating engines, auxiliary equipment and battery energy storage solution equipment.

On November 1, 2024, we sold our cementing business located in Vernal, Utah, to a business owned by a former employee as part of a strategic repositioning. We received a promissory note for $13.0 million as consideration., ~~The~~and ~~note~~recorded ~~receivable~~a isgain ~~secured~~on bydisposal ~~substantially all assets~~ of ~~the~~$8.2 ~~divested~~million ~~operations~~related ~~and~~to the ~~former~~sale ~~employee’s~~of ~~ownership interests in and distributions from~~ the business. The note receivable iswas tofully berepaid ~~paid to the Company in quarterly installments~~ with interest ofin ~~10% per annum from March 31, 2025, to~~ December ~~31, 2029~~2025. ~~We recorded a gain on disposal of $8.2 million related to the sale of the business.~~ The former employee was part of our cementing operations until November 1, 2024, and is no longer affiliated with the Company.

On May 31, 2024, we consummated the acquisition of all of the outstanding equity interests in Aqua Prop, LLC (“~~AquaPropSM~~AquaProp”), which provides wet sand solutions for hydraulic fracturing at well sites (the “AquaProp Acquisition”). The consideration for the AquaProp Acquisition included $13.7 million of cash paid to the seller, $3.7 million of deferred cash consideration payable to the seller by May 31, 2025, the payoff of $7.2 million of the seller’s outstanding debt, the payment of $0.3 million of certain transaction costs and estimated contingent consideration of $10.9 million. As a result of the AquaProp Acquisition, we expanded our business to include wet sand services.

On December 1, 2023, we consummated the purchase of the assets and operations of Par Five Energy Services LLC (“Par Five”), which provides cementing services in the Delaware Basin in exchange for $25.4 million of cash, including deferred cash consideration of $3.1 million which iswas payable to Par Five or its beneficiary on June 1, 2025, with interest at 4.0% per annum. (the “Par Five Acquisition”). The Par Five Acquisition complemented our existing cementing business and enabled us to serve both the Midland and Delaware sub-basins of the Permian Basin.

~~On November 1~~Collectively, ~~2022, we consummated~~ the ~~acquisition~~AquaProp ofAcquisition, ~~all of~~ the ~~outstanding~~Par ~~limited~~Five ~~liability~~Acquisition ~~company~~and ~~interests~~our acquisition of Silvertip Completion Services Operating, LLC (~~the~~ “Silvertip ~~Acquisition~~”), ~~which provides wireline perforation and ancillary services~~ in ~~the~~2022 Permian Basin in exchange for 10.1 million shares of our common stock valued at $106.7 million, $30.0 million of cash, the payoff of $7.2 million of assumed debt, and the payment of certain other closing and transaction costs. Collectively, the AquaProp Acquisition, the Par Five Acquisition and the Silvertip Acquisition have positioned the Company as a more integrated and diversified completions-focused energy service provider. See “Note 4. Business Acquisitions” in the financial statements for additional disclosures.

~~Effective~~We ~~September~~believe 1,that ~~2022,~~our wesubstantial ~~disposed~~market ofpresence ~~our~~in ~~coiled~~the ~~tubing~~Permian ~~assets~~Basin positions us well to ~~STEP~~capitalize ~~Energy~~on ~~Services~~drilling, ~~Ltd.~~completion ~~(“STEP”)~~activity and ~~shut~~power ~~down~~demand in the region. Our operational focus has primarily been in the Permian Basin's Midland sub-basin, where our ~~coiled~~customers ~~tubing~~have ~~operations~~operated. WeHowever, ~~received~~we ~~approximately~~have ~~$2.8~~increased ~~million~~our operations in ~~cash~~the Delaware sub-basin and ~~2.6~~are ~~million~~well-positioned ~~common~~to ~~shares~~support offurther ~~STEP,~~increases ~~valued~~in atour ~~$11.8~~activity ~~million,~~in asthis ~~consideration.~~area ~~Upon~~in ~~the~~response ~~sale~~to ofdemand from our ~~coiled~~customers. ~~tubing~~Over ~~assets~~time, we ~~recorded~~expect athe ~~loss~~Permian onBasin's ~~sale~~Midland and Delaware sub-basins to continue to command a disproportionate share of ~~$13.8~~future ~~million~~North American E&P spending.

Our competitors include many large and small energy service companies, including Halliburton Company, Liberty Energy Inc., Patterson-UTI Energy Inc., ProFrac Holding Corp., Solaris Energy Infrastructure, Inc., RPC, Inc., and a number of private and locally-oriented businesses. The markets in which we operate are highly competitive. To be successful, an energy service company must provide services that meet the specific needs of oil and natural gas E&P companies at competitive prices. Competitive factors impacting sales of our services are price, reputation, technical expertise, technology, emissions profile, service and equipment design and quality, and health and safety standards. Although we believe our customers consider all of these factors, we believe price is a key factor in E&P companies' criteria in choosing a service provider. However, we have recently observed the energy industry and our customers’ shift to new technologies and 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 has been challenging for companies in the service industry because of the capital requirements, lack of large-scale deployment of certain new technology such as electric-powered equipment, and the pricing for our services and expected return on invested capital. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our operational efficiencies, productivity, equipment quality and technology, 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 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. Our operational focus has primarily been in the Permian Basin's Midland sub-basin, where our customers have operated. However, we have increased our operations in the Delaware sub-basin and are well-positioned to support further increases in our activity in this area in response to demand from our customers. Over time, we expect the Permian Basin's Midland and Delaware sub-basins to continue to command a disproportionate share of future North American E&P spending.

Additionally, we believe the significant natural gas production in the Permian Basin will become a natural market for power-intensive businesses including data centers and other industrial businesses seeking alternative solutions for reliable and available electricity requirements which are not dependent on grid or public utility limitations.

We primarily provide hydraulic fracturing, wireline, and cementing completion services to E&P companies in the Permian Basin and power generation services to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers. Our completions equipment has been designed to handle the operating conditions commonly encountered in the Permian Basin and the region's increasingly high-intensity well completions (including simultaneous hydraulic fracturing (“Simul-Frac”), which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well. We also launched a new power generation business, PROPWR, that will provide power generation services to oil and gas producers and other industrial companies and data centers.

(“Simul-Frac”), which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well.

Commodity Price and Other Economic Conditions

The oil and gas industry has traditionally been volatile and is characterized by a combination of long-term, short-term and cyclical trends, including domestic and international supply and demand for oil and gas, current and expected future prices for oil and gas and the perceived stability and sustainability of those prices, and capital investments of E&P companies toward their development and production of oil and gas reserves. The power generation services industry is impacted by prices and availability of electricity and power generation equipment including turbines, reciprocating engines and necessary ancillary equipment. Our power generation business will be negatively impacted if electricity prices decrease and grid power becomes widely available. The oil and gas industry isand the power generation services industry are also impacted by general domestic and international economic conditions such as supply chain disruptions and inflation, war and political instability in oil producing countries, government regulations (both in the United States and internationally), levels of consumer demand, adverse weather conditions, and other factors that are beyond our control.

The geopolitical and macroeconomic consequences of military action in the Middle East, the Russian invasion of Ukraine, including the associated sanctions, ~~and~~recent ~~the~~events ~~adverse~~in ~~impacts~~Venezuela, ofand ~~the~~actions ~~COVID-19~~by ~~pandemic~~OPEC+ have ~~resulted~~contributed into volatility in supply and demand dynamics for crude oil and associated volatility in crude oil pricing. Asin ~~the~~recent ~~global~~years. ~~response~~More ~~to the COVID-19 pandemic began to wane~~recently, the ~~demand and prices for crude oil increased from the lows experienced in 2020, with the~~ West Texas Intermediate (“WTI”) average crude oil price ~~reaching approximately $94 per barrel in 2022, the highest average price in the prior ten years. However, the WTI average crude oil price~~ declined to approximately $7865 per barrel in ~~2023~~2025 ~~and~~compared to approximately $76 per barrel in 2024. Wein ~~believe~~response ~~that~~to ~~the~~tariff ~~volatility~~policies ofimplemented ~~crude~~by ~~oil~~the ~~prices~~United inStates ~~recent~~government, ~~years~~an ~~has~~anticipated ~~been~~increase ~~partly~~in ~~driven~~global bysupply ~~declines~~of in crude oil ~~supplies,~~and concerns ~~over~~of ~~sanctions~~a potential global recession resulting from ~~Russia's~~high ~~invasion~~inflation, ofinterest ~~Ukraine~~rates, ~~concerns~~impacts ~~over a potential disruption~~ of ~~Middle~~tariff ~~Eastern~~policies ~~oil~~on ~~supplies~~supply ~~resulting~~chains ~~from~~and ~~the~~increased ~~conflict~~costs inas ~~the~~a ~~Middle~~whole. ~~East~~Additionally, ~~slower~~we ~~crude~~have ~~oil~~recently ~~production~~experienced ~~growth~~a ~~due~~decrease toin the ~~lack~~Permian ofBasin ~~reinvestment~~rig incount to 304 at the ~~oil~~end ~~and~~of ~~gas~~2024 ~~industry~~and ina ~~the~~further ~~last~~decrease ~~three~~to ~~years,~~247 at the ~~extension~~end of ~~OPEC+~~2025, ~~production~~according ~~cuts~~to ofthe ~~approximately~~Baker ~~3.9~~Hughes ~~million~~Company ~~barrels~~(“Baker ~~per~~Hughes”), ~~day~~which ~~originally~~resulted ~~announced~~ in ~~2023~~a ~~and~~reduction ~~concerns~~in ofthe ademand ~~potential~~for ~~global~~completion ~~recession~~services ~~resulting~~and ~~from~~pressure ~~high~~on ~~inflation~~pricing ~~and~~of ~~interest~~our ~~rates~~services.

~~With~~Sustained levels of high inflation likewise caused the ~~significant~~U.S. ~~increase~~Federal inReserve ~~global~~and ~~crude~~other ~~oil~~central ~~prices~~banks ~~from~~to ~~2021~~increase interest rates, ~~including~~and to the ~~WTI~~extent ~~crude~~elevated ~~oil~~inflation ~~price~~remains, ~~there~~we ~~was~~may aexperience ~~significant~~further ~~increase~~cost inincreases ~~the~~for ~~Permian~~our ~~Basin~~operations, ~~rig~~including ~~count~~interest ~~from~~rates, ~~approximately~~labor ~~179~~costs atand ~~the~~equipment. ~~beginning~~We ofcannot ~~2021~~predict toany ~~approximately~~future ~~353~~trends atin the ~~end~~rate of ~~2022,~~inflation ~~according~~and tocrude ~~the~~oil ~~Baker~~prices. ~~Hughes~~A ~~Company~~significant ~~(“Baker~~increase ~~Hughes”).~~in ~~Following~~or ~~the~~continued ~~increase~~high inlevels ~~rig~~of ~~count~~inflation, ~~and~~to the ~~WTI~~extent ~~crude~~we ~~oil~~are ~~price,~~unable to timely pass-through the ~~energy~~cost ~~service~~increases ~~industry~~to ~~has~~our ~~experienced~~customers, ~~increased~~further ~~demand~~declines ~~for~~in ~~its~~crude ~~completion~~oil ~~services~~prices, ~~and~~or ~~improved~~potential ~~pricing.~~changes ~~However,~~in the ~~Permian~~United ~~Basin~~States’ ~~rig~~trade ~~count~~policy, ~~experienced~~including athe ~~13%~~imposition ~~decrease~~of totariffs ~~309~~and at the ~~end~~resulting ofconsequences, ~~2023~~would ~~and~~negatively ~~further~~impact ~~decreased~~our tobusiness, ~~304~~financial atcondition ~~the~~and ~~end~~results of ~~2024~~operations. ~~which~~See ~~resulted~~Part inII, aItem ~~reduction~~1A. in“Risk ~~the~~Factors—We ~~demand~~may ~~for~~be ~~completion~~adversely ~~services~~affected ~~and~~by ~~pressure~~the oneffects ~~pricing~~ of ~~our services~~inflation.”

~~Sustained~~Government ~~levels~~regulations ofand ~~high~~investors ~~inflation~~are ~~likewise~~demanding ~~caused~~ the ~~U.S.~~oil ~~Federal Reserve~~ and ~~other~~gas ~~central~~industry ~~banks~~transition to ~~increase~~a ~~interest~~lower ~~rates~~emissions operating environment, including upstream and toenergy ~~the~~service ~~extent~~companies. ~~elevated~~As ~~inflation~~a ~~remains~~result, we ~~may~~are ~~experience~~working ~~further~~with ~~cost~~our ~~increases~~customers ~~for~~and equipment manufacturers to transition our ~~operations~~equipment into a lower emissions profile. Currently, a number of lower emission solutions for pumping equipment, including ~~interest~~Tier ~~rates~~IV DGB dual-fuel, ~~labor~~FORCE® ~~costs~~electric, direct drive gas turbine and ~~equipment.~~other Wetechnologies ~~cannot~~have ~~predict~~been ~~any~~developed, ~~future~~and ~~trends~~we expect additional lower emission solutions will be developed in the ~~rate~~future. ofWe ~~inflation~~are continually evaluating these technologies and ~~crude~~other ~~oil~~investment ~~prices~~and acquisition opportunities that would support our existing and new customer relationships. AThe ~~significant~~transition ~~increase~~to inlower oremissions ~~continued~~equipment ~~high~~is ~~levels~~quickly ofevolving ~~inflation~~and will be capital intensive. Over time, we may be required to convert substantially all of our conventional Tier II equipment to lower emissions equipment. To the extent any of our customers have certain expectations or requirements with respect to emissions reductions from their contractors, if we are unable to ~~timely~~continue ~~pass-through~~quickly ~~the~~transitioning ~~cost~~to ~~increases~~lower toemissions equipment, the demand for our services could be adversely impacted.

customers, further declines in crude oil prices, or potential changes in U.S trade policy, including the imposition of tariffs and the resulting consequences, would negatively impact our business, financial condition and results of operations. See Part II, Item 1A. “Risk Factors—We may be adversely affected by the effects of inflation.”

Government regulations and investors are demanding the oil and gas industry transition to a lower emissions operating environment, including upstream and energy service companies. As a result, we are working with our customers and equipment manufacturers to transition our equipment into a lower emissions profile. Currently, a number of lower emission solutions for pumping equipment, including Tier IV DGB dual-fuel, FORCE® electric, direct drive gas turbine and other technologies have been developed, and we expect additional lower emission solutions will be developed in the future. We are continually evaluating these technologies and other investment and acquisition opportunities that would support our existing and new customer relationships. The transition to lower emissions equipment is quickly evolving and will be capital intensive. Over time, we may be required to convert substantially all of our conventional Tier II equipment to lower emissions equipment. We have transitioned our hydraulic fracturing available equipment portfolio from approximately 10% lower emissions equipment in 2021 to approximately 35% in 2022, 60% in 2023 and 70% in 2024, and expect to increase to approximately 75% by the end of the first quarter of 2025. To the extent any of our customers have certain expectations or requirements with respect to emissions reductions from their contractors, if we are unable to continue quickly transitioning to lower emissions equipment, the demand for our services could be adversely impacted.

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. If the rig count or market conditions do not improve or decline in the future, and we are unable to increase our pricing or pass-through future cost increases for our customers, there could be a material adverse impact on our business, results of operations and cash flows.

Our results of operations have historically reflected seasonal tendencies, typically in the fourth quarter, relating to the holiday season, inclement winter weather and the exhaustion of our customers' annual budgets. As a result, we typically experience declines in our operating and financial results in November and December, even in a stable commodity price and operations environment.

Our Services

WeAs ~~have~~of ~~historically~~December 31, 2025, we conducted our business through four operating segments: ~~hydraulic~~Hydraulic ~~fracturing~~Fracturing, ~~wireline~~Wireline, ~~cementing~~Cementing and ~~coiled~~Power ~~tubing.~~Generation, ~~Prior~~all ~~to the fourth quarter~~ of ~~fiscal~~which ~~year~~meet ~~2023, our operating segments met~~ the ~~aggregation~~ criteria ~~and~~of ~~were~~a ~~aggregated into the “Completion Services”~~ reportable segment ~~and our coiled tubing operations (which were divested in September 2022) were shown in the “All Other” category~~. ~~Effective~~Prior into the ~~fourth~~third quarter of ~~fiscal year 2023~~2025, weour ~~revised~~Power ~~our~~Generation segment ~~reporting~~did asnot wemeet ~~determined~~the ~~that~~quantitative ~~our~~thresholds ~~operating~~for ~~segments~~a noreportable ~~longer~~segment ~~met~~and ~~the~~prior ~~criteria~~ to ~~be aggregated. In~~ the fourth quarter of fiscal year 2024, weour ~~formed~~Cementing ~~PROPWR~~segment todid ~~provide~~not ~~power~~meet ~~generation~~the ~~services~~quantitative tothresholds ~~oil~~for ~~and~~a ~~gas~~reportable ~~producers~~segment. ~~and~~Accordingly, ~~non-oil~~they ~~and~~were ~~gas~~shown ~~applications~~in ~~such~~the as“All ~~general~~Other” ~~industrial projects and data centers~~category. ~~This~~Effective ~~new~~as ~~subsidiary~~of ~~has~~the ~~ordered~~third ~~equipment,~~quarter ~~but~~of itfiscal ~~has~~year ~~not~~2025 ~~yet begun any revenue-generating activities. Our hydraulic fracturing, wireline~~ and ~~cementing operating segments meet~~ the ~~criteria~~fourth quarter of afiscal ~~reportable~~year ~~segment.~~2024, ~~Our~~Power ~~divested~~Generation ~~coiled tubing~~ and ~~our~~Cementing, ~~newly~~respectively, ~~formed~~are ~~power~~shown ~~generation~~as ~~services~~reportable segments dosince ~~not~~they meet the ~~reportable segment~~ criteria ~~and~~of ~~are~~a ~~included~~reportable ~~within the “All Other” category~~segment. Additionally, our corporate administrative activities do not involve business activities from which itwe may earn revenues and its results are not regularly reviewed by the Company’s Chief Operating Decision Maker (the “CODM”) when making key operating and resource decisions. As a result, corporate administrative expenses have been included under “Reconciling Items.” For additional financial information on our reportable segment presentation, please see reportable segment information in Part II - Item 8, “Financial Statements and Supplementary Data.”

Hydraulic Fracturing

We provide hydraulic fracturing services to E&P companies in the Permian Basin. These services are intended to optimize hydrocarbon flow paths during the completion phase of horizontal shale wellbores. We have significant expertise in multi‑stage fracturing of horizontal oil‑producing wells in unconventional geological formations. Our total available hydraulic horsepower (“HHP”) at December 31, ~~2024~~2025, was 1,~~556~~259,500 HHP, which was comprised of ~~450~~445,000 HHP of our Tier IV Dynamic Gas Blending (“DGB”) dual-fuel equipment, ~~294~~312,000 HHP of FORCE® electric-powered equipment and ~~812~~502,500 HHP of conventional Tier II equipment. Our hydraulic fracturing fleets range from approximately 50,000 to 80,000 HHP depending on the job design and customer demand at the wellsite. Our completions equipment has been designed to handle the operating conditions commonly encountered in the Permian Basin and the region’s increasingly high-intensity well completions, (including simultaneous hydraulic fracturing (“Simul-Frac”), which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well. With the industry transition to lower emissions equipment and Simul-Frac, in addition to several other changes to our customers' job designs, we believe that our available fleet capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at wellsites. In 2021, we began to transition our fleet from traditional equipment to Tier IV DGB dual-fuel equipment. In 2022, we entered into three-year electric fleet leases which commenced in 2023 and 2024 for four FORCE® electric-powered hydraulic fracturing fleets worth of equipment with 60,000 HHP per fleet, and in 2024, we entered into an additional three-year lease for one more FORCE® electric-powered hydraulic fracturing fleet worth of equipment with 72,000 HHP (collectively, the “Electric Fleet Leases”). As of December 31, 2025, we have received 312,000 HHP of FORCE® electric-powered equipment representing five fleets worth of equipment.

lower emissions equipment and Simul-Frac, in addition to several other changes to our customers' job designs, we believe that our available fleet capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at wellsites. In addition, in 2021 and 2022, we committed to additional conversions of some of our Tier II equipment to Tier IV DGB, and to purchase new Tier IV DGB dual-fuel equipment. As such, we entered into conversion and purchase agreements with our equipment manufacturers and received all of the converted and new Tier IV DGB dual-fuel equipment by the end of 2023, representing 450,000 HHP of our Tier IV DGB dual-fuel equipment as of December 31, 2024. In 2022, we entered into three-year electric fleet leases for four FORCE® electric-powered hydraulic fracturing fleets with 60,000 HHP per fleet (the “Electric Fleet Leases”) and in June 2024, we entered into an additional three-year lease for a fifth FORCE® electric-powered hydraulic fracturing fleet with 72,000 HHP. As of December 31, 2024, we have received 294,000 HHP of FORCE® electric-powered equipment representing four fleets and a portion of the fifth fleet. We currently expect to receive the remaining equipment associated with the fifth fleet in the first half of 2025.

The hydraulic fracturing process consists of pumping fracturing fluid into a well at sufficient pressure to fracture the formation. Materials known as proppants, which in our business are comprised primarily of sand, are suspended in the fracturing fluid and are pumped into the fracture to prop it open. The fracturing fluid is designed to break, or loosen viscosity, and be forced out of the formation by its pressure, leaving the proppants suspended in the fractures created, thereby increasing the mobility of the hydrocarbons. As a result of the fracturing process, production rates are usually enhanced substantially, thus increasing the rate of return of hydrocarbons for the operator.

We own and operate a fleet of mobile hydraulic fracturing units and other auxiliary equipment to perform fracturing services. We also refer to all of our fracturing units, other equipment and vehicles necessary to perform a fracturing job as a “fleet” and the personnel assigned to each fleet as a “crew.” Our hydraulic fracturing units consist primarily of high pressure hydraulic pumps, diesel or dual gas engines, gas turbine generators, transmissions and various hoses, valves, tanks and other supporting equipment like blenders, irons, hoses and data vans. We also own and operate a fleet of trucks, trailers and other equipment that provide onsite storage and handling of wet sand used in the completion phase of shale wellbores.

We provide dedicated equipment, personnel and services that are tailored to meet each of our ~~customer~~customers’s needs. Each fleet has a designated team of personnel, which allows us to provide responsive and customized services, such as project design, proppant and other consumables procurement, real-time data provision and post‑completion analysis for each of our jobs. Many of our hydraulic fracturing fleets and associated personnel have worked continuously with the same customer for the past several years promoting deep relationships and a high degree of coordination and visibility into future customer activity levels. Furthermore, in light of our substantial market presence and historically high fleet utilization levels, we have established a variety of trusted relationships with key equipment, sand and other downhole consumable suppliers. We believe these strategic relationships position us to acquire equipment, parts and materials on a timely and economic basis and allow our dedicated procurement and logistics team to support consistently safe and reliable operations.

Wireline

We provide wireline and ancillary services on new oil well completions in the Permian Basin. Wireline utilizes equipment with a drum of wireline to deploy perforating guns in the well to perforate the casing, cement, and formation. Once the well is perforated, it is ready to be fractured. Pumpdown utilizes pressure pumping equipment to pump water into the well to deploy or push the perforating guns attached to the wireline through the lateral section of a well.

We own and operate a fleet of mobile wireline units and other auxiliary equipment to perform well completion services. We also refer to our wireline units, pressure control equipment, other equipment and vehicles necessary to perform a job as a "spread" and the personnel assigned to the spread as a "crew." On average, one wireline spread consists of a wireline tractor truck with a large cab functioning as a mobile office where the engineer controls the wireline spooled drum along with associated pressure control iron and equipment, trailers and vehicles. We currently have 2628 wireline units.

Cementing

We provide cementing services for completion of new wells and remedial work on existing wells. Cementing services use pressure pumping equipment to deliver a slurry of liquid cement that is pumped down a well between the casing and the borehole. Cementing provides isolation between fluid zones behind the casing to minimize potential damage to hydrocarbon bearing formations or the integrity of freshwater aquifers, and provides structural integrity for the casing by securing it to the earth. Cementing is also done when re-completing wells, where one zone is plugged and another is opened.

4We believe that our Cementing segment provides an organic growth opportunity for us to expand our service offerings within our existing customer base. We currently have 29 cementing units.

We believe that our cementing segment provides an organic growth opportunity for us to expand our service offerings within our existing customer base. We currently have 29 cementing units.

Power Generation Services

In December 2024, we ~~formed~~launched ~~PROPWR~~our toPROPWRSM ~~provide~~business line which provides turnkey power generation services to oil and gas producers and non-oil and gas applications, such as general industrial projects and data centers, using mobile power generation equipment installed at customers’ sites. These services are generally provided through contractual arrangements in which we set a price per unit of power generated or a price per period and a minimum quantity of power per period under our contracts. We are also paid cost plus a predetermined margin for other related services. This subsidiary began revenue generating activities during the third quarter of fiscal year 2025 and has ~~ordered~~entered into contractual arrangements with equipment manufacturers to purchase mobile natural gas-fueled power generation equipment, ~~but~~including ~~has~~turbine ~~not~~generator ~~yet begun~~sets, ~~revenue~~reciprocating engines, auxiliary equipment and battery energy storage solution equipment. We have received certain units of this equipment and expect to receive the remaining units currently on order from the first quarter of fiscal year 2026 through year-~~generating~~end ~~activities~~2027. The total capacity of equipment under these contractual arrangements including equipment received through December 31, 2025 is approximately 550 megawatts, split approximately 70% and 30% between high-efficiency reciprocating engine generators and low emissions modular turbines, respectively. As of February 19, 2026, we had total committed capacity of approximately 240 megawatts.

Our Customers

Our customers consist primarily of oil and natural gas producers in North America. Our top five customers accounted for approximately 5868.82%, 6358.28% and 8463.02% of our revenue, for the years ended December 31, ~~2024~~2025, ~~2023~~2024, and ~~2022~~2023, respectively. For the year ended December 31, ~~2024~~2025, ~~XTO~~Exxon ~~Energy~~Mobil ~~Inc.~~Corporation (“~~XTO~~ExxonMobil”), aOccidental ~~wholly~~Petroleum ~~owned subsidiary of Exxon Mobil~~ Corporation ~~(“ExxonMobil”)~~, ~~Permian~~EOG Resources, Inc. and ~~EOG~~Permian Resources Corporation accounted for 1924.9%, 13.7%, 1412.91%, and 1011.62%, respectively, of total revenue. No other customer accounted for more than 10% of our total revenue for the year ended December 31, ~~2024~~2025. There have been many recent mergers and acquisitions in the oil and gas industry. In May 2024, Pioneer Natural Resources USA, Inc. (“Pioneer”) merged with and into a wholly owned subsidiary of Exxon Mobil. We currently provide pressure pumping, wireline and other services to ExxonMobil and previously provided such services to Pioneer. Mergers and acquisitions involving our customers could negatively impact our future business with them or positively impact our business by providing us access to potential new customers.

On April 22, 2024, we entered into a sub-agreement for hydraulic fracturing services with XTO Energy Inc. (“XTO”), a wholly owned subsidiary of ExxonMobil, pursuant to which we agreed to provide hydraulic fracturing, wireline and pumpdown services with two committed FORCE® electric-powered hydraulic fracturing fleets ~~with~~and the option to add a third FORCE® fleet (also with wireline and pumpdown services) for a ~~period~~certain number of ~~three years or for~~ contracted hours, ~~whichever occurs last,~~ with respect to each fleet, subject to certain termination and release rights. This agreement will expire in approximately late 2026. At this time, we do not expect

such agreement to be renewed or extended and, if we are not able to procure additional work from XTO, we will be required to seek to redeploy the equipment associated with the affected fleets with other customers.

Competition

We provide our services primarily in the Permian Basin, and we compete against different companies in each service and product line we offer. The markets in which we operate are highly competitive. To be successful, an energy service company must provide services and equipment that meet the specific needs of oil and natural gas E&P companies at competitive prices. Competitive factors impacting sales of our services are price, reputation, technical expertise, emissions profile, service and equipment design and quality, and health and safety standards. Although we believe our customers consider all of these factors, we believe price is a key factor in E&P companies’ criteria in choosing a service provider. However, 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 has been challenging for companies in the energy service industry because of the capital requirements, lack of large scale deployment of certain new technology such as electric-powered equipment, and the pricing of our services and expected return on invested capital. While we seek to price our services competitively, we believe many of our customers elect to work with us based on our operational efficiencies, productivity, equipment ~~portfolio~~quality and ~~quality~~technology, 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 provide our services primarily in the Permian Basin, and we compete against different companies in each service and product line we offer. Our competition includes many large and small energy service companies, including the largest integrated energy service companies. Our major competitors include Halliburton Company, Liberty Energy Inc., Patterson‑UTI Energy Inc., ProFrac Holding Corp., Solaris Energy Infrastructure, Inc., RPC, Inc., and a number of private and locally-oriented businesses.

Seasonality

Our results of operations have historically reflected seasonal tendencies, generally in the fourth quarter, relating to the conclusion of our customers’ annual capital expenditure budgets, the holidays and inclement winter weather which could result in suspension of services during which we may experience declines in our operating and financial results.

Operating Risks and Insurance

Our operations are subject to hazards inherent in the energy service industry, such as accidents, blowouts, explosions, fires and spills and releases that can cause personal injury or loss of life, damage or destruction of property, equipment, natural resources and the environment and suspension of operations.

In addition, claims for loss of oil and natural gas production and damage to formations can occur in the energy service industry. If a serious accident were to occur at a location where our equipment and services are being used, it could result in us being named as a defendant in lawsuits asserting large claims.

Our business involves the transportation of heavy equipment and materials, and as a result, we may also experience traffic accidents which may result in spills, property damage and personal injury.

Despite our efforts to maintain safety standards, we have suffered accidents from time to time in the past and anticipate that we could experience accidents in the future. In addition to the property damage, personal injury and other losses from these accidents, the frequency and severity of these incidents affect our operating costs and insurability and our relationships with customers, employees, regulatory agencies and other parties. Any significant increase in the frequency or severity of these incidents, or the general level of compensation awards, could adversely affect the cost of, or our ability to obtain workers’ compensation and other forms of insurance, and could have other material adverse effects on our financial condition and results of operations.

We maintain commercial general liability, workers’ compensation, business automobile, commercial property, ~~umbrella~~and ~~liability~~equipment, excess liability, and directors and officers insurance policies providing coverages of risks and amounts that we believe to be customary in our industry. ~~Further,~~Our weprimary ~~have~~and ~~pollution~~excess ~~legal~~ liability ~~coverage~~insurance ~~for~~policies ~~our~~include ~~business~~liability ~~entities,~~coverage ~~which~~for ~~would~~sudden ~~cover,~~and ~~among~~accidental ~~other~~pollution ~~things,~~incidents. ~~third~~Although ~~party~~we ~~liability~~are ~~and~~insured ~~costs~~for ofenvironmental ~~clean~~pollution upresulting ~~relating~~from tocertain environmental ~~contamination~~accidents onthat ~~our~~occur ~~premises~~on ~~while~~a ~~our~~sudden ~~equipment is in transit~~ and onaccidental ~~our customers’ job site. With respect to our operations~~basis, ~~coverage~~we ~~would~~may not be ~~available~~insured ~~under~~against ~~our~~all ~~pollution legal liability policy for any surface or subsurface~~ environmental ~~cleanup~~accidents ~~and liability to third parties arising from any surface~~ or ~~subsurface~~events ~~contamination.~~that Wemight ~~also have certain specific coverages for some of our businesses, including our hydraulic fracturing and wireline services~~occur.

We maintain directors and officers insurance; however, our insurance coverage is subject to certain exclusions (including, for example, any required United States Securities and Exchange Commission (“SEC”) disgorgement or penalties) and we are responsible for meeting certain deductibles under the policies. Moreover, we cannot assure you that our insurance coverage will adequately protect us from all future claims.

Although we maintain insurance coverage of types and amounts that we believe to be customary in the industry, we are not fully insured against all risks, either because insurance is not available or because of the high premium costs relative to perceived risk. Further, insurance rates have in the past been subject to wide fluctuation and changes in coverage could result in less coverage, increases in cost or higher deductibles and retentions. Liabilities for which we are not insured, or which exceed the policy limits of our applicable insurance, could have a material adverse effect on us. See “Risk Factors” for a description of certain risks associated with our insurance policies.

Environmental and Occupational Health and Safety Regulations

Our operations are subject to stringent laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection, and occupational health and safety. Numerous federal, state and local governmental agencies issue regulations that often require difficult and costly compliance measures that could carry substantial administrative, civil and criminal penalties and may result in injunctive obligations for non-compliance. These laws and regulations may, for example, restrict the types, quantities and concentrations of various substances that can be released into the environment, limit or prohibit construction or drilling activities on certain lands lying within wilderness, wetlands, ecologically or seismically sensitive areas and other protected areas, or require action to prevent or remediate pollution from current or former operations. Moreover, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the release of hazardous substances, hydrocarbons or other waste products into the environment. Changes in environmental, health and safety laws and regulations occur frequently, and any changes that result in more stringent and costly requirements could materially adversely affect our operations and financial position. We have not experienced any material adverse effect from compliance with current requirements; however, this trend may not continue in the future.

Below is an overview of some of the more significant environmental, health and safety requirements with which we must comply. Our customers’ operations are subject to similar laws and regulations. Any material adverse effect of these laws and regulations on our customers’ operations and financial position may also have an indirect material adverse effect on our operations and financial position.

Waste Handling. We handle, transport, store and dispose of wastes that are subject to the Resource Conservation and Recovery Act ("“RCRA"”) and comparable state laws and regulations, which affect our activities by imposing requirements regarding the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. With federal approval, the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Although certain petroleum production wastes are exempt from regulation as hazardous wastes under RCRA, such wastes may constitute “solid wastes” that are subject to the less stringent requirements of non-hazardous waste provisions.

generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. With federal approval, the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Although certain petroleum production wastes are exempt from regulation as hazardous wastes under RCRA, such wastes may constitute “solid wastes” that are subject to the less stringent requirements of non-hazardous waste provisions.

Administrative, civil and criminal penalties can be imposed for failure to comply with waste handling requirements. Moreover, the U.S. Environmental Protection Agency (“EPA”) or state or local governments may adopt more stringent requirements for the handling of non-hazardous wastes or recategorize some non-hazardous wastes as hazardous for future regulation. Indeed, legislation has been proposed from time to time in Congress to recategorize certain oil and natural gas exploration, development and production wastes as hazardous wastes. Several environmental organizations have also petitioned the EPA to modify existing regulations to recategorize certain oil and natural gas exploration, development and production wastes as hazardous. Any such changes in these laws and regulations could have a material adverse effect on our capital expenditures and operating expenses. Although we do not believe the current costs of managing our wastes, as presently classified, to be significant, any legislative or regulatory reclassification of oil and natural gas E&P wastes could increase our costs to manage and dispose of such wastes.

Remediation of Hazardous Substances. The Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) and analogous state laws generally impose liability without regard to fault or legality of the original conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include the current owner or operator of a contaminated facility, a former owner or operator of the facility at the time of contamination and those persons that disposed or arranged for the disposal of the hazardous substance at the facility. Liability for the costs of removing or remediating previously disposed wastes or contamination, damages to natural resources, the costs of conducting certain health studies, amongst other things, is strict and joint and several. In the course of our operations, we use materials that, if released, would be subject to CERCLA and comparable state laws. Therefore, governmental agencies or third parties may seek to hold us responsible under CERCLA and comparable state statutes for all or part of the costs to clean up sites at which such hazardous substances have been released.

NORM. In the course of our operations, some of our equipment may be exposed to naturally occurring radioactive materials (“NORM”) associated with oil and gas deposits and, accordingly, may result in the generation of wastes and other materials containing NORM. NORM exhibiting levels of radiation in excess of established state standards are subject to special handling and disposal requirements, and any storage vessels, piping and work area affected by NORM may be subject to remediation or restoration requirements.

Water Discharges. The Clean Water Act, Safe Drinking Water Act, Oil Pollution Act and analogous state laws and regulations impose restrictions and strict controls regarding the unauthorized discharge of pollutants, including produced waters and other gas and oil wastes, into regulated waters. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or the state. Also, spill prevention, control and countermeasure plan requirements require appropriate containment berms and similar structures to help prevent the contamination of regulated waters.

Air Emissions. The Clean Air Act (“CAA”) and comparable state laws and regulations, regulate emissions of various air pollutants through the issuance of permits and the imposition of other emissions control requirements. The EPA has developed, and continues to develop, stringent regulations governing emissions of air pollutants from specified sources. New facilities may be required to obtain permits before work can begin, and existing facilities may be required to obtain additional permits and incur capital costs in order to remain in compliance. These and other laws and regulations may increase the costs of compliance for some facilities where we operate. Obtaining or renewing permits also has the potential to delay the development of oil and natural gas projects.

Climate Change. InNotwithstanding the ~~United~~EPA’s ~~States,~~recent norule ~~comprehensive~~revoking ~~climate change legislation has been implemented at~~ the ~~federal~~“Endangerment ~~level,~~Finding” ~~though recently passed laws such as the IRA 2022 advance numerous climate-related objectives. Additionally, following the U.S. Supreme Court finding~~ (that greenhouse gas (“GHG”) emissions constitute a pollutant under the CAA), ~~the~~which ~~EPA~~supports ~~has~~the ~~adopted~~majority ~~regulations~~of ~~that,~~the ~~among~~EPA’s ~~other~~GHG-related ~~things~~regulations, ~~establish~~the ~~construction~~EPA ~~and~~under ~~operating~~previous ~~permit~~presidential ~~reviews~~administrations ~~for~~adopted ~~GHG~~a ~~emissions~~number ~~from~~of ~~certain~~regulations ~~large~~relating ~~stationary~~to ~~sources, require the monitoring and annual reporting of~~ GHG emissions ~~from~~that impact certain ~~petroleum~~oil and ~~natural~~ gas ~~system~~facilities. ~~sources in the United States~~However, ~~implement New Source Performance Standards directing~~ the ~~reduction~~current ofEPA ~~certain~~has ~~pollutants~~announced ~~from~~numerous ~~certain~~proposals ~~new, modified, or reconstructed facilities in the oil~~ and ~~natural~~initiatives ~~gas~~to ~~sector,~~repeal ~~and~~or ~~together~~revise ~~with~~many ~~the Department~~ of ~~Transportation~~its ~~(“DOT”),~~climate-change ~~implementing~~related ~~GHG~~rulemakings. ~~emissions~~As ~~limits~~a onresult, ~~vehicles~~there ~~manufactured~~is ~~for~~significant ~~operation~~uncertainty insurrounding the ~~United~~future ~~States.~~regulation ~~Additionally,~~of ~~the~~climate ~~EPA~~change ~~has~~at ~~recently finalized rules covering~~ the ~~standards~~federal oflevel. ~~performance for methane and volatile organic compounds emissions for oil and gas facilities, including leak detection, monitoring and repair, and a “super-~~

Additionally, various states and groups of states have adopted or are considering laws or other initiatives related to climate change. Litigation risks have also increased as a result of suits against certain oil and natural gas companies pertaining to alleged past or future damages resulting from climate change. Moreover, climate change may result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in the meteorological and hydrological patterns, that could adversely impact us, our customers’ and our suppliers’ operations. For more information, see our risk factor titled “Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide.”

Endangered and Threatened Species. Environmental laws such as the Endangered Species Act (“ESA”) and analogous state laws may impact exploration, development and production activities in areas where we operate. The ESA provides broad protection for species of fish, wildlife and plants that are listed as threatened or endangered. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act (“MBTA”) and various state analogs. Under the MBTA, the taking, killing or possessing of migratory birds is unlawful without a permit. In April 2025, the U.S. Department of the Interior issued a memorandum that reinstated the interpretation that the MBTA’s prohibition only applied to “affirmative actions that have as their purpose the taking or killing of migratory birds, their nests, or their eggs.” In addition, the U.S. Fish and Wildlife Service (“FWS”) may identify previously unidentified endangered or threatened species or may designate critical habitat and suitable habitat areas that it believes are necessary for survival of a threatened or endangered species. For example, the dunes sagebrush lizard, which is found only in the active and semi-stable shinnery oak dunes of southeastern New Mexico and adjacent portions of Texas (including areas where our customers operate), has, since May 2024, been listed as endangered under the ESA, although that decision has been challenged. To the extent any protections are implemented for this or any other species, it could cause us or our customers to incur additional costs or become subject to operating restrictions or operating bans in the affected areas.

Regulation of Hydraulic Fracturing and Related Activities. Our hydraulic fracturing operations are a significant component of our business. Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons, particularly natural gas, from tight formations, including shales. The process, which involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and natural gas commissions. However, federal agencies have asserted regulatory authority over certain aspects of the process. For example, in April and May 2024, the U.S. Bureau of Land Management (“BLM”) finalized two rules increasing royalty rates, rentals, and minimum bids, and updating the agency’s interpretation of its mandate that conservation is a use of

~~emitter~~federal land on par with mineral extraction and other uses (“Public Lands Rule”). ~~response~~In ~~program~~September to2025, ~~timely~~the ~~mitigate~~U.S. ~~emissions~~Department ~~events~~of asthe ~~detected~~Interior byannounced ~~governmental~~its ~~agencies~~proposal orto ~~qualified~~rescind ~~third~~the ~~parties~~Public Lands Rule. Further, ~~triggering~~in ~~certain~~May ~~investigation~~2025, the BLM announced a policy designed to expedite the oil and ~~repair~~gas ~~requirements.~~leasing ~~These~~process ~~requirements~~on ~~were~~public ~~finalized~~lands. inIn ~~2023~~addition, ~~but~~federal ~~are~~legislation ~~currently~~to ~~subject~~repeal tothe ~~legal~~Safe ~~challenge~~Drinking Water Act exemption for hydraulic fracturing and require more stringent permitting of hydraulic fracturing has previously been proposed in Congress. AtThis ~~this~~federal ~~time~~legislation has not passed. Elsewhere, itseveral ~~remains~~states ~~uncertain~~and aslocal tojurisdictions ~~whether~~in ~~the~~which ~~current~~we ~~administration~~or ~~will~~our ~~repeal~~customers operate also have adopted or ~~modify~~are ~~this~~considering ~~rule~~adopting regulations that could restrict or prohibit hydraulic fracturing in certain circumstances, impose more stringent operating standards and/or require the ~~timing~~disclosure ~~with~~of ~~respect~~the tocomposition ~~the~~of ~~same~~hydraulic fracturing fluids.

~~Additionally,~~Federal ~~various states~~ and ~~groups~~state ofgovernments ~~states~~ have ~~adopted~~also orinvestigated ~~are~~whether ~~considering~~the ~~adopting~~disposal ~~legislation,~~of ~~regulations~~produced orwater ~~other~~into ~~regulatory~~underground ~~initiatives~~injection ~~that~~wells ~~are~~has ~~focused~~caused onincreased ~~such~~seismic ~~areas~~activity ~~such~~in ascertain ~~GHG~~areas. ~~cap~~In ~~and~~response ~~trade~~to ~~programs,~~concerns ~~carbon~~regarding ~~taxes,~~induced ~~reporting and tracking programs~~seismicity, ~~and~~regulators ~~restriction~~in ofsome ~~emissions. At the international level~~states, ~~the~~including ~~United~~Oklahoma ~~Nations-sponsored~~and ~~“Paris Agreement~~Texas,” ~~requires~~have ~~member states to submit non-binding~~imposed, ~~individually-determined~~or ~~reduction~~are ~~goals~~considering ~~known as Nationally Determined Contributions (“NDCs”) every five years after 2020. The United States rejoined the Paris Agreement and~~imposing, inadditional ~~April~~requirements ~~2021, established a goal of reducing economy-wide net GHG emissions 50-52% below 2005 levels by 2030. However,~~ in ~~January 2025,~~ the ~~current~~permitting ~~president~~of ~~signed~~produced anwater ~~Executive~~disposal ~~Order~~wells ~~once~~or ~~again~~otherwise ~~withdrawing~~to ~~the~~assess ~~United~~any ~~States~~relationship ~~from~~between ~~the~~seismicity ~~Paris Agreement~~ and ~~from any other commitments made under~~ the ~~United~~use ~~Nations Framework Convention on Climate Change. The full impact~~ of ~~these~~such ~~recent developments is uncertain at this time~~wells. For ~~more information~~example, ~~see~~the ~~our~~Texas ~~risk~~Railroad ~~factors~~Commission ~~titled~~ (“~~Our~~TRRC”) ~~and~~has ~~our~~adopted ~~customers’~~rules ~~operations~~restricting ~~are~~injection ~~subject~~well tooperations afollowing ~~series~~seismic ofactivity ~~risks~~exceeding ~~arising~~certain ~~out~~magnitude ofand ~~the~~suspending ~~threat~~all ofdeep ~~climate change that could result in increased operating costs, limit the areas in which~~ oil and ~~natural~~ gas ~~production~~produced ~~may~~water ~~occur,~~injection ~~and~~wells ~~reduce~~in ~~demand~~certain ~~for~~geographical ~~the~~areas ~~products~~covered ~~and~~by ~~services we provide” and “The IRA 2022 could accelerate~~ the ~~transition~~TRRC’s toseismic aresponse ~~low carbon economy and could impose new costs on our customers’ operations~~program.”

Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States, for example, in January 2024 the government announced a temporary pause on pending decisions on liquefied natural gas exports to certain countries. However, upon taking office, the current president signed an Executive Order resuming the processing of permit applications for such projects. Litigation risks are also increasing as a number of parties have sought to bring suit against certain oil and natural gas companies operating in the United States in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or that such companies have been aware of the adverse effects of climate change but failed to adequately disclose those impacts to their investors or customers.

Moreover, climate change may result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in the meteorological and hydrological patterns, that could adversely impact us, our customers’ and our suppliers’ operations. Such physical risks may result in damage to our customers’ facilities or otherwise adversely impact our operations, such as if facilities are subject to water use curtailments in response to drought, or demand for our customers’ products, such as to the extent warmer winters reduce the demand for energy for heating purposes, which may ultimately reduce demand for the products and services we provide. Such physical risks may also impact our suppliers, which may adversely affect our ability to provide our products and services. Extreme weather conditions can interfere with our operations and increase our costs, and damage resulting from extreme weather may not be fully insured.

Endangered and Threatened Species. Environmental laws such as the Endangered Species Act (“ESA”) and analogous state laws may impact exploration, development and production activities in areas where we operate. The ESA provides broad protection for species of fish, wildlife and plants that are listed as threatened or endangered. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act and various state analogs. The U.S. Fish and Wildlife Service (“FWS”) may identify previously unidentified endangered or threatened species or may designate critical habitat and suitable habitat areas that it believes are necessary for survival of a threatened or endangered species. For example, the dunes sagebrush lizard, which is found only in the active and semi-stable shinnery oak dunes of southeastern New Mexico and adjacent portions of Texas (including areas where our customers operate), has, since May 2024, been listed as endangered under the ESA. To the extent any protections are implemented for this or any other species, it could cause us or our customers to incur additional costs or become subject to operating restrictions or operating bans in the affected areas.

Regulation of Hydraulic Fracturing and Related Activities. Our hydraulic fracturing operations are a significant component of our business. Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons, particularly natural gas, from tight formations, including shales. The process, which involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and natural gas commissions. However, federal agencies have asserted regulatory authority over certain aspects of the process. Although several of these rulemakings have been rescinded, modified or subjected to legal challenges, new or more stringent regulations may be promulgated by the current government. For example, in March 2024, the Bureau of Land Management (“BLM”) finalized a rule that requires operators to limit flaring from well sites on federal lands, and allows the delay or denial of permits if BLM finds that an operator’s methane waste minimization plan is insufficient. The rule was challenged by various states in the District Court for the District of North Dakota, and, in September 2024, that court ordered

that the rule cannot be enforced within the plaintiff states pending the outcome of the litigation. Although the rule is currently being implemented in areas not covered by the order, the future of the rule is uncertain. The previous administration also called for revisions and restrictions to the leasing and permitting programs for oil and gas development on federal lands and, for a time, suspended federal oil and gas leasing activities. The Department of the Interior (“DOI”) issued a report recommending various changes to the federal leasing program, though many such changes would require congressional action. In July 2023, the BLM finalized a rule to update the fiscal terms of federal oil and gas leases, which increases fees, rents, royalties, and bonding requirements. The rule also adds new criteria for BLM to consider when determining whether to lease nominated land, including the presence of important habitats or wetlands, the presence of historical properties or sacred sites, and recreational use of the land. Any regulations that restrict, ban or effectively ban such operations may adversely impact demand for our products and services. Further, legislation to amend the Safe Drinking Water Act to repeal the exemption for hydraulic fracturing (except when diesel fuels are used) from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, have previously been proposed in Congress. Several states and local jurisdictions in which we or our customers operate also have adopted or are considering adopting regulations that could restrict or prohibit hydraulic fracturing in certain circumstances, impose more stringent operating standards and/or require the disclosure of the composition of hydraulic fracturing fluids.

Increased regulation of hydraulic fracturing and related activities could subject us and our customers to additional permitting and financial assurance requirements, more stringent construction specifications, increased monitoring, reporting and record keeping obligations, and plugging and abandonment requirements. New requirements could result in increased operational costs for us and our customers, and reduce the demand for our services. For more information on each of these items, see our risk factor titled “Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.”

OSHA Matters. The Occupational Safety and Health Act (“OSHA”) and comparable state statutes regulate the protection of the health and safety of workers. In addition, the OSHA hazard communication standard requires that information be maintained about hazardous materials used or produced in operations and that this information be provided to employees, state and local government authorities and the public.

Human Capital

Our employees are our key asset. Our primary human capital management objectives are to effectively engage, develop, retain and reward our employees. As of December 31, ~~2024~~2025, we employed approximately 1,~~900~~700 people, and none of our employees are represented by a union. All of our employees work for or support our ~~hydraulic~~Hydraulic ~~fracturing~~Fracturing, ~~wireline~~Wireline, ~~cementing~~Cementing and ~~power~~Power ~~generation~~Generation ~~services~~ operating segments. We believe that we have good relations with our employees. We believe that our employees are a key component of our ability to attract and retain customers as a result of their operational excellence in the field.

Some examples of significant programs and initiatives that support our objective of attracting, developing and retaining our ~~diverse and inclusive~~ workforce include:

•Opportunity and Engagement. We are an equal opportunity employer and prohibit discrimination against any employee and applicant on the basis of any legally protected characteristic. We believe that in order to attract and retain talent with the skill sets and expertise that can help to maximize our operational efficiencies across all levels in the Company, it is in our best interest to create a culture that is welcoming. We conducted a pulse employee engagement survey in 2025, which confirmed continued strong overall employee engagement results with improvement over the 2024 survey in the categories of future vision, leadership trust and belonging. The improvement in engagement scores is attributed to action planning undertaken by department leadership and improved communication and transparency by the senior leadership team. Attracting the right people to ProPetro remains top priority. Some examples of this effort to recruit and develop our team and culture include:

the Company, it is in our best interest to create a culture that is inclusive. We conducted our second annual employee engagement survey in 2024. The results show improvement in our overall employee engagement score over the 2023 survey and above industry benchmarks. The survey focuses on engagement, manager effectiveness, training and tools to ensure that employees are well equipped to do their jobs effectively and workplace culture. Attracting the right people to ProPetro remains top priority. Some examples of this effort to recruit and develop our team and culture include:

◦a commitment to conducting business in a manner that respects all human rights in compliance within the requirements of applicable laws;

◦a commitment within our business operations to promoting and encouraging respect ~~for human rights~~ and fundamental freedoms for all without ~~distinctions~~unlawful discrimination on the basis of any ~~kind~~protected characteristic, such as race, color, sex, ~~language,~~ religion, ~~political~~and ornational ~~other opinions~~origin;

◦working with personnel, business partners and other parties directly linked to our operations that share our commitment to these same legal compliance principles;

◦maintaining employment policies reflecting our commitments, including our code of conduct, our equal employment opportunity employer policy, and our anti-harassment and anti-discrimination policy; and

◦providing an anonymous Ethics and Compliance hotline that is promoted internally and accessible from our intranet and website to make it ~~possible~~easy for grievances regarding health and safety to be addressed early and remediated directly, in confidence and without fear of retaliation.

•Training and Safety. We offer in-depth, role-appropriate safety training upon hiring and as part of the continuous development of our employees. The safety of our employees, our customers, and the communities in which we operate is paramount. We track and evaluate safety incidents at wellsites and offices, and if an accident does occur, we aim to take actions to mitigate similar incidents from ~~reoccurring~~recurring in the future. The Company seeks to incentivize employees to focus on conducting operations in accordance with our strict safety standards, ~~and~~as ~~encourages~~well ~~employees~~as to immediately report any breach of safety protocol, which is highly encouraged. ~~Ten~~Employees receive training to reinforce reporting rights and responsibilities, as well as non-retaliation policies. The weighting for safety performance was increased from ten percent ofin ~~our~~2024 ~~executive~~to ~~officers’~~twenty ~~annual~~percent ~~target~~in ~~bonuses~~2025 ~~under~~in the ~~2024~~executive officers’ annual incentive program. ~~were~~This change was intended to bring increased focus on safety performance. The 2025 safety incentive was based upon the Company’s achievement of certain safety goals, including atargets ~~target~~for total recordable incident rate and lost time incident rate.

•Professional Development. In ~~2024~~2025, the Company continued its focus on leadership development, targeting leadership positions including frontline supervisors and above. Internal facilitators were trained and certified to deliver content to drive program efficiency and better associate the topics and importance of the training to the business. The Company ~~also~~launched ~~transitioned~~ the ~~Human~~Workday ~~Resources~~Learning ~~Information~~Management System (~~HRIS~~the “LMS”) ~~from~~in ~~PayCom~~2025 to ~~Workday~~support tothe ~~gain~~leadership ~~greater~~development ~~talent~~program ~~related functionality~~ and ~~efficiency~~make inmore ~~the~~resources ~~areas~~available ofto ~~performance~~employees ~~management,~~to ~~succession~~support ~~planning,~~general ~~learning and~~ development. ~~and~~These ~~compensation~~materials ~~planning.~~are ~~Responsibility~~easy for ~~Human~~employees ~~Capital~~to ~~Management~~access ~~(HCM)~~from inany ~~Workday~~device ~~was~~to ~~designed~~drive totheir ~~ensure~~own ~~the~~development ~~direct~~interests. ~~supervisor~~Also, ~~working~~supervisors ~~closest~~are ~~with~~able ~~the~~to ~~employee~~assign isspecific attraining through the ~~center~~LMS ofduring the ~~conversation~~annual ~~driving~~performance ~~engagement,~~appraisal ~~providing~~process ~~feedback,~~to ~~rewarding~~emphasize position specific training to improve performance and ~~supporting~~support overall development.

•Compensation, Health, Wellness and Benefits. Our employee benefit offerings are designed to meet the varied and evolving needs of our entire workforce across the Company and we believe they are consistent with those provided by our peer companies with which we compete for talent. The Company provides employees with the ability to participate in health and welfare plans, including medical, dental, life, accidental death and dismemberment and short-term and long-term disability insurance plans.

In ~~2024~~2025, as part of our 401(k) plan, we continued to focus on financial wellness education and group and individual consultations for employees as well as encouraging participation in the program. The program opportunities included many crucial topics ranging from budgeting and debt management to understanding plan options and investment strategy. Concerning health benefits, in ~~2024~~2025 we ~~added~~continued ~~additional~~our ~~services~~focus ~~focused~~ on emotional and mental health, as well as certain preventative health services related to the early detection of concerns including breast cancer, diabetes and cardiovascular disease.

We also strive to give back to the areas in which we conduct business operations, and in which our employees live and work. Our employees give generously and receive up to eight hours per year of paid time off to participate in community service. Our employee-led P.U.M.P. Committee also organizes or sponsors events in which employees can choose to participate in addition to our paid community service time benefit.

Availability of Filings

Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act, are made available free of charge on our internet website at www.propetroservices.com, as soon as reasonably practicable after we have electronically filed the material with, or furnished it to, the SEC. The SEC maintains an internet site that contains our reports, proxy and information statements and our other SEC filings. The address of that website is www.sec.gov. ~~Please~~In ~~note~~addition ~~that~~to ~~information~~its ~~contained~~reports onfiled ~~our~~or ~~website~~furnished with the SEC, ~~whether~~the ~~currently~~Company ~~posted~~publicly ordiscloses ~~posted~~material information from time to time in its press releases, at the ~~future~~annual meeting of Shareholders, isin ~~not~~publicly accessible conferences and Investor presentations, and through its website (principally in its Investor Relations page). Please note that references to the Company’s website in this Form 10-K are provided as a ~~part~~convenience and do not constitute, and should be deemed, an incorporation by reference of ~~this~~the ~~Annual~~information ~~Report~~contained on, or available through the ~~documents~~website, ~~incorporated~~and bysuch ~~reference~~information inshould not be considered part of this ~~Annual~~Form ~~Report~~10-K.

Board of Directors and Executive Officers

Set forth below are the names, age and business experience of the Board of Directors of the company as of February 2019, ~~2025~~2026.

Phillip A. Gobe, 7273, began serving as our Chairman of the Board in July of 2019 and as Executive Chairman in October 2019. Mr. Gobe was appointed as our Chief Executive Officer on March 13, 2020 and served in that role until August 31, 2021, at which point he was re-appointed as Executive Chairman. Mr. Gobe stepped down as Executive Chairman on March 31, 2022, and continues serving the Company as Chairman of the Board. Mr. Gobe ~~has~~ served as a director of Pioneer ~~since~~from July 2014 until Pioneer’s merger with ExxonMobil in May 2024. Mr. Gobe previously served as Chairman of the Board for Pantheon Resources PLC until his June 2023 retirement. He also previously served as a director of Scientific Drilling International and Pioneer Southwest Energy Partners L.P. Mr. Gobe joined Energy Partners, Ltd as Chief Operating Officer in December 2004 and became president in May 2005, and served in those capacities until his retirement in September 2007. Mr. Gobe also served as a director of Energy Partners, Ltd. from November 2005 until May 2008. Prior to that, Mr. Gobe served as Chief Operating Officer for Nuevo Energy Company from February 2001 until its acquisition by Plains Exploration & Production Company in May 2004. Prior to that time, he held numerous operations and human resources positions with Vastar Resources, Inc. and Atlantic Richfield Company (“ARCO”) and its subsidiaries. Mr. Gobe has a ~~Bachelors~~Bachelor of Arts degree from the University of Texas and a Master of Business Administration degree from the University of Louisiana in Lafayette. Mr. Gobe’s extensive experience in the energy industry, including service as a director to public corporations in the industry, makes him well suited to serve as Chairman of the Board.

Samuel D. Sledge, 3839, has served as our Chief Executive Officer and as a member of our Board since August 31, 2021. Mr. Sledge previously served as the Company’s President from April 2021 to August 2021, and prior to that, he served as Chief Strategy and Administrative Officer beginning in March 2020. Mr. Sledge has significant experience with ProPetro having joined the Company in 2011. Mr. Sledge has served in various capacities throughout his tenure such as a Frac Technical Specialist and Technical Operations Manager where his duties included quality control, planning and logistics, and the development of the engineering program. Mr. Sledge has also served as ProPetro’s Vice President of Finance, Corporate Development, and Investor Relations where his responsibilities included financial planning and analysis, strategic initiatives, and investor relations. Mr. Sledge also serves on the Board of the Energy Workforce and Technology Council (“EWTC”), an industry association for energy service companies, and currently serves as the Chairman of the EWTC Board. Mr. Sledge received a Bachelor of Business Administration and a ~~Masters~~Master of Business Administration from Baylor University. We believe Mr. Sledge’s experience in the energy industry and his significant experience in management roles at the Company make him well suited to serve as a director.

Spencer D. Armour III, 7172, has served as a member of our Board since February 2013. Mr. Armour has over 30 years of executive and entrepreneurial experience in the energy services industry. Mr. Armour served as President of PT Petroleum LLC in Midland, Texas from 2011 to 2018. He was the Vice President of Corporate Development for Basic Energy Services, Inc. from 2007 to 2008, which acquired Sledge Drilling Corp., a company Mr. Armour co-founded and served as Chief Executive Officer from 2005 to 2006. From 1998 through 2005, he served as Executive Vice President of Patterson-UTI Energy, Inc., which acquired Lone Star Mud, Inc., a company Mr. Armour founded and served as President from 1986 to 1997. Mr. Armour also served on the board of Patterson-UTI Energy, Inc. from 1999 to 2001. He currently serves on the boards of Viper Energy, Inc. and CES Energy Solutions Corp and is a partner at Geneses Investments. Mr. Armour received a ~~B.S.~~Bachelor of Science in Economics from the University of Houston in 1977 and served on the University of Houston System Board of Regents from 2011 until 2018. We believe that Mr. Armour’s extensive experience in the energy services industry and his deep knowledge of industry dynamics within the Permian Basin make him well suited to serve as a director.

Mark S. Berg, 6667, has served as a member of our Board since 2019. Mr. Berg is a senior energy industry executive with extensive commercial and operational experience, including leadership of strategic planning, business development, land, water management, completion and well services, environmental, sustainability, legal, government relations and communications. During his 20-year career with Pioneer ~~Natural Resources (“Pioneer”)~~, then an NYSE-listed independent oil and gas exploration and production company, first as Executive Vice President & General Counsel from 2005 to 2014 and then as Executive Vice President, Corporate Operations from 2014 until its merger with ExxonMobil in 2024, he played a key role in transforming the company into a major U.S. shale resource developer. He led the negotiating team for the $65 billion merger with ExxonMobil as well as multiple multibillion-dollar mergers, global divestitures, and cross-border joint ventures. Prior to joining Pioneer, Mr. Berg served from 2002 to 2004 as Senior Vice President, General Counsel & Secretary of Hanover Compressor Company, then an NYSE-listed company specializing in natural gas compression and processing, where he instituted disciplined internal controls, resolved an SEC investigation, and settled securities class action litigation. From 1997 to 2002 he served as Executive Vice President & General Counsel of American General Corporation, a Fortune 200 diversified financial services company, and oversaw its $27 billion merger with American International Group. Mr. Berg began his career with the Houston based law firm Vinson & Elkins L.L.P.

and served as a partner from 1990 through 1997, focused on mergers, acquisitions and international project development. From 2018 to 2020, he served on the board of directors of HighPoint Resources, an exploration and production company then listed on the NYSE. Mr. Berg currently serves as the Chairman of the Board of Crystal Clearwater Resources, a leading wastewater solutions company. Additionally, Mr. Berg serves on the boards of Oncor Electric Delivery Holdings Company LLC and Oncor Electric Delivery Company LLC, a regulated electricity transmission and distribution company. Mr. Berg also serves as the founding Vice Chairman of the Permian Strategic Partnership, a coalition of Permian Basin energy companies and higher education institutions focused on supporting public education, healthcare, road safety and workforce development in the Permian Basin region. Mr. Berg earned a Bachelor of Arts degree in Public Policy from Tulane University and a Juris Doctor from the University of Texas. We believe that Mr. Berg’s vast leadership experience in the energy industry makes him well suited to serve as a director.

Anthony J. Best, 76, has served as a member of our Board since January 2018 and was elected to serve as Lead Independent Director in October 2019. Mr. Best has over 40 years of experience in the energy industry. Mr. Best retired as the Chairman of the board of Newpark Resources in May 2023. He was previously a director with Quantum Energy Partners’ (“Quantum”) portfolio companies, ExL Petroleum and Middle Fork Energy Partners, and also served as Senior Advisor for Quantum. Prior to joining Quantum, Mr. Best served in various roles with SM Energy Company, an oil and gas exploration company, commencing in 2006 as its President and Chief Operating Officer, and as its Chief Executive Officer from February 2007 through January 2015. From 2003 to 2005, Mr. Best served as President and Chief Executive Officer of Pure Resources, Inc., a Unocal development and exploration company. From 2000 to 2003, Mr. Best served as an independent consultant offering leadership and oil and gas consultation to energy companies and volunteer organizations, and from 1979 through 2000, Mr. Best served in various roles of increasing responsibility at ARCO, culminating in the position of President, ARCO Latin America. Mr. Best holds a Master of Science in Engineering Management degree from the University of Alaska and a Bachelor of Science degree in Mechanical Engineering from Texas A&M University. Prior to beginning his business career, Mr. Best served five years as an engineering officer in the United States Air Force. We believe that Mr. Best’s experience in significant management roles with companies operating in the Permian Basin and his broad experience in the energy industry make him well suited to serve as a director.

G. Larry Lawrence, 74, was appointed to our Board in December 2020. Mr. Lawrence previously served as Audit Committee Chair of Legacy Reserves, LP’s Board of Directors, a role he held from 2006 to 2019. From January 2021 until June 2021, Mr. Lawrence served as the interim Chief Financial Officer of Natural Gas Services Group, a natural gas compression equipment provider, where he previously served as Chief Financial Officer for nine years. Prior to Natural Gas Services Group, Mr. Lawrence served as Chief Financial Officer for Lynx Operating Co. Inc., an oil and gas exploration company, for three years and as Chief Financial Officer for Pure Resources, Inc., an oil and gas E&P company, for two years. He has also held finance and management consulting positions for Parson Group, ARCO and Crescent Consulting. Mr. Lawrence earned his bachelor’s degree with an accounting major from Dillard University in New Orleans. We believe that Mr. Lawrence’s broad experience in the energy industry, including his service as a director and executive officer with various companies, makes him well suited to serve as a director.

Mary P. Ricciardello, 70, has served as a member of our Board since January 2023. Ms. Ricciardello currently serves as a director, Audit Committee member and Corporate Governance, Nominating and Sustainability Committee member at Eagle Materials Inc. Ms. Ricciardello previously served as a director at Devon Energy from 2008 to 2021, Noble Corporation from 2003 to 2020, Enlink Midstream from 2014 to 2018, Midstates Petroleum from 2010 to 2013 and U.S. Concrete from 2003 to 2010. Beginning in 1982, Ms. Ricciardello enjoyed a distinguished, two-decade career at Reliant Energy Inc. (“Reliant”) and its predecessor, Houston Lighting & Power Company, an electricity generation and retail services company, where she held several roles of increasing responsibility in the financial services and treasury functions. In 1996, Ms. Ricciardello was appointed as Reliant’s Vice President and Comptroller and she served as its Senior Vice President and Chief Accounting Officer from 1999 until her retirement in 2002. Ms. Ricciardello earned a Bachelor of Science degree in Business Administration from the University of South Dakota and a Master of Business Administration from the University of Houston. She is also a Texas licensed Certified Public Accountant and earned a CERT Certificate in Cybersecurity from Carnegie Mellon University. We believe that Ms. Ricciardello is well suited to serve as a director based on her accounting and financial expertise and public company board and committee experience.

Michele Vion, 66, was appointed to our Board in February 2020. Ms. Vion previously served as Vice President, Human Resources at HighPoint Resources Corporation, a successor to the Bill Barrett Corporation, an oil and gas E&P company, from August 2010 to September 2019. Ms. Vion was previously employed at Level 3 Communications, Inc., an international communications company, starting in 2006 and ultimately as Group Vice President of Human Resources up to January 2010. Ms. Vion also previously served as Vice President of Human Resources for Sun Microsystems, Inc., a computer networking company, for seven years. She also previously held senior human resource and client account management positions at

~~with~~Prudential ~~ExxonMobil~~Financial, asInc., ~~well~~an asinsurance ~~multiple~~and ~~multibillion-dollar~~investment ~~mergers,~~management ~~global~~company ~~divestitures~~and JP Morgan, ~~and~~a ~~cross-border~~global ~~joint~~financial ~~ventures~~services firm. Prior to joining ~~Pioneer~~JP Morgan, MrMs. ~~Berg~~Vion served ~~from~~in ~~2002~~an toaccounting ~~2004~~position as ~~Senior~~a ~~Vice~~Regional ~~President,~~Controller ~~General~~for ~~Counsel~~the &Eastern ~~Secretary~~Region ofat ~~Hanover~~Sony ~~Compressor~~Corporation ~~Company,~~of ~~then~~America. anMs. ~~NYSE-listed~~Vion ~~company~~previously ~~specializing~~served inas ~~natural~~Compensation ~~gas~~Committee ~~compression~~Chair and ~~processing,~~as ~~where~~a hemember ~~instituted~~of ~~disciplined~~the ~~internal~~Audit ~~controls,~~Committee ~~resolved~~of anBoingo ~~SEC investigation~~Wireless, ~~and settled securities class action litigation~~Inc.’s ~~From~~Board ~~1997~~of toDirectors, ~~2002~~roles heshe ~~served~~held asfrom ~~Executive~~2018 ~~Vice~~until ~~President~~Boingo’s &acquisition ~~General~~by ~~Counsel~~Digital ofColony ~~American General Corporation~~Management, aLLC ~~Fortune~~in ~~200~~June ~~diversified~~2021. ~~financial~~Ms. ~~services~~Vion ~~company,~~also ~~and~~served ~~oversaw~~on ~~its~~the ~~$27~~board ~~billion~~and ~~merger~~as ~~with~~Chair ~~American~~of ~~International~~the ~~Group~~Compensation ~~(“AIG”). Mr.~~Committee ~~Berg~~and ~~began~~as ~~his~~member ~~career~~of ~~with~~ the ~~Houston~~Audit ~~based~~Committee ~~law~~and ~~firm~~Nominating ~~Vinson & Elkins L.L.P.~~ and ~~served~~Corporate asGovernance aCommittee ~~partner~~of ~~from~~Callidus ~~1990~~Software ~~through~~Inc., ~~1997~~a publicly-traded, ~~focused~~cloud-based onsoftware ~~mergers~~company, ~~acquisitions~~from ~~and~~2005 ~~international~~to ~~project development~~2016. ~~From~~Currently, ~~2018~~Ms. toVion ~~2020,~~serves heas ~~served~~Chief onHuman ~~the~~Resources ~~board~~Officer offor ~~directors~~Stored ofEnergy ~~HighPoint Resources~~Systems, ana ~~exploration~~privately ~~and~~held ~~production~~ company ~~then~~based ~~listed~~in onLongmont, ~~the NYSE~~CO. ~~Effective~~ ~~March 2025, Mr~~Ms. ~~Berg~~Vion ~~has~~holds ~~been~~a ~~appointed~~Bachelor toof ~~serve~~Arts onin ~~the~~East ~~boards~~Asian ofStudies ~~Oncor~~and ~~Electric~~Economics ~~Delivery~~from ~~Holdings~~Wesleyan ~~Company~~University, ~~LLC~~has ~~and~~attended ~~Oncor~~Stanford ~~Electric~~University’s ~~Delivery~~Director’s ~~Company LLC~~College, aand ~~regulated~~participated ~~electricity~~in ~~transmission~~the ~~and~~Financial ~~distribution~~Times’ ~~company.~~Director MrExchange. ~~Berg~~We ~~also~~believe ~~serves~~that asMs. ~~the~~Vion ~~founding~~is ~~Vice~~well ~~Chairman~~suited ofto ~~the~~serve ~~Permian~~as ~~Strategic Partnership,~~ a ~~coalition~~director ofbased ~~Permian~~on ~~Basin~~her ~~energy~~executive ~~companies~~leadership ~~and~~experience ~~higher~~in ~~education~~human ~~institutions~~resources ~~focused~~and onaccounting ~~supporting~~and public ~~education,~~company ~~healthcare,~~board ~~road safety~~ and ~~workforce~~committee ~~development in the Permian Basin region~~experience.

~~Anthony~~Alex JV. ~~Best~~Volkov, 7553, has served as a member of our Board since ~~January~~May ~~2018 and was elected to serve as Lead Independent Director in October 2019~~2024. Mr. ~~Best~~Volkov has ~~over~~almost 40three ~~years~~decades of experience in ~~the~~various ~~energy~~roles ~~industry.~~within MrExxonMobil. ~~Best~~Since ~~retired~~1997, ~~as the Chairman of the board of Newpark Resources in May 2023~~Mr. HeVolkov’s ~~was~~roles ~~previously~~have aspanned ~~director~~marketing, ~~with~~business ~~Quantum~~development, ~~Energy~~supply ~~Partners’~~chain ~~(“Quantum”) portfolio companies~~logistics, ~~ExL Petroleum~~ and ~~Middle~~strategy ~~Fork~~development. ~~Energy~~His ~~Partners,~~international ~~and~~experience ~~also~~includes ~~served~~serving as ~~Senior~~Vice ~~Advisor~~President ~~for~~of ~~Quantum.~~Exxon ~~Prior~~Neftegas toLimited ~~joining~~in ~~Quantum~~Moscow, ~~Mr.~~overseeing ~~Best~~commercial ~~served~~activities in ~~various~~Russia ~~roles with SM Energy Company, an oil~~ and ~~gas~~later ~~exploration~~moving ~~company,~~to ~~commencing~~the inUnited ~~2006~~Kingdom asto ~~its~~lead ~~President~~international ~~and~~natural ~~Chief~~gas ~~Operating~~marketing ~~Officer,~~ and astrading ~~its Chief Executive Officer from February 2007 through January 2015~~efforts. ~~From~~In ~~2003 to 2005~~2019, Mr. ~~Best~~Volkov ~~served~~transitioned to Houston as Vice President, ~~and~~Global ~~Chief~~LNG ~~Executive~~Marketing, ~~Officer~~overseeing ofExxonMobil’s ~~Pure~~LNG ~~Resources,~~portfolio ~~Inc.~~globally, a ~~Unocal~~position ~~development~~he ~~and~~held ~~exploration~~until ~~company~~2021. ~~From~~Between ~~2000~~2021 toand ~~2003~~2023, ~~Mr.~~he ~~Best~~held ~~served~~positions as anVice ~~independent~~President, ~~consultant~~Commercial ~~offering~~& ~~leadership~~Power and ~~oil~~then ~~and~~as ~~gas~~Vice ~~consultation~~President, toStrategy ~~energy companies~~ and ~~volunteer~~Business ~~organizations~~Development, ~~and~~culminating ~~from~~in ~~1979~~his ~~through~~current ~~2000~~role, ~~Mr.~~the ~~Best~~Vice ~~served~~President inof ~~various~~Commercial ~~roles~~& ofIntegration ~~increasing~~overseeing ~~responsibility~~unconventional atbusiness ~~ARCO~~development, ~~culminating~~land ~~in the position of President~~management, ~~ARCO~~and ~~Latin~~midstream ~~America~~infrastructure activities. Mr. ~~Best~~Volkov ~~holds~~is a ~~Master~~graduate of ~~Science in Engineering Management degree from~~ the University of ~~Alaska~~Nizhni Novgorod, Russia, and holds a ~~Bachelor~~Master of ~~Science~~Business ~~degree~~Administration ~~in Mechanical Engineering~~ from ~~Texas~~the ~~A&M~~ University. ~~Prior~~of ~~to beginning his business career, Mr~~Alabama. ~~Best served five years as an engineering officer in the United States Air Force.~~ We believe ~~that~~ Mr. ~~Best~~Volkov’s broad experience in ~~significant management roles with companies operating in~~ the ~~Permian~~energy ~~Basin~~industry, ~~and~~including ~~his~~various ~~broad~~business ~~experience~~development inroles ~~the~~at ~~energy~~ExxonMobil, ~~industry~~makes ~~make~~ him well suited to serve as a director.

G.Set ~~Larry~~forth ~~Lawrence,~~below ~~73,~~are ~~was~~the ~~appointed to our Board in December 2020. Mr. Lawrence previously served as Audit Committee Chair of Legacy Reserves~~name, ~~LP’s Board of Directors~~age, aposition ~~role~~and hedescription ~~held~~of ~~from 2006 to 2019. From January 2021 until June 2021, Mr. Lawrence served as~~ the ~~interim~~business ~~Chief~~experience ~~Financial Officer~~ of ~~Natural~~our ~~Gas~~executive ~~Services~~officers ~~Group,~~(other athan ~~natural~~those ~~gas~~who ~~compression~~are equipment provider, where he previously served as Chief Financial Officer for nine years. Prior to Natural Gas Services Group, Mr. Lawrence served as Chief Financial Officer for Lynx Operating Co. Inc., an oil and gas exploration company, for three years and as Chief Financial Officer for Pure Resources, Inc., an oil and gas E&P company, for two years. He has also ~~held~~Directors ~~finance~~ and ~~management~~included ~~consulting~~above) positions for Parson Group, ARCO and Crescent Consulting. Mr. Lawrence earned his bachelor’s degree with an accounting major from Dillard University in New Orleans. We believe that Mr. Lawrence’s broad experience in the energy industry, including his service as aof ~~director and executive officer with various companies~~February 19, ~~makes him well suited to serve as a director~~2026.

~~Jack~~Caleb BL. ~~Moore~~Weatherl, 7138, has served as aour ~~member~~Chief ofFinancial ~~our~~Officer ~~Board~~ since ~~March~~July ~~2017~~2025. Mr. ~~Moore~~Weatherl ~~most~~has ~~recently~~over ~~served~~a asdecade ~~President~~of ~~and~~experience ~~Chief~~in ~~Executive~~senior ~~Officer~~level ofpositions ~~Cameron~~in ~~International~~private ~~Corporation~~companies. ~~(“Cameron”),~~Before anjoining ~~oil~~the ~~and~~Company, ~~gas~~Mr. ~~industry~~Weatherl ~~equipment~~served ~~manufacturer~~as ~~and~~Chief ~~provider~~Executive Officer, ~~from~~and ~~April~~as ~~2008~~a toBoard ~~October~~Member ~~2015~~of ~~and~~Garrison ~~served~~Energy asHoldings ~~Chairman~~LLC, ofa ~~the~~Midland, ~~Board~~Texas-based ofoil ~~Cameron~~and ~~from~~gas ~~May~~exploration ~~2011~~and ~~until~~production itcompany, ~~was~~from ~~acquired~~May by2023 ~~Schlumberger~~until inSeptember ~~April 2016~~2024. Prior to ~~his employment with Cameron~~that, ~~Mr.~~he ~~Moore~~served ~~held~~as ~~various~~the ~~management~~President ~~positions~~and atChief ~~Baker~~Financial ~~Hughes~~Officer ~~Incorporated,~~of ~~where~~Stronghold heEnergy ~~was~~II ~~employed~~Holdings, ~~for~~LLC, 23a ~~years.~~Midland, ~~Mr.~~Texas-based ~~Moore~~oil ~~currently~~and ~~serves~~gas onexploration ~~the~~and ~~Board~~production ofcompany, ~~Directors~~from ofDecember ~~Occidental~~2017 ~~Petroleum~~to ~~Corporation,~~October ~~KBR Inc.~~2022, and ~~the~~as ~~University~~a ofBoard ~~Houston~~Member ~~System~~from ~~Board~~October of2021 ~~Regents.~~to MrOctober 2022. ~~Moore~~His ~~previously~~work ~~served~~history onalso ~~the~~includes ~~board~~serving ofas ~~the~~Chief ~~American~~Financial ~~Petroleum~~Officer ~~Institute~~for Desert Royalty Company, ~~the~~L.L.C. ~~National~~from ~~Ocean~~June ~~Industries~~2016 ~~Association,~~to ~~Rowan~~December ~~Companies~~2017, ~~plc~~Vice President, Co-Founder and ~~the~~Board ~~Petroleum~~Member ~~Equipment~~of ~~Suppliers~~Stronghold ~~Association.~~Energy MrPartners, L.P. ~~Moore~~from ~~received~~May a2014 ~~Bachelor~~to ofJune ~~Business~~2016 ~~Administration~~and ~~from~~Vice ~~the~~President ~~University~~ of ~~Houston~~Weatherl ~~and~~Energy ~~attended~~Investments, ~~the~~L.P. ~~Advanced~~from ~~Management~~August ~~Program~~2013 atto ~~Harvard~~June ~~Business School~~2016. WeEarlier ~~believe~~in ~~that~~his career, Mr. ~~Moore’s~~Weatherl ~~wealth~~held ofpositions ~~experience~~at inBain ~~the~~Capital ~~oilfield~~and ~~service~~McKinsey ~~sector,~~& ~~including~~Company. ~~service~~Mr. asWeatherl aearned ~~director~~his ~~and~~Bachelor ~~executive~~of ~~officer~~Arts todegree ~~various~~in ~~public~~economics ~~corporations~~from inHarvard ~~the sector~~College, ~~makes~~and ~~him~~his ~~well~~Master’s ~~suited~~of toBusiness ~~serve~~Administration asfrom aHarvard ~~director~~Business School.

~~Mary~~Adam ~~P. Ricciardello~~Muñoz, 6943, has served as aour ~~member~~President ofand ~~our~~Chief ~~Board~~Operating Officer since August 2021, and prior to that, he served as Chief Operating Officer since January ~~2023~~2021 and served as Senior Vice President of Operations since March 2020. MsMr. ~~Ricciardello~~Muñoz ~~currently~~joined ~~serves~~the asCompany ain ~~director,~~2010 ~~Audit~~to ~~Committee~~initiate ~~member~~ProPetro’s ~~and~~Permian ~~Corporate~~Basin ~~Governance~~pressure pumping operation. Prior to joining the Company, ~~Nominating~~Mr. ~~and~~Muñoz ~~Sustainability~~held ~~Committee~~sales ~~member~~and operations roles at ~~Eagle~~Frac ~~Materials~~Tech ~~Inc~~Services and Weatherford International. MsSince joining the Company, Mr. ~~Ricciardello~~Muñoz ~~previously~~has served as athe ~~director~~Director atof ~~Devon~~Business ~~Energy~~Development ~~from~~and ~~2008~~Technical toServices ~~2021,~~where ~~Noble~~he ~~Corporation~~was ~~from~~responsible ~~2003~~for tooverseeing ~~2020,~~the ~~Enlink~~growth ~~Midstream~~of ~~from~~the ~~2014~~hydraulic fracturing operations as well as managing the department’s day-to-day ~~2018,~~technical ~~Midstates~~services. ~~Petroleum~~Mr. ~~from~~Muñoz ~~2010~~has most recently served as the Vice President of Frac Services where his duties included leading the hydraulic fracturing division through specific efforts to ~~2013~~increase operational efficiencies and Umaximize financial productivity.S Mr. ~~Concrete~~Muñoz received a Bachelor of Business Marketing from ~~2003~~The toUniversity of Texas at the Permian Basin.

John J. “Jody” Mitchell, 43, has served as our General Counsel and Corporate Secretary of the Company since January 2023. Prior to his appointment as General Counsel, Mr. Mitchell served as the Company’s Vice President and Deputy General Counsel since April 2021. Before joining the Company, Mr. Mitchell served in various roles at Concho Resources Inc., a hydrocarbon exploration company acquired by ConocoPhillips in 2021 (“Concho”), from 2014 to 2021, including Director of Marketing and Midstream and, prior to that, Associate General Counsel. Before joining Concho, Mr. Mitchell served as counsel supporting the upstream and midstream businesses at Petrohawk Energy Corporation (“Petrohawk”) and at BHP Billiton following BHP Billiton’s acquisition of Petrohawk. Mr. Mitchell began his career as an associate at Locke Lord Bissell & Liddell LLP, where he concentrated on oil, gas and energy litigation and construction litigation. Mr. Mitchell holds a Bachelor of Arts from the University of Texas and a Juris Doctor from the University of Houston Law Center.

~~2010~~Shelby K. ~~Beginning~~Fietz, ~~in 1982~~44, ~~Ms.~~has ~~Ricciardello~~served ~~enjoyed~~as aour ~~distinguished,~~Chief ~~two-decade~~Commercial ~~career~~Officer atof ~~Reliant~~the ~~Energy~~Company ~~Inc.~~since ~~(“Reliant”)~~November ~~and~~2023. ~~its~~Mr. ~~predecessor,~~Fietz ~~Houston~~joined ~~Lighting~~ProPetro &in ~~Power Company~~2012, ~~an electricity generation~~ and ~~retail~~prior ~~services~~to ~~company,~~his ~~where~~appointment ~~she~~as ~~held~~Chief ~~several~~Commercial ~~roles~~Officer, ofMr. ~~increasing~~Fietz ~~responsibility~~served inas the ~~financial~~Company’s ~~services~~Vice ~~and~~President ~~treasury~~of ~~functions. In 1996~~Commercial, ~~Ms.~~leading ~~Ricciardello~~the ~~was~~business ~~appointed~~development, assales, ~~Reliant’s~~supply ~~Vice~~chain, ~~President~~ and ~~Comptroller~~marketing ~~and~~functions. ~~she~~He ~~served~~also aspreviously ~~its~~held ~~Senior~~the position of Vice President ~~and~~of ~~Chief~~Business ~~Accounting~~Development, ~~Officer~~Sales ~~from~~and ~~1999~~Marketing, ~~until~~while ~~her~~also ~~retirement~~leading inour ~~2002.~~supply Mschain organization. ~~Ricciardello~~Prior ~~earned~~to ahis ~~Bachelor~~appointment ofas ~~Science~~an ~~degree~~officer, inMr. ~~Business~~Fietz ~~Administration~~held ~~from~~roles ~~the University~~ of ~~South~~increasing ~~Dakota~~responsibility ~~and~~within anProPetro ~~MBA~~in ~~from~~both ~~the~~operations ~~University~~and ofbusiness ~~Houston~~development. ~~She~~Mr. isFietz also aserves ~~Texas~~in ~~licensed~~a ~~Certified~~leadership ~~Public~~capacity ~~Accountant~~with ~~and~~the ~~earned~~Permian aBasin ~~CERT~~Chapter ~~Certificate~~of inthe ~~Cybersecurity~~Energy ~~from~~Workforce ~~Carnegie~~and ~~Mellon~~Technology ~~University~~Council. ~~We believe that Ms~~Mr. ~~Ricciardello~~Fietz isholds ~~well suited to serve as~~ a ~~director~~Bachelor ~~based~~of onScience ~~her~~from ~~accounting~~Angelo ~~and~~State ~~financial expertise and public company board and committee experience~~University.

~~Michele~~Celina ~~Vion~~A. Davila, 6545, ~~was~~has ~~appointed to our Board in February 2020. Ms. Vion previously~~ served as ~~Vice~~our ~~President,~~Chief ~~Human~~Accounting ~~Resources~~Officer atsince ~~HighPoint~~November ~~Resources~~2023. ~~Corporation,~~Prior ~~a successor~~ to ~~the~~her ~~Bill~~appointment ~~Barrett~~as ~~Corporation,~~Chief anAccounting ~~oil and gas E&P company~~Officer, ~~from August 2010 to September 2019.~~ Ms. ~~Vion~~Davila ~~was~~served ~~previously~~as ~~employed~~the atCompany’s ~~Level~~Director 3of ~~Communications,~~Accounting ~~Inc.,~~and anCorporate ~~international~~Controller ~~communications~~since ~~company,~~August ~~starting~~2022 ~~in 2006~~ and ~~ultimately~~ as ~~Group~~Corporate ~~Vice~~Controller ~~President~~since ofOctober ~~Human Resources up to January 2010~~2019. Ms. ~~Vion~~Davila ~~also~~joined ~~previously~~the ~~served~~Company asin ~~Vice~~January ~~President~~2019 ofas ~~Human~~Hydraulic ~~Resources~~Fracturing ~~for Sun Microsystems, Inc~~Controller., a computer networking company, for seven years. She also previously held senior human resource and client account management positions at Prudential Financial, Inc., an insurance and investment management company and JP Morgan, a global financial services firm. Prior to joining JPthe ~~Morgan~~Company, Ms. ~~Vion~~Davila served in anvarious ~~accounting~~roles ~~position as a Regional Controller for the Eastern Region~~ at ~~Sony~~Pioneer, ~~Corporation of America. Ms. Vion previously served as Compensation Committee Chair and as~~ a ~~member~~leading ofindependent ~~the~~natural ~~Audit~~resources ~~Committee of Boingo Wireless~~company, ~~Inc.’s~~from ~~Board~~2012 ofto ~~Directors~~2018, ~~roles~~including ~~she~~Accounting ~~held~~Manager ~~from~~and, ~~2018~~prior ~~until~~to ~~Boingo’s acquisition by Digital Colony Management~~that, ~~LLC~~Accounting ~~in June 2021~~Supervisor. Ms. ~~Vion~~Davila ~~also~~began ~~served~~her oncareer ~~the board and~~ as ~~Chair~~a ofSenior ~~the~~Auditor ~~Compensation~~at ~~Committee~~Johnson, ~~and~~Miller, ~~as member of the Audit Committee~~ and ~~Nominating~~Co. ~~and~~Ms. ~~Corporate~~Davila ~~Governance~~is ~~Committee of Callidus Software Inc.,~~ a ~~publicly-traded,~~Certified ~~cloud-based~~Public ~~software~~Accountant ~~company,~~and ~~from 2005 to 2016. Ms. Vion~~ holds a Bachelor of Arts in ~~East~~Accounting ~~Asian Studies~~ and ~~Economics~~a ~~from Wesleyan University, has attended Stanford University~~Master’s ~~Director’s College, and participated~~ in ~~the~~Business ~~Financial~~Administration ~~Times’~~degree ~~Director~~from ~~Exchange.~~Texas WeTech ~~believe that Ms~~University. ~~Vion is well suited to serve as a director based on her executive leadership experience in human resources and accounting and public company board and committee experience.~~

Alex V. Volkov, 52, has served as a member of our Board since May 2024. Mr. Volkov is currently Vice President - Commercial & Integration, for ExxonMobil Upstream Unconventional business. Alex joined ExxonMobil in 1997 in Houston, Texas. During his early tenure with the company he has held diverse assignments in the areas of marketing, business development, supply chain logistics, and business strategy development. From 2014 to 2016, Alex was based in Moscow, Russia where he served as Vice President of Exxon Neftegas Limited responsible for ExxonMobil commercial activities in Russia, including natural gas sales and marketing of Sakhalin-1 gas resources. Alex moved to the United Kingdom in 2016 and he was appointed Vice President, International Gas, ExxonMobil Gas & Power Marketing and Chairman, ExxonMobil Gas Marketing Europe in 2018. In this capacity, he was responsible for ExxonMobil’s natural gas marketing and trading activities in Europe, Russia, Caspian, Malaysia, Thailand, and Australia. In 2019 Alex moved to Houston and was named Vice President, Global LNG Marketing. In this role, he had global responsibility for ExxonMobil’s Liquefied Natural Gas (LNG) portfolio and marketing of LNG for ExxonMobil’s projects and joint ventures. Between 2021 and 2023 Alex served first as Vice President, Commercial & Power and then as Vice President, Strategy and Business Development which included Upstream Acquisitions & Divestment team that was responsible for evaluation and negotiation of ExxonMobil / Pioneer merger announced in October 2023 and after the announcement he served as Transition Executive overseeing the integration of two companies . He assumed his current position in July of 2024. Alex graduated from the University of Nizhni Novgorod, Russia in 1994 and he also holds an MBA from the University of Alabama.

Set forth below are the name, age, position and description of the business experience of our executive officers (other than those who are also Directors and included above) as of February 20, 2025.

David S. Schorlemer, 57, began serving as a Special Advisor to the Chief Financial Officer on October 12, 2020 until his appointment as Chief Financial Officer on October 23, 2020. Mr. Schorlemer has two decades of experience in senior level positions in public and private companies and has focused on building integrated business systems and support organizations. He most recently served as Executive Vice President, Chief Financial Officer, Treasurer and Secretary of Basic Energy Services, Inc., a Fort Worth, Texas based oilfield services company, from September 2018 until joining the Company. Prior to that, he served as the Chief Financial Officer of Gulf Island Fabrication, Inc. from January 2017 to August 2018. His work history also includes serving as Chief Financial Officer for three oilfield services companies: GR Energy Services Management, LP from January 2016 to December 2016, Stallion Oilfield Holdings, Inc., September 2004 to December 2015 and Q Services, Inc. from July 1997 until its merger with Key Energy Services, Inc. in July 2002. He also held the role of vice president, marketing and strategic planning for Key Energy Services, Inc. from July 2002 to September 2004. Prior to entering the energy services industry, Mr. Schorlemer was a technology consultant and project manager with Accenture’s Technology Practice

where he worked on various domestic and international projects with Fortune 500 Companies in industries including: telecommunications, transportation, automotive and manufacturing and oil and gas. Mr. Schorlemer earned his Bachelor of Business Administration degree in finance from The University of Texas, and his Master of Business Administration from Texas A&M University.

Adam Muñoz, 42, has served as our President and Chief Operating Officer since August 2021, and prior to that, he served as Chief Operating Officer since January 2021 and served as Senior Vice President of Operations since March 2020. Mr. Muñoz joined the Company in 2010 to initiate ProPetro’s Permian pressure pumping operation. Prior to joining ProPetro, Mr. Muñoz held sales and operations roles at Frac Tech Services and Weatherford International. Since joining ProPetro, Mr. Muñoz has served as the Director of Business Development and Technical Services where he was responsible for overseeing the growth of the hydraulic fracturing operations as well as managing the department’s day-to-day technical services. Mr. Muñoz has most recently served as the Vice President of Frac Services where his duties included leading the hydraulic fracturing division through specific efforts to increase operational efficiencies and maximize financial productivity. Mr. Muñoz received a Bachelor of Business Marketing from The University of Texas at the Permian Basin.

John J. “Jody” Mitchell, 42, has served as our General Counsel and Corporate Secretary of the Company since January 2023. Prior to his appointment as General Counsel, Mr. Mitchell served as the Company’s Vice President and Deputy General Counsel since April 2021. Before joining the Company, Mr. Mitchell served in various roles at Concho Resources Inc., a hydrocarbon exploration company acquired by ConocoPhillips in 2021 (“Concho”), from 2014 to 2021, including Director of Marketing and Midstream and, prior to that, Associate General Counsel. Before joining Concho, Mr. Mitchell served as counsel supporting the upstream and midstream businesses at Petrohawk Energy Corporation (“Petrohawk”) and at BHP Billiton following BHP Billiton’s acquisition of Petrohawk. Mr. Mitchell began his career as an associate at Locke Lord Bissell & Liddell LLP, where he concentrated on oil, gas and energy litigation and construction litigation. Mr. Mitchell holds a Bachelor of Arts from the University of Texas and a Juris Doctor from the University of Houston Law Center.

Shelby K. Fietz, 43, has served as our Chief Commercial Officer of the Company since November 2023. Mr. Fietz joined ProPetro in 2012, and prior to his appointment as Chief Commercial Officer, Mr. Fietz served as the Company’s Vice President of Commercial, leading the business development, sales, supply chain, and marketing functions. He also previously held the position of Vice President of Business Development, Sales and Marketing, while also leading our supply chain organization. Prior to his appointment as an officer, Mr. Fietz held roles of increasing responsibility within ProPetro in both operations and business development. Mr. Fietz also serves in a leadership capacity with the Permian Basin Chapter of the Energy Workforce and Technology Council. Mr. Fietz holds a Bachelor of Science from Angelo State University.

Celina M. Davila, 44, has served as our Chief Accounting Officer since November 2023. Prior to her appointment as Chief Accounting Officer, Ms. Davila served as the Company’s Director of Accounting and Corporate Controller since August 2022 and as Corporate Controller since October 2019. Ms. Davila joined the Company in January 2019 as Hydraulic Fracturing Controller. Prior to joining the Company, Ms. Davila served in various roles at Pioneer, a leading independent natural resources company, from 2012 to 2018, including Accounting Manager and, prior to that, Accounting Supervisor. Ms. Davila began her career as a Senior Auditor at Johnson, Miller, and Co. Ms. Davila is a Certified Public Accountant and holds a Bachelor of Arts in Accounting and a Master in Business Administration degree from Texas Tech University.

Item 1A. Risk Factors.

The following is a description of significant factors that could cause actual results to differ materially from those contained in forward-looking statements made in this Annual Report and presented elsewhere by management from time to time. Such factors may have a material adverse effect on our business, financial condition and results of operations. It is not possible to predict or identify all such factors. Consequently, you should not consider any such list to be a complete statement of all our potential risks or uncertainties. Due to these, and other factors, past performance should not be considered an indication of future performance.

Risks Inherent in Our Business and Industry

Our business and financial performance depends on the historically cyclical oil and natural gas industry and particularly on the level of capital spending and E&P activity within the United States and in the Permian Basin, and a decline in prices for oil and natural gas may cause fluctuation in operating results or otherwise have an adverse effect on our revenue, cash flows, profitability and growth.

Demand for most of our services depends substantially on the level of capital expenditures in the Permian Basin by companies in the oil and natural gas industry. AsActivity ~~a result, our operations are dependent on the~~ levels ofand ~~capital~~ spending ~~and~~by ~~activity~~our incustomers ~~oil~~ and, ~~gas exploration~~correspondingly, ~~development~~demand ~~and production. Demand~~ for our services, is largely dependent on oil and natural gas prices, ~~and~~ our customers’ well completion budgets and rig count. Prolonged low oil and natural gas prices would generally depress the level of oil and natural gas exploration, development, production, and well completion activity and would result in a corresponding decline in the demand for the completion services that we provide. Historically, oil prices and markets have been extremely volatile. Prices are affected by many factors beyond our control. The average WTI oil price per barrel was approximately $7665, $7876 and $9478 for the years ended December 31, ~~2024~~2025, ~~2023~~2024, and ~~2022~~2023, respectively. In ~~2023~~2025, ~~the~~price volatility continued and ~~overall~~crude ~~decline in~~ oil ~~and~~prices ~~natural~~generally ~~gas~~declined, ~~prices~~contributing ~~caused~~to areductions ~~reduction~~ in our customers’ spending and associated drilling and completion activities, which has had and may continue to have an adverse effect on our revenue and cash flows, if the WTI oil price remains highly volatile or declines further in the future. Such trends are expected to continue in 2026. In addition, such volatility and reduction in our customers’ spending and associated drilling and completion activities could also reduce the prices we receive for our services and impact the number of fleets that we are able to deploy, which would also have an adverse effect on our revenue and cash flows. See “The cyclical nature of the oil and natural gas industry may cause our operating results to fluctuate.”

Many factors over which we have no control affect the supply of, and demand for our services, and our customers’ willingness to explore, develop and produce oil and natural gas, and therefore, influence prices for our services, including:

•the actions by the members of OPEC+ with respect to oil production levels and announcements of potential changes in such levels, including the ability of the OPEC+ countries to agree on and comply with supply limitations;

•the domestic and foreign supply of, and demand for, oil and natural gas;

•the level of prices, and expectations about future prices, of oil and natural gas, including a potential increase in Venezuelan oil supply and any related impact on global oil prices and domestic oil production;

•the level of global oil and natural gas E&P;

•the cost of exploring for, developing, producing and delivering oil and natural gas;

•the supply of and demand for drilling and hydraulic fracturing and wireline equipment, including the supply and demand for lower emissions hydraulic fracturing and wireline equipment;

•cost increases and supply chain constraints related to our services;

•the expected decline in rates of current production;

•the price and quantity of foreign imports;

•political and economic conditions in oil and natural gas producing countries and regions, including the United States, the Middle East, Africa, South America and Russia;

•the actions taken by the United States and other countries on climate change or to transition away from fossil fuels;

•the severity and duration of world health events and related economic repercussions;

•speculative trading in crude oil and natural gas derivative contracts;

•the level of consumer product demand;

•the discovery rates of new oil and natural gas reserves;

•contractions in the credit market;

•the strength or weakness of the U.S. dollar;

•available pipeline and other transportation capacity;

•the levels of oil and natural gas storage;

•weather conditions and other natural disasters;

•domestic and foreign tax policy;

•domestic and foreign governmental approvals and regulatory requirements and conditions, including tighter emissions standards in the energy industry and proposed or existing tariffs;

•the result of the U.S presidential election;

•the continued threat of terrorism and the impact of military and other action, including military action in the Middle East;

•political or civil unrest in the United States or elsewhere, including the Russia-Ukraine war and the conflict in the Israel-Gaza region and related instability in the Middle East, including ~~from~~tensions ~~Houthi~~with ~~rebels in Yemen~~Iran, and ~~tensions~~U.S. ~~with~~intervention ~~Iran~~in Venezuela;

•technical advances affecting energy consumption, including resulting from artificial intelligence (“AI”);

•the proximity and capacity of oil and natural gas pipelines and other transportation facilities;

•the price and availability of alternative fuels;

•the ability of oil and natural gas producers to raise equity capital and debt financing;

•merger and divestiture activity among oil and natural gas producers; and

•overall domestic and global economic conditions.

These factors and the volatility of the energy markets make it extremely difficult to predict future oil and natural gas price movements with any certainty. In 2022, Russia launched a large-scale invasion of Ukraine, leading to armed hostilities and imposition of sanctions on Russian economic trades. Since October 2023, an ongoing conflict between Israel and Palestinian militants in the Israel-Gaza region has led to armed hostilities. These events, which have impacted economic activity and disrupted global supply chain dynamics, have contributed to the unpredictable nature of crude oil prices.

The cyclical nature of the oil and natural gas industry may cause our operating results to fluctuate.

We derive substantially all of our revenues from companies in the oil and natural gas E&P industry, a historically cyclical industry with levels of activity that are significantly affected by the levels and volatility of oil and natural gas prices. We have experienced, and may in the future experience, significant fluctuations in operating results as a result of the reactions of our customers to changes in oil and natural gas prices. For example, aduring ~~decline~~2025 inand ~~oil~~into early 2026, price volatility has continued and ~~gas~~crude oil prices, ~~combined~~have ~~with~~generally ~~adverse~~declined. ~~changes~~If insuch ~~the~~prices ~~capital~~do ~~and~~not ~~credit~~improve ~~markets,~~or ~~could~~decline ~~cause~~further, ~~many~~ E&P companies tomay ~~significantly~~ reduce their ~~2020 and 2021~~ capital budgets and drilling activity. This could result in a significant decline in demand for energy services and could adversely impact the prices ~~energy~~we ~~service companies~~ can charge for ~~their~~our services and impact the number of fleets that we are able to deploy. These factors have in the past materially and adversely affected our business, results of operations and financial condition and may do so in the future. In addition, a ~~majority~~material portion of the service revenue we earn is based upon a charge for a relatively short period of time (for example, a day, a week or a month) for the actual period of time ~~the~~our service is provided to our customers. ByAcross ~~contracting~~our ~~services~~businesses, onwe aconsider ~~short‑~~contracts with term ~~basis,~~length weof ~~are~~twelve ~~exposed~~months or more to ~~the~~be ~~risks~~long-term ofcontracts. aWe ~~rapid~~occasionally ~~reduction~~obtain inlonger-term ~~market~~contractual ~~prices~~arrangements ~~and~~for ~~utilization~~certain ~~and~~of ~~resulting~~our ~~volatility~~hydraulic infracturing services and our ~~revenues~~PROPWRSM business line typically contracts for services on a long-term basis.

1615

Many of our power generation services involve long sales cycles.

The sales cycle for our power generation services, from initial contact with potential customers to the commencement of field deployment, may be lengthy. Customers generally consider a wide range of solutions before making a decision to contract for power generation services. Before a customer commits to a contract for power generation services, it often requires a significant technical review, assessment of competitive offerings and approval at a number of management levels within its organization. During the time our customers are evaluating our offerings, we may incur substantial sales and marketing, engineering and research and development expenses, which we may ultimately be unable to offset with recognized profits.

Our PROPWRSM business line exposes us to the significant risks and uncertainties associated with establishment of a new line of business, and such business line may not achieve the results we anticipate.

The mobile power business is developing and evolving rapidly, and we and others are seeking to procure equipment and enter into contracts with customers for the deployment of such equipment. Procurement of mobile power equipment requires that we make long lead-time commitments to purchase such equipment from the manufacturer and a corresponding increased capital expenditure commitment. Customer demand for our power equipment may be lower than we project, which could result in an inability or delay in deploying equipment, less growth in such business than we are projecting and reduced financial returns from such business. In addition, changes in customer demand or an excess supply of mobile power equipment could result in a supply and demand imbalance that depresses prices.

There are limited manufacturers of mobile power equipment, and we may experience delays or difficulties in procuring the specialized equipment required to support this business line. Such delays or difficulties in procuring equipment could be caused by increasing demand and orders by our competitors and limitations on the manufacturers’ ability to timely deliver such equipment. In addition, such equipment requires the expenditure of significant capital, much of which we have in the past and will in the future obtain through debt or other financing structures. Such financing may not be available at all or on attractive terms. In addition, financing the procurement of such equipment exposes us to the risks associated with greater financial leverage on our business. See “—Our indebtedness and liquidity needs could restrict our operations and adversely affect our financial condition.”

In addition, market prices for the products or services offered in this new business line may decline due to competitive pressures, technological changes or other factors, any of which would reduce our projected growth in the power business and our financial returns. The mobile power equipment we acquire could fail to meet customer expectations or become obsolete due to competition, such as from the installation of utility power, changing customer preferences or the introduction of new technologies. Additionally, our PROPWRSM business could fail to meet operational requirements in contracts with customers in the field. The failure of our PROPWRSM business to become established and grow as we are projecting for any of the foregoing reasons, or for reasons we cannot currently anticipate, could materially and adversely affect our financial condition and results of operations.

The majority of our operations are located in the Permian Basin, making us vulnerable to risks associated with operating in one major geographic area.

Our operations are geographically concentrated in the Permian Basin. For the years ended December 31, ~~2024~~2025, ~~2023~~2024 and ~~2022~~2023, approximately 98100.50%, 98.15% and 98.31%, respectively, of our revenues were attributable to our operations in the Permian Basin. As a result of this concentration, we may be disproportionately exposed to the impact of regional supply and demand factors, delays or interruptions of production from or drilling and completions activity with respect to wells in the Permian Basin caused by weather, significant governmental regulation, processing or transportation capacity constraints, market limitations, curtailment of production or interruption of the processing or transportation of oil and natural gas produced from the wells in these areas. For example, winter weather conditions in January 2026 across the Permian Basin have resulted in a multi-day suspension of substantially all of our operations, which may negatively impact our results of operations in the first quarter of 2026. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic oil and natural gas producing areas such as the Permian Basin, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions. Due to the concentrated nature of our operations, we could experience any of the same conditions at the same time, resulting in a relatively greater impact on our revenue than they might have on other companies that have more geographically diverse operations.

The IRA 2022 could accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations.

The IRA 2022, signed into law in August 2022, provides for hundreds of billions of dollars in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles and supporting infrastructure and carbon capture and sequestration, amongst other provisions. If not modified, repealed or revoked by the current administration, these incentives could further accelerate the transition of the economy away from the use of fossil fuels towards lower- or zero-carbon emissions alternatives, which could decrease demand for oil and gas and consequently adversely affect the business of our customers, thereby reducing demand for our services. In addition, the IRA 2022 imposes the first ever federal fee on the emission of GHG through a methane emissions charge. The IRA 2022 amends the federal CAA to impose a fee on the emission of methane from sources required to report their GHG emissions to the EPA, including those sources in the offshore and onshore petroleum and natural gas production and gathering and boosting source categories. The methane emissions charge began in calendar year 2024 at $900 per ton of methane, increased to $1,200 in 2025, and will be set at $1,500 for 2026 and each year after. Calculation of the fee is based on certain thresholds established in the IRA 2022. We cannot predict whether how or when the current administration might take action to revise or repeal the methane emissions charge. Additionally, Congress may take actions to repeal or revise the IRA 2022, including with respect to the methane emissions charge, which timing or outcome similarly cannot be predicted. To the extent that the methane emissions charge is implemented as originally promulgated, it could increase our customers’ operating costs and adversely affect their businesses, thereby reducing demand for our services.

Our business may be adversely affected by a deterioration in general economic conditions or a weakening of the broader energy industry.

A prolonged economic slowdown or recession in the United States, adverse events relating to the energy industry or regional, national and global economic conditions and factors, particularly a slowdown in the E&P industry, could negatively impact our operations and therefore adversely affect our results. The risks associated with our business are more acute during periods of economic slowdown or recession because such periods may be accompanied by decreased exploration and development spending by our customers, decreased demand for oil and natural gas and decreased prices for oil and natural gas. For example, decreases in prices of oil and natural gas and/or our customers’ spending and activity levels could reduce the prices we receive for our services and impact the number of fleets that we are able to deploy, which would have an adverse effect on our revenue, cash flows, profitability and growth.

New technology may cause us to become less competitive.

The energy service industry is subject to the introduction of new drilling and completion techniques and services using new technologies, including ~~artificial intelligence~~AI, some of which may be subject to patent or other intellectual property protections. As competitors and others use or develop new or comparable technologies in the future, we may lose market share or be placed at a competitive disadvantage. For example, many E&P companies, including our customers, are transitioning to a lower emissions operating environment and may require us to invest in equipment with lower emissions profiles. The transition to lower emissions equipment is capital intensive and could require us to convert all our conventional Tier II equipment to lower emissions equipment. If we are unable to quickly transition to lower emissions equipment, the demand for our services could be adversely impacted. ~~For example, many E&P companies, including our customers, are transitioning to a lower emissions operating environment and may require us to invest in equipment with lower emissions profiles.~~ Further, we may face competitive pressure to further develop, implement or acquire and deploy certain technology improvements at a substantial cost, such as ~~our~~additional FORCE® electric-powered hydraulic fracturing fleets. ~~deployed~~The ~~in 2023, or the~~ cost of ~~implementing~~deploying oradditional ~~purchasing a technology like~~ FORCE® fleets may be substantially higher than anticipated, and we may not be able to successfully implement the technologies ~~we may purchase~~. In fiscal year 2024, we recorded a property and equipment impairment charge of $188.6 million on our conventional Tier II diesel-only hydraulic fracturing ~~pumping~~pumps ~~units~~ and associated conventional assets, (~~the "~~“Tier II Units"”) because we determined that the marketability of our Tier II Units had declined due to decreasing customer demand for and related pricing pressures on such equipment, among other factors. InSome ~~2022~~of our competitors have greater financial, wetechnical ~~recorded~~and personnel resources that may allow them to enjoy technological advantages and develop and implement new products on a ~~property~~timely basis or at an acceptable cost. We cannot be certain that we will be able to develop and ~~equipment~~implement ~~impairment~~new ~~charge~~technologies ofor ~~$57~~products on a timely basis or at an acceptable cost.5 ~~million~~Limits on our ~~DuraStim®~~ability ~~electric-powered~~to ~~equipment~~develop, ~~because~~effectively ~~they~~use ~~did~~and implement new and emerging technologies could have a material adverse effect on our business, financial condition, prospects or results of operations.

Our operations require substantial capital, and we may be unable to obtain needed capital or financing on satisfactory terms, or at all, which could limit our ability to grow.

The energy service industry is capital intensive. In conducting our business and operations, we have made, and expect to continue to make, substantial capital expenditures, including capital expenditures to maintain our fleet and costs related to purchase options under certain leases. Our total capital expenditures incurred were approximately $281.2 million, $133.4 million and $310.0 million during the years ended December 31, 2025, 2024, and 2023. Moreover, our PROPWRSM business has required us to make substantial capital expenditures for new power generation units, and these expenditures are expected to increase as we order and deploy additional units, among other business related expenditures. During the year ended December 31, 2025, we incurred approximately $198.4 million of capital expenditures for our PROPWRSM business. We have historically financed capital expenditures primarily with funding from cash on hand, cash flow from operations, equipment and vendor financing and borrowings under our credit facility. Approximately $81.1 million of our PROPWRSM capital expenditures incurred in fiscal year 2025 were financed through vendor financing. We may be unable to generate sufficient cash from operations and other capital resources to maintain planned or future levels of capital expenditures which, among other things, may prevent us from acquiring new equipment (including power generation equipment or hydraulic fracturing equipment with a lower emissions profile) or properly maintaining our existing equipment. Any disruptions or volatility in the global financial markets may lead to an increase in interest rates or a contraction in credit availability impacting our ability to finance our operations. Our Borrowing Base (as defined below) was $167.7 million as of December 31, 2025. If our customer activity levels decline in the future resulting in a decrease in our eligible accounts receivable, our Borrowing Base could decline. This could put us at a competitive disadvantage or interfere with our growth plans. Further, our actual capital expenditures incurred could exceed our capital expenditure budget. In the event our capital expenditure requirements at any time are greater than the amount of liquidity we have available, we could be required to seek additional sources of capital, which may include debt financing, joint venture partnerships, sales of assets, offerings of debt or equity securities or other means. We may not be able to obtain any such alternative source of capital. We may be required to curtail or eliminate contemplated activities. If we can obtain alternative sources of capital, the terms of such alternative may not be favorable to us. In particular, the terms of any debt financing may include covenants that significantly restrict our operations. Our inability to grow as planned may reduce our chances of maintaining and improving profitability.

not meet our expectations. Some of our competitors have greater financial, technical and personnel resources that may allow them to enjoy technological advantages and develop and implement new products on a timely basis or at an acceptable cost. We cannot be certain that we will be able to develop and implement new technologies or products on a timely basis or at an acceptable cost. Limits on our ability to develop, effectively use and implement new and emerging technologies could have a material adverse effect on our business, financial condition, prospects or results of operations.

Our operations require substantial capital and we may be unable to obtain needed capital or financing on satisfactory terms, or at all, which could limit our ability to grow.

The energy service industry is capital intensive. In conducting our business and operations, we have made, and expect to continue to make, substantial capital expenditures. Our total capital expenditures incurred were approximately $133.4 million, $310.0 million and $365.3 million during the years ended December 31, 2024, 2023, and 2022. We have historically financed capital expenditures primarily with funding from cash on hand, cash flow from operations, equipment and vendor financing and borrowings under our credit facility. We may be unable to generate sufficient cash from operations and other capital resources to maintain planned or future levels of capital expenditures which, among other things, may prevent us from acquiring new equipment (including equipment with a lower emissions profile) or properly maintaining our existing equipment. Any disruptions or volatility in the global financial markets may lead to an increase in interest rates or a contraction in credit availability impacting our ability to finance our operations. Our Borrowing Base (as defined below) was $164.1 million as of December 31, 2024. If our customer activity levels decline in the future resulting in a decrease in our eligible accounts receivable, our Borrowing Base could decline. This could put us at a competitive disadvantage or interfere with our growth plans. Further, our actual capital expenditures could exceed our capital expenditure budget. In the event our capital expenditure requirements at any time are greater than the amount of liquidity we have available, we could be required to seek additional sources of capital, which may include debt financing, joint venture partnerships, sales of assets, offerings of debt or equity securities or other means. We may not be able to obtain any such alternative source of capital. We may be required to curtail or eliminate contemplated activities. If we can obtain alternative sources of capital, the terms of such alternative may not be favorable to us. In particular, the terms of any debt financing may include covenants that significantly restrict our operations. Our inability to grow as planned may reduce our chances of maintaining and improving profitability.

Concerns over general economic, business or industry conditions may have a material adverse effect on our results of operations, liquidity and financial condition.

Concerns over global economic conditions, geopolitical issues (including the Russia-Ukraine war and conflicts in the Middle East, including tensions with Iran), public health crises, interest rates, inflation, the availability and cost of credit in the United States, foreign financial markets and potential changes in U.S. trade policy, including the imposition of tariffs and the resulting consequences, have contributed to increased economic uncertainty and diminished expectations for the global economy. These factors, combined with volatility in commodity prices, business and consumer confidence and unemployment rates, could precipitate an economic slowdown. Concerns about global economic growth have had a significant adverse impact on global financial markets and commodity prices. In addition, there is currently significant uncertainty about the future relationship between the United States and various other countries, including changes arising as a result of the current presidential administration, with respect to trade policies, treaties, tariffs, taxes, and other limitations on cross-border operations. The historically unpredictable nature of oil and natural gas prices, and particularly the volatility over the past two years have caused a reduction in our customers’ spending and associated drilling and completion activities, which had and may continue to have an adverse effect on our revenue and cash flows. For example, decreases in commodity prices and/or our customers’ spending and activity levels could reduce the prices we receive for our services and impact the number of fleets that we are able to deploy, which would have an adverse effect on our revenue, cash flows, profitability and growth. If the economic climate in the United States or abroad deteriorates or remains uncertain, worldwide demand for petroleum products could diminish, which could impact the price at which oil, natural gas and natural gas liquids can be sold, which could affect the ability of our customers to continue operations and adversely impact our results of operations, liquidity and financial condition.

Changes in U.S. trade policy and the impact of tariffs and other trade measures may have a material adverse effect on our business and results of operations.

Our business and results of operations may be adversely affected by uncertainty and changes in U.S. trade policies, including tariffs, trade agreements or other trade restrictions imposed by the United States or other governments. For example, on March 12, 2025, the U.S. government imposed a 25% tariff on steel imports, and on April 2, 2025, the U.S. government announced a 10% tariff on product imports from almost all foreign countries and individualized higher tariffs on certain other countries. Additionally, tariffs have been placed on the import of certain materials. Several tariff announcements have been followed by announcements of limited exemptions and temporary pauses. These actions are unprecedented, have caused substantial uncertainty and volatility in financial markets and may result in retaliatory measures on U.S. goods.

Any imposition of or increase in tariffs on imports of steel or other materials, as well as corresponding price increases for such materials available domestically, could increase our material input costs and our costs to maintain our assets. It remains unclear to what extent, upon which countries, and upon which terms, tariffs may be levied. There also remains uncertainty regarding the full scope of tariffs, if the tariffs will be increased, decreased or eliminated altogether. To the extent that we are unable to pass all or any such cost increases on to our customers, such cost increases could adversely affect our returns on investment.

The imposition of further tariffs by the United States on a broader range of imports, or further retaliatory trade measures taken in response to additional tariffs or uncertainty regarding such potential impacts, could increase costs in our supply chain or reduce demand for our customers’ products, either of which could adversely affect our results of operations. The ultimate impact of these trade measures on our business operations and financial results is uncertain and may be affected by various factors, including whether and when such trade measures are implemented, the timing when such measures may become effective, the amount, scope, or nature of such trade measures, and our ability to execute strategies to mitigate any negative impacts.

Our indebtedness and liquidity needs could restrict our operations and adversely affect our financial condition.

Our business is capital intensive and ~~our~~we ~~existing~~are employing debt and ~~future~~other ~~indebtedness,~~financing ~~whether~~arrangements ~~incurred~~to infund ~~connection~~many ~~with~~of ~~acquisitions~~our capital expenditures, ~~operations~~particularly orthose ~~otherwise,~~associated ~~may~~with ~~adversely~~the ~~affect~~expansion of our ~~operations~~PROPWRSM business and ~~limit~~the acquisition and deployment of our ~~growth~~FORCE® electric fleets. For example, we are a party to the Caterpillar Equipment Loan Agreement (as defined below), and we ~~may~~entered ~~have~~into ~~difficulty~~an ~~making~~Interim ~~debt~~Funding ~~service~~Agreement ~~payments~~and onMaster ~~such~~Lease ~~indebtedness~~Agreement as(together, ~~payments~~the ~~become~~“Stonebriar ~~due~~Equipment Lease Facility”) with Stonebriar Commercial Finance LLC (“Stonebriar”) for the right, but not the obligation, to fund up to $350.0 ~~Our~~million ~~level~~of purchases of ~~indebtedness~~power ~~may~~generator ~~affect~~equipment and entered into an amendment to our ~~operations~~revolving incredit ~~several~~facility ~~ways~~(as amended, ~~including~~the “ABL Credit Facility”) to increase the ~~following:~~debt basket for capital leases, purchase money debt and other similar financing facilities to $425.0 million. We expect the Caterpillar Equipment Loan Agreement, the Stonebriar Equipment Lease Facility, and the ABL Credit Facility to provide us with additional access to capital, if needed, to facilitate the growth of our PROPWRSM business line.

• increasing our vulnerability to general adverse economic and industry conditions;

• the covenants that are contained in the agreements governing our indebtedness could limit our ability to borrow funds, dispose of assets, pay dividends and make certain investments;

~~• our~~Our ~~debt~~existing ~~covenants~~and ~~could~~future ~~also~~indebtedness, whether incurred to fund such capital expenditures or to fund acquisitions, operations or otherwise, may adversely affect our ~~flexibility~~operations inand ~~planning~~limit ~~for~~our growth, and ~~reacting~~we ~~to,~~may ~~changes~~have indifficulty ~~the~~making ~~economy~~debt ~~and~~service inpayments on such indebtedness as payments become due. Our level of indebtedness may affect our ~~industry;~~operations in several ways, including the following:

• ~~any~~increasing ~~failure~~our tovulnerability ~~comply with the financial or other debt covenants, including covenants that impose requirements~~ to ~~maintain~~general ~~certain~~adverse ~~financial~~economic ~~ratios, could result in an event of default, which could result in some or all of our indebtedness becoming immediately due~~ and ~~payable~~industry conditions;

• ~~our~~the ~~level~~covenants ofthat ~~debt~~are ~~could~~contained ~~impair~~in ~~our~~the ~~ability~~agreements togoverning ~~obtain~~our ~~additional~~indebtedness ~~financing,~~could orlimit ~~obtain~~our ~~additional~~ability ~~financing~~to onborrow ~~favorable~~funds, ~~terms~~dispose inof ~~the future for working capital~~assets, ~~capital~~pay ~~expenditures,~~dividends ~~research~~ and ~~development~~make ~~efforts,~~certain ~~potential strategic acquisitions or other general corporate purposes~~investments;

•our debt covenants could also affect our flexibility in planning for, and reacting to, changes in the economy and in our industry;

•any failure to comply with the financial or other debt covenants, including covenants that impose requirements to maintain certain financial ratios, could result in an event of default, which could result in some or all of our indebtedness becoming immediately due and payable;

•our level of debt could impair our ability to obtain additional financing, or obtain additional financing on favorable terms in the future for working capital, capital expenditures, research and development efforts, potential strategic acquisitions or other general corporate purposes;

•placing us at a competitive disadvantage relative to competitors that have less debt; and

• our business may not generate sufficient cash flow from operations to enable us to meet our obligations under our indebtedness.

Furthermore, interest rates on future indebtedness could be higher than current levels, causing our financing costs to increase accordingly. Changes in interest rates, either positive or negative, may affect the yield requirements of investors who invest in our shares, and a rising interest rate environment could have an adverse impact on the price of our shares, and our ability to issue equity or incur debt.

Restrictions in our ABL Credit Facility, our Caterpillar Equipment Loan Agreement, our Stonebriar Equipment Lease Facility, and any future financing agreements may limit our ability to finance future operations or capital needs or capitalize on potential acquisitions and other business opportunities.

The operating and financial restrictions and covenants in our credit facility, Caterpillar Equipment Loan Agreement, Stonebriar Equipment Lease Facility and any future financing agreements could restrict our ability to finance future operations or capital needs or to expand or pursue our business activities. For example, our ABL Credit Facility restricts or limits our ability to:

•grant liens;

•incur additional indebtedness;

•engage in a merger, consolidation or dissolution;

•enter into transactions with affiliates;

•sell or otherwise dispose of assets, businesses and operations;

•materially alter the character of our business as currently conducted; and

•make acquisitions, investments and capital expenditures.

Furthermore, our ABL Credit Facility contains certain other operating and financial covenants. Our ability to comply with the covenants and restrictions contained in the ABL Credit Facility may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. If we violate any of the restrictions, covenants, ratios or tests in our ABL Credit Facility, a significant portion of our indebtedness may become immediately due and payable and our lenders’ commitment to make further loans to us may terminate. Further, our borrowing base, as redetermined monthly, has a borrowing base of the sum of 85.0% to 90.0% of eligible accounts receivable and 80% of eligible unbilled accounts (up to a maximum of 25% of the borrowing base), in each case, depending on the credit ratings of our accounts receivable counterparties, less customary reserves (the “Borrowing Base”). Changes to our operational activity levels or customer concentration levels have an impact on our total eligible accounts receivable, which could result in significant changes to our borrowing base and therefore our availability under our ABL Credit Facility. If our customer activity declines in the future, our borrowing base could decline. If our borrowing base is reduced below the amount of our outstanding borrowings, we will be required to repay the excess borrowings immediately on demand by the lenders. We might not have, or be able to obtain, sufficient funds to make these accelerated payments. Any subsequent replacement of our ABL Credit Facility or any new indebtedness could have similar or greater restrictions. Please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital Resources — Credit Facility and Other Financing Arrangements.”

We may record losses or impairment charges related to goodwill and long-lived assets including intangible assets.

~~Changes~~borrowing base), in ~~future~~each ~~market conditions and prolonged periods of low utilization~~case, ~~changes~~depending inon ~~technology or~~ the ~~sale~~credit ratings of ~~assets~~our ~~below~~accounts ~~their~~receivable ~~carrying~~counterparties ~~value~~and ~~may~~subject ~~cause us~~ to ~~experience~~certain ~~losses~~customer inconcentration ~~our~~limits, ~~results~~less ofcustomary ~~operations.~~reserves ~~These~~(the ~~events~~“Borrowing ~~could~~Base”). ~~result~~Changes into ~~the~~our ~~recognition~~operational ofactivity ~~impairment~~levels ~~charges~~ or ~~losses~~customer ~~from~~concentration ~~asset~~levels ~~sales~~have ~~that~~an ~~negatively~~ impact on our ~~financial~~total ~~results.~~eligible ~~Significant~~accounts ~~impairment~~receivable, ~~charges~~which orcould ~~losses from asset sales as a~~ result ~~of a decline~~ in ~~market~~significant ~~conditions~~changes orto ~~otherwise~~our ~~could~~borrowing ~~have~~base aand ~~material~~therefore ~~adverse~~our ~~effect~~availability onunder our ~~results~~ABL ofCredit ~~operations~~Facility. inIf ~~future~~our ~~periods.~~customer ~~For~~activity ~~example,~~declines in ~~2024~~the future, weour ~~recorded~~borrowing ~~property~~base ~~and~~could ~~equipment impairment charges of $188~~decline.6 ~~million~~If ~~in connection with~~ our ~~Tier~~borrowing IIbase ~~Units~~is ~~and~~reduced ~~$23.6~~below ~~million in connection with~~ the ~~goodwill~~amount inof our ~~wireline~~outstanding ~~operating segment. In 2022~~borrowings, we ~~recorded~~will ~~property~~be ~~and~~required ~~equipment~~to ~~impairment~~repay ~~charges~~the ofexcess ~~$57.5~~borrowings ~~million~~immediately inon ~~connection~~demand ~~with~~by ~~our~~the ~~DuraStim® electric powered hydraulic fracturing equipment~~lenders. IfWe ~~oil~~might ~~and~~not ~~natural~~have, ~~gas~~or ~~prices~~be ~~trade~~able atto ~~depressed price levels~~obtain, ~~and~~sufficient ~~our~~funds ~~equipment~~to ~~remains~~make ~~idle~~these oraccelerated ~~under-utilized,~~payments. ~~the~~Any ~~estimated~~subsequent ~~fair~~replacement ~~value~~ of ~~such~~our ~~equipment~~ABL ~~may~~Credit ~~decline,~~Facility ~~which~~or ~~will~~any ~~result~~new inindebtedness ~~additional~~could ~~impairment~~have ~~expense~~similar inor ~~the~~greater ~~future~~restrictions.

Our ~~operations~~Master ~~are~~Loan ~~subject~~and Security Agreement and our First Amendment to ~~unforeseen~~Master ~~interruptions~~Loan and ~~hazards~~Security ~~inherent~~Agreement inwith Caterpillar Financial Services Corporation (collectively, the ~~oil~~“Caterpillar Equipment Loan Agreement”) also contains certain operating and ~~natural~~financial ~~gas~~covenants. Our ability to comply with such covenants may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, ~~for~~our ~~which~~ability to comply with these covenants may be impaired. If we violate any of the restrictions or covenants in our Caterpillar Equipment Loan Agreement, a significant portion of our indebtedness may become immediately due and payable, our lender’s commitments to make further loans to us may terminate, and our lender will be able to foreclose on the equipment that was financed through the Caterpillar Equipment Loan Agreement. We might not have, or be ~~adequately~~able ~~insured~~to ~~and~~obtain, ~~which~~sufficient funds to make these accelerated payments. Any subsequent replacement of the Caterpillar Equipment Loan Agreement or any new financing agreements could ~~cause~~have ussimilar or greater restrictions. The Stonebriar Equipment Lease Facility contains restrictions similar to ~~lose~~those ~~customers~~set forth in the Caterpillar Equipment Loan Agreement, and ~~substantial~~if ~~revenue~~we violate those restrictions, Stonebriar would be entitled to accelerate required lease payments and obtain control over the lease equipment, among other remedies.

~~Our~~We ~~operations~~may ~~are~~record ~~exposed~~losses ~~to the risks inherent to our industry, such as equipment defects, vehicle accidents, worksite injuries to our~~ or ~~third-party~~impairment ~~personnel,~~charges ~~fires,~~related explosions, blowouts, surface cratering, uncontrollable flows of gas or well fluids, pipe or pipeline failures, abnormally pressured formations and various environmental hazards, such as oil spills and releases of, and exposure to, ~~hazardous~~goodwill substances. For example, our operations are subject to risks associated with hydraulic fracturing, including any mishandling, surface spillage or potential underground migration of fracturing fluids, including hydrochloric acid and ~~other~~long-lived ~~chemical~~assets ~~additives. In addition, our operations are exposed to potential natural disasters,~~ including ~~blizzards,~~intangible ~~tornadoes, storms, floods, other adverse weather conditions and earthquakes~~assets. The occurrence of any of these events could result in substantial losses to us due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigations and penalties or other damage resulting in curtailment or suspension of our operations or the loss of customers. For example, in January 2025, we experienced an accident at a customer site that resulted in one fatality and injured two others, which temporarily halted operations and is subject to routine investigation by OSHA. The cost of managing such risks may be significant. The frequency and severity of such incidents will affect operating costs, insurability and relationships with customers, employees and regulators. In particular, our customers may elect not to purchase our services if they view our environmental or safety record as unacceptable, which could cause us to lose customers and substantial revenues.

~~Our~~Changes ~~insurance~~in ~~may~~future ~~not~~market beconditions ~~adequate~~and toprolonged ~~cover~~periods ~~all~~of ~~losses~~low orutilization, ~~liabilities~~changes wein ~~may~~technology ~~suffer.~~or Wethe ~~are~~sale ~~also~~of ~~self-insured~~assets upbelow totheir ~~$10 million~~carrying ~~per~~value ~~occurrence~~may ~~for~~cause ~~certain~~us ~~losses~~to ~~arising~~experience ~~from~~losses orin ~~attributable~~our toresults ~~fire~~of ~~and/or~~operations. ~~explosion~~These atevents ~~wellsites~~could ~~that~~result doin ~~not~~the ~~have~~recognition ~~qualified~~of ~~fire~~impairment ~~suppression~~charges ~~measures.~~or ~~Furthermore,~~losses wefrom ~~may~~asset besales ~~unable~~that tonegatively ~~maintain~~impact orour ~~obtain~~financial ~~insurance~~results. ofSignificant ~~the~~impairment ~~type~~charges ~~and~~or ~~amount~~losses wefrom ~~desire~~asset atsales ~~reasonable~~as ~~rates. As~~ a result of ~~market~~a ~~conditions,~~decline ~~premiums~~in ~~and~~market ~~deductibles~~conditions ~~for~~or ~~certain~~otherwise ofcould ~~our insurance policies~~ have ~~increased~~a ~~and~~material ~~could~~adverse ~~escalate~~effect ~~further.~~on Inour ~~addition,~~results ~~sub‑limits~~of ~~have~~operations ~~been~~in ~~imposed~~future ~~for certain risks~~periods. InFor ~~some instances~~example, ~~certain~~in ~~insurance~~fiscal ~~could~~year ~~become~~2024, ~~unavailable~~we orrecorded ~~available~~property ~~only~~and ~~for~~equipment ~~reduced~~impairment ~~amounts~~charges of ~~coverage~~$188.6 Ifmillion wein ~~were~~connection towith ~~incur~~our aTier ~~significant~~II ~~liability~~Units ~~for~~and ~~which~~$23.6 wemillion ~~are~~in ~~not~~connection ~~fully~~with ~~insured,~~the itgoodwill ~~could~~in ~~have~~our aWireline ~~material~~operating ~~adverse~~segment. ~~effect~~If onoil ~~our~~and ~~business,~~natural ~~results~~gas ofprices ~~operations~~trade ~~and~~at ~~financial~~depressed ~~condition.~~price ~~In addition~~levels, weand ~~may~~our ~~not~~equipment beremains ~~able~~idle ~~to secure additional insurance~~ or ~~bonding~~under-utilized, ~~that~~the ~~might~~estimated befair ~~required~~value byof ~~new~~such ~~governmental~~equipment ~~regulations. This~~ may ~~cause~~decline, uswhich towill ~~restrict~~result ~~our~~in ~~operations,~~additional ~~which~~impairment ~~might~~expense ~~severely~~in ~~impact~~the ~~our financial position~~future.

Our operations are subject to unforeseen interruptions and hazards inherent in the oil and natural gas and mobile power generation industries, for which we may not be adequately insured, and which could cause us to lose customers and substantial revenue.

Our operations are exposed to the risks inherent to our industry, such as equipment defects, vehicle accidents, worksite injuries to our or third-party personnel, fires, explosions, blowouts, surface cratering, uncontrollable flows of gas or well fluids, pipe or pipeline failures, abnormally pressured formations and various environmental hazards, such as oil spills and releases of, and exposure to, hazardous substances. For example, our operations are subject to risks associated with hydraulic fracturing, including any mishandling, surface spillage or potential underground migration of fracturing fluids, including hydrochloric acid and other chemical additives. In addition, our operations are exposed to potential natural disasters, including blizzards, tornadoes, storms, floods, other adverse weather conditions and earthquakes. The occurrence of any of these events could result in substantial losses to us due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigations and penalties or other damage resulting in curtailment or suspension of our operations or the loss of customers. For example, in January 2025, we experienced an accident at a customer site that resulted in one fatality and injured two others, which temporarily halted operations and resulted in our being issued a citation by the Occupational Safety and Health Administration. The cost of managing such risks may be significant. The frequency and severity of such incidents will affect operating costs, insurability and relationships with customers, employees and regulators. In particular, our customers may elect not to purchase our services if they view our environmental or safety record as unacceptable, which could cause us to lose customers and substantial revenues.

Our insurance may not be adequate to cover all losses or liabilities we may suffer. We are also self-insured up to $10 million per occurrence for certain losses. Furthermore, we may be unable to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies have

increased and could escalate further. In addition, sub‑limits have been imposed for certain risks. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. If we were to incur a significant liability for which we are not fully insured, it could have a material adverse effect on our business, results of operations and financial condition. In addition, we may not be able to secure additional insurance or bonding that might be required by new governmental regulations. This may cause us to restrict our operations, which might severely impact our financial position.

Since hydraulic fracturing activities are part of our operations, they are covered by our insurance against claims made for bodily injury, property damage and cleanup costs stemming from a sudden and accidental pollution event. However, we may not have coverage if we are unaware of the pollution event and unable to report the "occurrence" to our insurance company within the time frame required under our insurance policy. In addition, these policies do not provide coverage for all liabilities, and the insurance coverage may not be adequate to cover claims that may arise, or we may not be able to maintain adequate insurance at rates we consider reasonable. A loss not fully covered by insurance could have a material adverse effect on our financial position, results of operations and cash flows.

A terrorist attack, armed conflict or political or civil unrest could harm our business.

Terrorist activities, anti‑terrorist efforts, other armed conflicts and political or civil unrest, including the Russia-Ukraine war and conflicts in the Middle East, could adversely affect the U.S. and global economies and could prevent us from meeting financial and other obligations. We could experience loss of business, delays or defaults in payments from payors or disruptions of fuel supplies and markets if pipelines, production facilities, processing plants, refineries or transportation facilities are direct targets or indirect casualties of an act of terror or war. Such activities could reduce the overall demand for oil and natural gas and power generation, which, in turn, could also reduce the demand for our services. Terrorist activities, the threat of potential terrorist activities, political or civil unrest and any resulting economic downturn could adversely affect our results of operations, impair our ability to raise capital or otherwise adversely impact our ability to realize certain business strategies.

We may be subject to claims for personal injury and property damage, which could materially adversely affect our financial condition and results of operations.

WeOutside of our mobile power business, we operate with most of our customers under master service agreements (“MSAs”). We endeavor to allocate potential liabilities and risks between the parties in the MSAs. Generally, under our MSAs, including those relating to our hydraulic fracturing services, we assume responsibility for, including control and removal of, pollution or contamination which originates above surface and originates from our equipment or services. In our power business, we typically operate under power purchase agreements or power-as-a-service agreements and these agreements typically have liability allocation provisions that are similar to our MSAs. Our customer assumes responsibility for, including control and removal of, all other pollution or contamination which may occur during operations, including that which may result from seepage or any other uncontrolled flow of drilling fluids. We may have liability in such cases if we are negligent or commit willful acts. Generally, our customers also agree to indemnify us against claims arising from their employees’ personal injury or death to the extent that, in the case of our hydraulic fracturing operations, their employees are injured or their properties are damaged by such operations, unless resulting from our gross negligence or willful misconduct. Similarly, we generally agree to indemnify our customers for liabilities arising from personal injury to or death of any of our employees, unless resulting from gross negligence or willful misconduct of the customer. In addition, our customers generally agree to indemnify us for loss or destruction of customer‑owned property or equipment and in turn, we agree to indemnify our customers for loss or destruction of property or equipment we own. Losses due to catastrophic events, such as blowouts, are generally the responsibility of the customer. However, despite this general allocation of risk, we might not succeed in enforcing such contractual allocation, might incur an unforeseen liability falling outside the scope of such allocation or may be required to enter into an MSA with terms that vary from the above allocations of risk. Litigation arising from a catastrophic occurrence at a location where our equipment and services are being used may result in us being named as a defendant in lawsuits asserting large claims. As a result, we may incur substantial losses which could materially and adversely affect our financial condition and results of operation.

We are subject to cyber security risks. A cyber incident could occur and result in information theft, data corruption, operational ~~disruption~~disruptions, reputational harm and/or financial loss.

~~The~~Our ~~oil~~ and ~~natural~~our ~~gas~~customers’ ~~industry~~businesses ~~has~~have become increasingly dependent on digital technologies to conduct certain processing activities. For example, we depend on digital technologies to perform many of our services and process and record operational and accounting data. At the same time, cyber incidents, including deliberate attacks or unintentional events, have increased.

The frequency and magnitude of cybersecurity attacks is increasing and attackers have become more sophisticated. Cybersecurity attacks are similarly evolving and include, without limitation, use of malicious software, surveillance, credential stuffing, spear phishing, social engineering, use of deepfakes (i.e., highly realistic synthetic media generated by ~~artificial intelligence~~AI), attempts to gain unauthorized access to data, and other electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or otherwise protected information and corruption of data. We may be unable to anticipate, detect or prevent future attacks, particularly as the methodologies used by attackers change frequently or are not identifiable until deployed. We may also be unable to investigate or remediate incidents as attackers are increasingly using techniques and tools designed to circumvent controls, to avoid detection, and to remove or obfuscate forensic evidence.

The U.S. government has issued public warnings indicating that energy assets might be specific targets of cyber security threats. Our technologies, systems and networks, and those of our vendors, suppliers and other business partners, may become the target of cyberattacks or information security breaches that could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary information, personal information and other data, or other disruption of our business operations. In addition, certain cyber incidents, such as unauthorized surveillance, may remain undetected for an extended period. Our systems and insurance coverage (if any) for protecting against cyber security risks, including cyberattacks, may not be sufficient and may not protect against or cover all of the losses (including potential reputational loss) we may experience as a result of the realization of such risks. As cyber incidents continue to evolve, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate the effects of cyber incidents.

We utilize technologies, controls and procedures, as well as internal staff and external service providers to protect our systems and data, to identify and remediate vulnerabilities and to monitor and respond to threats. However, there can be no assurance that such measures will be sufficient to prevent security breaches from occurring. No security measure is infallible. If we or the third parties with whom we interact were to experience a successful attack, the potential consequences to our business, workforce and the communities in which we operate could be significant, including financial losses, regulatory fines, loss of business, an inability to settle transactions or maintain operations, litigation costs, remediation costs, disruptions related to investigation, and significant damage to our reputation.

We may grow through acquisitions and/or internal expansions, and our failure to properly plan and manage such growth may adversely affect our performance.

Wegain ~~have~~unauthorized ~~completed~~access ~~and~~to ~~may in the future pursue~~data, ~~asset~~and ~~acquisitions~~other orelectronic ~~acquisitions~~security ofbreaches ~~businesses.~~that Wecould ~~have~~lead ~~internally~~to ~~expanded~~disruptions ~~and may~~ in ~~the~~critical ~~future~~systems, ~~expand~~unauthorized ~~into~~release ~~new lines~~ of ~~business.~~confidential, ~~Any~~personally ~~acquisition~~identifiable ~~of assets~~ or ~~businesses,~~otherwise orprotected ~~expansion~~information ~~into~~and ~~new~~corruption ~~lines~~ of ~~business~~data. ~~involves~~We ~~potential~~may ~~risks,~~be ~~including~~unable ~~the failure~~ to ~~realize expected profitability~~anticipate, ~~growth~~detect or ~~accretion;~~prevent ~~environmental~~future ~~or regulatory compliance matters or liability; title or permit issues; the incurrence of significant charges~~attacks, ~~such~~particularly as ~~impairment~~the ofmethodologies ~~goodwill,~~used ~~property~~by ~~and~~attackers ~~equipment~~change orfrequently ~~intangible assets~~ or ~~restructuring~~are ~~charges;~~not ~~and~~identifiable ~~the~~until ~~incurrence of unanticipated liabilities and costs for which indemnification is unavailable or inadequate~~deployed. ~~The~~We ~~process of upgrading acquired assets to our specifications and integrating acquired assets or businesses~~ may also ~~involve~~be ~~unforeseen~~unable ~~costs~~to ~~and~~investigate ~~delays~~ or ~~other~~remediate ~~operational,~~incidents ~~technical~~as ~~and~~attackers ~~financial~~are ~~difficulties~~increasingly ~~and~~using ~~may~~techniques ~~require a significant amount of time~~ and ~~resources~~tools ~~and~~designed ~~may~~to ~~divert~~circumvent ~~management’s attention from existing operations or other priorities. For example~~controls, into ~~2024,~~avoid ~~we acquired the assets and operations of AquaProp~~detection, and ~~we are in the process of fully integrating all parts of the acquired business into our operations. In late 2024, we also started a new line of business~~ to ~~provide~~remove ~~power~~or ~~generation~~obfuscate ~~services~~forensic ~~to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers~~evidence. ~~This new line of business has not begun any revenue-generating activities yet.~~

WeThe ~~must~~U.S. ~~plan~~government ~~and~~has ~~manage~~issued ~~any~~public ~~acquisitions~~warnings indicating that energy assets might be specific targets of cyber security threats. Our technologies, systems and ~~expansions~~networks, ~~effectively~~and tothose ~~achieve~~of ~~revenue~~our ~~growth~~vendors, suppliers and ~~maintain~~other ~~profitability~~business partners, may become the target of cyberattacks or information security breaches that could result in ~~our~~the ~~evolving~~unauthorized ~~market.~~release, ~~Any~~gathering, ~~failure~~monitoring, tomisuse, ~~manage~~loss ~~acquisitions~~or destruction of proprietary and ~~expansions~~confidential ~~effectively~~information, orpersonally ~~integrate~~identifiable ~~acquired~~information ~~assets~~and other data, or ~~businesses~~other ~~into~~disruption of our ~~existing~~business operations. ~~successfully~~In addition, orcertain tocyber ~~realize~~incidents, ~~the~~such ~~expected~~as ~~benefits~~unauthorized ~~from~~surveillance, may remain undetected for an ~~acquisition~~extended orperiod. ~~minimize~~Our systems and insurance coverage (if any) ~~unforeseen~~for ~~operational~~protecting ~~difficulties~~against cyber security risks, ~~could~~including ~~have~~cyberattacks, may not be sufficient and may not protect against or cover all of the losses (including potential reputational loss) we may experience as a ~~material~~result ~~adverse~~of ~~effect~~the onrealization ~~our~~of ~~business,~~such ~~financial~~risks. ~~condition~~As cyber incidents continue to evolve, ~~prospects~~we may be required to expend additional resources to continue to modify or ~~results~~enhance our protective measures or to investigate and remediate the effects of ~~operations~~cyber incidents.

We utilize technologies, controls and procedures, as well as internal staff and external service providers, to protect our systems and data, to identify and remediate vulnerabilities and to monitor and respond to threats. However, there can be no assurance that such measures will be sufficient to prevent security breaches from occurring. No security measure is infallible. If we or the third parties with whom we interact were to experience a successful attack, the potential consequences to our business, workforce and the communities in which we operate could be significant, including financial losses, regulatory fines or penalties, loss of business, an inability to settle transactions or maintain operations, litigation costs, compliance and remediation costs, disruptions related to investigation, and significant damage to our reputation.

We may pursue acquisitions, internal expansions or other strategic transactions, and our failure to properly plan and manage such growth may adversely affect our performance.

We have completed and may in the future pursue asset acquisitions, acquisitions of businesses or other strategic transactions. We have internally expanded and may in the future expand into new lines of business, such as our new PROPWRSM business. Any acquisition of assets or businesses, expansion into new lines of business or other strategic transactions involves potential risks, including the failure to realize expected profitability, growth or accretion; environmental or regulatory compliance matters or liability; title or permit issues; the incurrence of significant charges, such as impairment of goodwill, property and equipment, intangible assets or restructuring charges; and the incurrence of unanticipated liabilities and costs for which indemnification is unavailable or inadequate. The process of upgrading acquired assets to our specifications and integrating acquired assets or businesses may also involve unforeseen costs and delays or other operational, technical and financial difficulties and may require a significant amount of time and resources and may divert management’s attention from existing operations or other priorities. For example, since 2023, we acquired the assets and operations of Par Five Energy Services LLC and Aqua Prop, LLC, which required fully integrating all parts of the acquired business into our operations.

We must plan and manage any acquisitions, expansions or other strategic transactions effectively to achieve revenue growth and maintain profitability in our evolving market. Any failure to manage acquisitions, expansions or other strategic transactions effectively or integrate acquired assets or businesses into our existing operations successfully, or to realize the expected benefits from such transactions or minimize any unforeseen operational difficulties, could have a material adverse effect on our business, financial condition, prospects or results of operations.

We may be adversely affected by the effects of inflation.

The U.S. inflation rate steadily increased in ~~2021 and~~ 2022 before decreasing to a moderate level in 2023 through ~~2024~~2025. Inflation in wages, materials, parts, equipment and other costs has the potential to adversely affect our results of operations, cash flows and financial position by increasing our overall cost structure, particularly if we are unable to achieve commensurate increases in the prices we charge our customers for our products and services. In addition, the existence of inflation in the economy has the potential to result in higher interest rates, which could result in higher borrowing costs, supply shortages, increased costs of labor, weakening exchange rates and other similar effects. Sustained levels of high inflation have likewise caused the U.S. Federal Reserve and other central banks to increase interest rates in 2023 followed by decreases in 2024 and 2025, and the U.S. Federal Reserve may maintain high benchmark interest rates ~~into~~throughout ~~2025~~2026 in an effort to curb inflationary pressure on the costs of goods and services across the U.S., which could have the effects of raising the cost of capital and depressing economic growth, either of which—or the combination thereof—could hurt the financial and operating results of our business. To the extent elevated inflation remains, and as a result potential changes in U.S. trade policy, including the imposition of tariffs and the resulting consequences, we may experience further cost increases for our operations, including labor costs and equipment. We cannot predict any future trends in the rate of inflation and a significant increase in inflation, to the extent we are unable to timely pass-through the cost increases to our customers, would negatively impact our business, financial condition and results of operations.

the resulting consequences, we may experience further cost increases for our operations, including labor costs and equipment. We cannot predict any future trends in the rate of inflation and a significant increase in inflation, to the extent we are unable to timely pass-through the cost increases to our customers, would negatively impact our business, financial condition and results of operations.

Risks Related to Customers, Suppliers and Competition

Reliance upon a few large customers may adversely affect our revenue and operating results.

The majority of our revenue is generated from our hydraulic fracturing services. Due to the large percentage of our revenue historically derived from our hydraulic fracturing services with recurring customers and the limited availability of our fracturing units, we have had some degree of customer concentration. Our top ten customers represented approximately 7584.35%, 8575.53% and 9185.25% of our consolidated revenue for the years ended December 31, ~~2024~~2025, ~~2023~~2024 and ~~2022~~2023, respectively. It is likely that we will depend on a relatively small number of customers for a significant portion of our revenue in the future. If awe ~~major~~cease ~~customer fails~~ to ~~pay~~do ~~us,~~work ~~revenue~~for ~~would~~a becustomer, ~~impacted and~~ our operating results and financial condition ~~could~~would be ~~harmed.~~adversely ~~Additionally,~~affected ifunless we ~~were~~successfully toredeploy ~~lose~~the ~~any~~equipment. ~~material~~Our ~~customer,~~inability ~~we may not be able~~ to redeploy our equipment at similar utilization or pricing levels and such loss could have an adverse effect on our business until the equipment is redeployed at similar utilization or pricing levels. Similarly, if a major customer fails to pay us, our revenue would be impacted and our operating results and financial condition could be harmed. ExxonMobil, Occidental Petroleum Corporation, EOG Resources, Inc. and Permian Resources Corporation accounted for 24.9%, 13.7%, 12.1%, and 11.2%, respectively, of our revenue for the year ended December 31, 2025. Two of our fleets that currently perform services for ExxonMobil’s subsidiary XTO are governed by an agreement that will expire in approximately late 2026. At this time, we do not expect such agreement to be renewed or extended and, if we are not able to procure additional work from XTO, we will be required to redeploy the equipment associated with the affected fleets with other customers, exposing us to the risks described below associated with a delay or inability to redeploy our equipment.

~~XTO Energy~~Finally, Permian Resources and EOG Resources accounted for 19.7%, 14.9% and 10.6%, respectively, of our revenue for the year ended December 31, 2024. If either of these customers were to significantly reduce or discontinue our services, it could there have ~~a material adverse effect on our financial condition, results of operations and cash flows. There have~~ been many recent mergers and acquisitions in the oil and gas industry. In May 2024, Pioneer merged with and into a wholly owned subsidiary of ExxonMobil. The Company currently provides pressure pumping, wireline and other services to ExxonMobil and previously provided such services to Pioneer. Mergers and acquisitions involving our customers could negatively impact our future business with them or positively impact our business by providing us access to potential new customers.

We face significant competition that may cause us to lose market share, and competition in our industry has intensified as a result of customer consolidation and industry downturns.

The energy service industry is highly competitive and has relatively few barriers to entry. The principal competitive factors impacting sales of our services are price, reputation and technical expertise, equipment and service quality and health and safety standards. The market is also fragmented and includes numerous small companies capable of competing effectively in our markets on a local basis, as well as several large companies that possess substantially greater financial and other resources than we do. Our larger competitors’ greater resources could allow those competitors to compete more effectively than we can. For instance, our larger competitors may offer services at below‑market prices or bundle ancillary services at no additional cost to our customers. We compete with large national and multi‑national companies that have longer operating histories, greater financial, technical and other resources and greater name recognition than we do. Several of our competitors provide a broader array of services and have a stronger presence in more geographic markets. In addition, we compete with several smaller companies capable of competing effectively on a regional or local basis.

Some jobs are awarded on a bid basis, which further increases competition based on price. Pricing is often the primary factor in determining which qualified contractor is awarded a job. The competitive environment may be further intensified by tighter emissions standards in the energy industry and mergers and acquisitions among oil and natural gas companies or other events that have the effect of reducing the number of available customers. As a result of competition, we may lose customers or customer work and lose market share or be unable to maintain or increase prices for our present services or to acquire additional business opportunities, which could have a material adverse effect on our business, financial condition, results of operations and cash flows.

Our competitors may be able to respond more quickly to new or emerging technologies and services and changes in customer requirements. The amount of equipment available may exceed demand, which could result in active price competition. In addition, ~~some~~from ~~E&P~~time ~~companies~~to ~~have~~time, ~~commenced~~our ~~completing~~customers ~~their~~and ~~wells~~potential ~~using~~customers acquire equipment and utilize their own ~~hydraulic~~personnel ~~fracturing~~to ~~equipment~~perform ~~and~~services ~~personnel~~similar or equivalent to the services we offer. Any increase in the development and utilization of such in‑-house ~~fracturing~~services ~~capabilities~~ by our customers or potential customers could decrease the demand for our services and have a material adverse impact on our business.

Pressure on pricing for our services resulting from the industry downturn has impacted, and may continue to impact, our ability to maintain utilization and pricing for our services or implement price increases. During periods of declining pricing for our services, we may not be able to reduce our costs accordingly, which could further adversely affect our results of operations. Also, we may not be able to successfully increase prices without adversely affecting our utilization levels. The inability to maintain our utilization and pricing levels, or to increase our prices as costs increase, could have a material adverse effect on our business, financial condition and results of operations.

Furthermore, competition among energy service and equipment providers is affected by each provider’s reputation for safety and quality. We cannot assure that we will be able to maintain our competitive position.

We expect to face significant competition in the future as the mobile and modular power industry evolves.

The power generation industry is evolving rapidly, driven by increased demand from numerous end-markets, including those in the data center, industrial, utility and energy businesses. As a result, increased competition from within the mobile and modular power industry can likely be expected to occur. Should this materialize, the portion of the total addressable market that we could capture with our power generation services could be lower than expected, which could translate to lower than expected revenues, which in turn could have a material adverse effect on our business, financial condition and results of operations.

Our customers may not continue to outsource their power generation needs.

Our customers have a wide range of applications and equipment to address power generation needs. As a result of the significant resources and expertise required to develop these systems, certain of these customers have chosen to outsource the provision of power generation to us. To a significant extent, we will depend on customers continuing to outsource their power generation needs. Customers may not continue to outsource as much or any of their power generation needs in the future or may seek alternative solutions.

We are exposed to the credit risk of our customers, and any material nonpayment or nonperformance by our customers could adversely affect our business, results of operations and financial condition.

We are subject to the risk of loss resulting from nonpayment or nonperformance by our customers. Our credit procedures and policies may not be adequate to fully eliminate customer credit risk. If we fail to adequately assess the creditworthiness of existing or future customers or experience unanticipated deterioration in their creditworthiness, any resulting increase in nonpayment or nonperformance by them and our inability to re‑market or otherwise use the production could have a material adverse effect on our business, results of operations and financial condition. In weak economic environments, we may experience increased delays and failures to pay due to, among other reasons, a reduction in our customers’ cash flow from operations and their access to the credit markets or other sources of capital. The unpredictable nature of oil and gas prices in recent years and other factors may have negatively impacted the financial condition and liquidity of some of our customers, and future declines or continued volatility could impact their ability to meet their financial obligations to us. If our customers delay paying or fail to pay us a significant amount of our outstanding receivables, it could have a material adverse effect on our liquidity, results of operations, and financial condition.

Our business depends upon the ability to obtain specialized equipment, parts and key raw materials, including ~~sand~~power ~~and~~generation ~~chemicals~~assets, balance of plant components, power distribution equipment and associated ancillary equipment, from third‑party suppliers,. ~~and~~We we may be vulnerable to supply chain disruptions, delayed deliveries and future price increases, which could adversely impact our ability to provide our services.

We purchase specialized equipment, parts and raw materials (including, for example, power generation ~~equipment~~assets, ~~frac~~balance ~~sand~~of plant components, ~~chemicals~~power distribution equipment, gas processing equipment and ~~fluid~~associated ~~ends~~ancillary equipment) from third party suppliers and affiliates. In some cases, our customers, particularly customers for our hydraulic fracturing services, are responsible for supplying necessary raw materials (including frac sand), parts and/or equipment. Our power generation business, and the power generation industry in general, is especially dependent upon foreign supply chains and rare earth minerals as raw materials for power generation assets. Our suppliers use multiple forms of transportation to bring their products to market, including truck, ocean and air-cargo shipments. At times during the business cycle, there is a high demand for hydraulic fracturing, power generation and other energy services and extended lead times to obtain equipment and raw materials needed to provide these services. For example, in 2021 and 2022, there was significant disruption in supply chains around the world caused by the COVID-19 pandemic that impacted our operations. In addition, the ongoing war in Ukraine and conflicts in the Middle East, and related international sanctions and restrictions have impacted supply chains, and in some cases, global shipping routes. Should our current suppliers (or our customers’ suppliers where applicable) be unable or unwilling to provide the necessary equipment, parts or raw materials or otherwise fail to deliver the products timely and/or in the quantities

2324

~~demand~~required, ~~for~~whether ~~hydraulic~~as ~~fracturing~~a ~~and~~result ~~other~~of ~~energy~~a ~~services~~disruption ~~and extended lead times~~ to ~~obtain~~the ~~equipment~~timely ~~and~~supply of raw materials ~~needed to provide these services. For example~~, inparts ~~2021~~ and ~~2022~~finished goods, ~~there~~or ~~was~~increases ~~significant disruption~~ in ~~supply chains around~~ the ~~world~~cost ~~caused~~of bytransportation ~~the~~services ~~COVID-19 pandemic that impacted our operations. Should our current suppliers~~ (orincluding ~~our~~due ~~customers’ suppliers where applicable) be unable or unwilling~~ to ~~provide~~general ~~the~~inflationary ~~necessary equipment~~pressures, ~~parts~~potential or ~~raw~~increased ~~materials~~tariffs, orcost ~~otherwise~~of ~~fail~~fuel toand ~~deliver~~labor, ~~the~~labor ~~products~~disputes, ~~timely~~governmental ~~and/~~regulation or ~~in the quantities required~~restrictions), any resulting delays in the provision of our services could have a material adverse effect on our business, financial condition, results of operations and cash flows. In addition, future price increases (including as a result of potential or increased tariffs) for this type of specialized equipment, parts and raw materials could negatively impact our ability to purchase new equipment, including new power generation assets, to update or expand our existing fleets, to timely repair equipment in our existing fleets or meet the current demands of our customers.

We may be required to pay fees to certain of our ~~Sand~~sand ~~Suppliers~~suppliers based on minimum volumes under long-term contracts regardless of actual volumes received.

We enter into purchase agreements with ~~the~~our ~~Sand~~sand ~~Suppliers~~suppliers to secure supply of sand in the normal course of our business. The agreements with the ~~Sand~~sand ~~Suppliers~~suppliers typically require that we purchase minimum ~~volume~~volumes of sand, based primarily on a certain percentage of our sand requirements from our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties (shortfall fees) may be charged. The shortfall fee represents liquidated damages and is either a fixed percentage of the purchase price for the minimum volumes or a fixed price per ton of unpurchased volumes. Our ~~current~~existing agreements with ~~Sand~~sand ~~Suppliers~~suppliers expire aton ~~different times prior to December~~May 31, ~~2025~~2029.

~~Disruption~~We ofmay be unable to adapt our ~~supply~~power ~~chain~~generation technologies to meet increasing customer needs and power loads, which could ~~adversely~~result ~~impact~~in increased downtime of our ~~ability~~power generation offering and disruptions to ~~provide~~the power supply to our ~~services~~customers.

~~Our~~Demand ~~suppliers~~for ~~use~~power ~~multiple~~has ~~forms~~continued ofto ~~transportation~~significantly tooutpace ~~bring~~available ~~their~~power ~~products~~generation tosupply ~~market,~~from ~~including~~the ~~truck~~grid, ~~ocean~~with ~~and air-cargo shipments. Disruption to~~ the ~~timely~~oil ~~supply of raw materials, parts~~ and ~~finished~~natural ~~goods~~gas orindustry ~~increases~~requiring inincreasing ~~the~~amounts ~~cost~~ of ~~transportation services~~power, ~~including~~as ~~due~~an toexample, ~~general~~exceeding ~~inflationary~~existing ~~pressures~~generation capacity, ~~cost~~requiring ofadditional ~~fuel~~transmission and ~~labor,~~distribution ~~labor~~infrastructure ~~disputes,~~and ~~governmental~~straining ~~regulation~~aging orpower ~~governmental~~grids. ~~restrictions~~Further, ~~limiting~~the ~~specific~~expanding ~~forms~~use of ~~transportation,~~AI ~~could~~has ~~have~~led anto ~~adverse~~additional ~~effect~~demand onfor ~~our~~electricity ~~ability~~as toa ~~provide~~result ~~our~~of ~~services,~~the ~~which~~expansion ~~would~~of ~~adversely~~existing ~~affect~~data ~~our~~centers ~~results~~and ofplans ~~operations,~~for ~~cash~~new ~~flows~~data ~~and~~centers ~~financial~~that ~~position~~support AI.

As we expand our power generation services, our current offering may not be able to effectively manage future power loads or otherwise satisfy evolving customer service demands, which could result in potential downtimes and disruptions for our customers and may lead to reputational damage and loss of customers. In addition, we are typically required to commit and install more generating capacity than is required under our power supply contracts in order to meet the reliability standards under those contracts, which increases the capital cost to us of the installed equipment. If we are unable to adapt our power generation technologies to meet future demand and customer needs as they evolve, or otherwise unable to meet their reliability requirements, our business and operating results may be adversely affected.

Distributed power generation services in some applications compete with access to the grid.

Distributed power generation services are an alternative for customers to consider when grid access is unavailable, costly or delayed. Our distributed power generation services offering could be affected in the event that large-scale utility projects are completed and the associated transmission and distribution networks are established. In this case, customers may only use our service offering as backup power or bridge power until line power is received.

Risks Related to Employees

We rely on a few key employees whose absence or loss could adversely affect our business.

Many key responsibilities within our business have been assigned to a small number of employees. The loss of their services could adversely affect our business. In particular, the loss of the services of one or more members of our executive team, such as our Chief Executive Officer, President and Chief Operating Officer, Chief Financial Officer, Chief Accounting Officer, Chief Commercial Officer, and General Counsel could disrupt our operations. We do not maintain “key person” life insurance policies on any of our employees. As a result, we are not insured against any losses resulting from the death of our key employees.

If we are unable to employ a sufficient number of skilled and qualified workers, our capacity and profitability could be diminished and our growth potential could be impaired.

The delivery of our services requires skilled and qualified workers with specialized skills and experience who can perform physically demanding work. As a result of the volatility of the energy service industry and the demanding nature of the work, workers may choose to pursue employment in fields that offer a less challenging work environment at wage rates that are competitive. Our ability to be productive and profitable will depend upon our ability to employ and retain skilled workers. In addition, our ability to expand our operations depends in part on our ability to increase the size of our skilled workers. As a result of the physical nature of our operations, we have experienced difficulties in attracting and retaining skilled workers. If demand for our services increases, we may experience difficulty in hiring or re-hiring skilled and unskilled workers in the future to meet that demand. At times, the demand for skilled workers in our geographic areas of operations is high, and the supply is limited. As a result, competition for experienced energy service personnel is intense, and we face significant challenges in competing for crews and management with large and well‑established competitors. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases in the wage rates that we must pay, or both. Furthermore, if we are unable to adjust wages to account for rapidly rising inflationary cost, there could be a reduction in the available skilled labor force we could attract or retain. If any of these events were to occur, our capacity and profitability could be diminished and our growth potential could be impaired.

Risks Related to Regulatory Matters

We are subject to environmental laws and regulations, and future compliance, claims, and liabilities relating to such matters may have a material adverse effect on our results of operations, financial position or cash flows.

The nature of our operations, including the handling, storing, transporting and disposing of a variety of fluids and substances, including hydraulic fracturing fluids, which can contain substances such as hydrochloric acid, and other regulated substances, air emissions, urea and ammonia, glycol, oil and coolant, consumables and wastewater discharges exposes us to some risks of environmental liability, including the release of pollutants from oil and natural gas wells and associated equipment to the environment, emissions or releases from our power generating equipment including air emissions, consumables which require disposal and contribute to waste storage with little to no recyclability, and potential spills from gas processing equipment. The cost of compliance with these laws can be significant. Failure to properly handle, transport or dispose of these materials or otherwise conduct our operations in accordance with these and other environmental laws could expose us to substantial liability for administrative, civil and criminal penalties, cleanup and site restoration costs and liability associated with releases of such materials, damages to natural resources and other damages, as well as potentially impair our ability to conduct our operations. Such liability is commonly on a strict, joint and several liability basis, without regard to fault. Liability may be imposed as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior operators or other third parties. Neighboring landowners and other third parties may file claims against us for personal injury or property damage allegedly caused by the release of pollutants into the environment. Environmental laws and regulations have changed in the past, and they may change in the future and become more stringent. For example, the prior administration made climate change a focus of its administration. For more information, see our risk factor titled, “Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide.” Separately, current and future claims and liabilities may have a material adverse effect on us because of potential adverse outcomes, defense costs, diversion of management resources, unavailability of insurance coverage and other factors. The ultimate costs of these liabilities are difficult to determine and may exceed any reserves we may have established. If existing environmental requirements or enforcement policies change, we may be required to make significant unanticipated capital and operating expenditures.

Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide.

~~Numerous~~Our ~~proposals~~operations ~~regarding~~as ~~climate~~well ~~change~~as the operations of our oil and natural gas E&P customers are subject to a series of regulatory, political, litigation, and financial risks associated with the production and processing of fossil fuels and, relatedly, emission of GHG. Numerous proposals have been made and ~~could~~certain ~~continue~~laws tohave bebeen ~~made~~enacted at the international, national, ~~regional~~ and state ~~levels~~level ~~of government~~ to monitor and limit ~~existing~~GHG emissions. Theses efforts have included consideration of ~~GHGs~~GHG ascap ~~well~~and astrade toprograms, ~~restrict~~carbon ortaxes, ~~eliminate~~climate-related ~~future~~financial ~~GHG~~risks and emissions. Asreporting aand ~~result~~tracking programs, ~~our~~and ~~operations~~restriction asof ~~well~~emissions. asThese ~~the~~initiatives ~~operations~~could ofincrease our ~~oil~~operating costs and ~~natural~~lead ~~gas~~to ~~E&P~~reputational ~~customers~~harm ~~are~~to ~~subject~~the toextent aour ~~series~~disclosures or efforts do not align with expectations of ~~regulatory~~regulators, ~~political~~investors or other parties. Further, ~~litigation~~certain laws, ~~and~~like ~~financial~~the ~~risks~~Inflation ~~associated~~Reduction ~~with~~Act ~~the~~of ~~production~~2022, include various incentives for lower carbon activities and ~~processing~~impose ofa ~~fossil~~fee ~~fuels~~on excess methane emissions from certain oil and ~~emission~~natural gas facilities, though Congress has taken action to delay implementation of ~~GHGs~~this fee until 2034.

In the United States, no comprehensive climate change legislation has been implemented at the federal level, though recently passed laws such as the IRA 2022 advance numerous climate-related objectives. Additionally, ~~following~~notwithstanding the ~~U.S. Supreme Court finding that GHG emissions constitute a pollutant under the CAA, the~~ EPA’s ~~has~~recent adopted regulations that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources in the United States, implement New Source Performance Standards directing the reduction of certain pollutants from certain new, modified, or reconstructed facilities in the oil and natural gas sector, and together with the DOT, implementing GHG emissions limits on vehicles manufactured for operation in the United States. In December 2023, the EPA finalized a rule that established OOOOb more stringent new source and OOOOc first-time existing source standards of performance for methane and volatile organic compound emissions for oil and gas facilities. Under the final rule, ~~states~~revoking ~~will have two years to prepare and submit their plans to impose methane emissions controls on existing sources. The presumptive standards under~~ the ~~final~~“Endangerment ~~rule are generally the same for both new and existing sources~~Finding”, ~~including~~which ~~enhanced~~supports leak detection using optical gas imaging and subsequent repair equipment, and reduction of emissions by 95% through capture and control systems. The rule also revises requirements for fugitive emissions monitoring and repair as well as equipment leaks and the ~~frequency~~majority of monitoring surveys, establishes a "super-emitter" response program to timely mitigate emissions events as detected by governmental agencies or qualified third parties, triggering certain investigation and repair requirements, and provides additional options for the ~~use of advanced monitoring to encourage the deployment of innovative technologies to detect and reduce methane emissions. However the~~ EPA’s ~~final~~GHG-related ~~rule is currently being challenged by 23 states and a coalition of industry groups in the U.S Circuit Court of Appeals for the D.C. Circuit. Additionally~~regulations, ~~at this time, it remains uncertain as to whether~~ the ~~current~~EPA ~~administration~~under ~~will~~previous ~~repeal~~presidential oradministrations ~~modify~~has ~~this~~adopted ~~rule~~a ~~and~~number the timing with respect to the same. Notwithstanding this, failure to comply with these new methane rules may result in substantial fines and penalties for non-compliance, as well as injunctive relief. Additionally, various states and groups of ~~states have adopted or are considering adopting legislation,~~ regulations or other regulatory initiatives that are focused on such areas such as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. At the international level, the United Nations-sponsored Paris Agreement, requires member states to submit non-

binding, individually-determined reduction goals known as NDCs every five years after 2020. The United States rejoined the Paris Agreement in January 2021 and, in April 2021, established a goal of reducing economy-wide net GHG emissions 50-52% below 2005 levels by 2030. However, in January 2025, the current President signed an Executive Order once again withdrawing the United States from the Paris Agreement and from any other commitments made under the United Nations Framework Convention on Climate Change. The full impact of these recent developments is uncertain at this time.

Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States. For example, in January 2024 the government announced a temporary pause on pending decisions on liquefied natural gas exports to certain countries. However, upon taking office, the current President signed an Executive Order resuming the processing of permit applications for such projects. Litigation risks are also increasing as a number of parties have sought to bring suit against certain oil and natural gas companies operating in the United States in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or that such companies have been aware of the adverse effects of climate change but failed to adequately disclose those impacts to their investors or customers. Additionally on January 26, 2024, the former president announced a temporary pause on pending decisions on new exports of LNG to countries that the United States does not have free trade agreements with, pending Department of Energy review of the underlying analyses for authorizations. The pause was intended to provide time to integrate certain considerations, including potential energy cost increases for consumers and manufacturers and the latest assessment of the impact of GHG emissions, to ensure adequate guards against health risks. The Department of Energy finalized its study in December 2024. However, upon taking office, the current President signed an Executive Order resuming the processing of permit applications for such projects. At this time, it is unclear what actions the Presidential Administration may take, if at all, with respect to the Department of Energy’s study. Litigation risks are also increasing as a number of parties have sought to bring suit against certain oil and natural gas companies operating in the United States in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or that such companies have been aware of the adverse effects of climate change but failed to adequately disclose those impacts to their investors or customers.

There have also recent been increasing financial risks for companies in the fossil fuel sector as certain shareholders currently invested in fossil-fuel energy companies concerned about the potential effects of climate change may elect in the future to shift some or all of their investments into non-fossil fuel related sectors. Institutional lenders who provide financing to fossil-fuel energy companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies although this trend has waned recently and several high-profile banks and institutional investors have withdrawn from various associations that aim to limit financing of industries that emit significant GHG emissions. Any limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities. Separately, the SEC released a final rule on climate-related disclosures on March 6, 2024, requiring the disclosure of certain climate-related risks and financial impacts, as well as GHG emissions, which was subsequently stayed by the U.S. Court of Appeals for the Fifth Circuit. The future of the rule remains uncertain at this time given the litigation; however, on February 11, 2025, SEC Acting Chairman Mark T. Uyeda released a public statement and notified the U.S. Court of Appeals for the Eighth Circuit (where the challenges are consolidated) to hold off scheduling argument in the case to provide time for the SEC to further deliberate the final rule and determine next steps. Relatedly, certain states have enacted or are otherwise considering disclosure requirements for certain climate-related risks. Enhanced climate-related disclosure requirements could increase our operating costs and lead to reputational or other harm with customers, regulators, or other stakeholders to the extent our disclosures do not meet their own standards or expectations. Consequently, we are also exposed to increased litigation risks relating to alleged climate-related damages resulting from our operations, statements alleged to have been made by us or others in our industry regarding climate change risks, or in connection with any future disclosures we may make regarding reported emissions, particularly given the inherent uncertainties and estimation required with respect to calculating and reporting GHG emissions. We also cannot predict how financial institutions and investors might consider any information disclosed under any such requirements when making investment decisions, and as a result it is possible that we could face increases with respect to the costs of, or restrictions imposed on, our access to capital.

Climate change may result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in the meteorological and hydrological patterns, that could adversely impact us, our customers’ and our suppliers’ operations. Such physical risks may result in damage to our customers’ facilities or otherwise adversely impact our operations, such as if facilities are subject to water use curtailments in response to drought, or demand for our customers’ products, such as to the extent warmer winters reduce the demand for energy for heating purposes, which may ultimately reduce demand for the products and services we provide. Such physical risks may also impact our suppliers, which may adversely affect our ability to provide our products and services. Extreme weather conditions can interfere with our operations and increase our costs, and damage resulting from extreme weather may not be fully insured.

aiming to reduce GHG emissions, including those from facilities in the oil and natural gas sector. However, the EPA is currently in the process of attempting to repeal, revise, or otherwise take action with respect to many of its regulations involving GHG emissions and climate change. As a result, there is significant uncertainty with respect to the future regulation of climate change at the federal level, and whether or how the current presidential administration will take further action with respect to climate change cannot be predicted at this time.

Litigation risks have also increased as a number of parties seek to bring suit against certain oil and natural gas companies operating in the United States in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or that such companies have been aware of the adverse effects of climate change but failed to adequately disclose those impacts to their investors or customers. Consequently, we may also be exposed, directly or indirectly, to such increased litigation risks relating to alleged climate-related damages, reports, or disclosures.

Financial risks have also increased for companies in the fossil fuel sector as certain shareholders or institutional lenders that provide financing may limit their investments in fossil fuels companies, though this trend has waned in recent years. Any limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities. We also cannot predict how financial institutions and investors might consider any information disclosed under any state climate reporting requirements, and as a result it is possible that we could face increases with respect to the costs of, or restrictions imposed on, our access to capital.

Federal and state legislative and regulatory changes relating to air permits could result in increased costs and additional operating restrictions or delays.

Our power generation equipment requires us to obtain air permits and we have assumed responsibility in obtaining such permits in some of our agreements. We believe obtaining air permits has been a competitive advantage. If the rules or regulations change that negatively affect our ability to obtain such permits or increase our costs, it could adversely impact our business.

Federal and state legislative and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

Our hydraulic fracturing operations are a significant component of our business, and it is an important and common practice that is used to stimulate production of hydrocarbons, particularly oil and natural gas, from tight formations, including shales. The process, which involves the injection of water, sand and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and natural gas commissions. However, federal agencies have asserted regulatory authority over certain aspects of the process. For example, the EPA has previously issued a series of rules under the CAA that establish new emission control requirements for emissions of volatile organic compounds and methane from certain oil and natural gas production and natural gas processing operations and equipment. ~~Separately~~Additionally, ~~the~~in ~~BLM~~April ~~finalized~~and aMay ~~rule governing hydraulic fracturing on federal lands but this rule was subsequently rescinded. Although several of these rulemakings have been rescinded~~2024, ~~modified or subjected to legal challenges, new or more stringent regulations may be promulgated by~~ the ~~government~~U.S. ~~For~~Bureau ~~example,~~of inLand ~~March~~Management ~~2024 the~~ (“BLM”) finalized atwo ~~rule~~rules ~~that~~increasing ~~requires~~royalty ~~operators~~rates, torentals, ~~limit~~and ~~flaring~~minimum ~~from well sites on federal lands~~bids, and ~~allows~~updating the ~~delay~~agency’s orinterpretation ~~denial~~ of ~~permits~~its ifmandate ~~BLM finds~~ that anconservation ~~operator’s methane waste minimization plan~~ is ~~insufficient.~~a ~~The~~use ~~rule~~of ~~was~~federal ~~challenged~~land byon ~~various~~par ~~states~~with inmineral ~~the~~extraction ~~District~~and ~~Court~~other ofuses ~~North~~(“Public ~~Dakota~~Lands ~~and,~~Rule”). inIn September ~~2024~~2025, the ~~court~~U.S. ~~ordered~~Department ~~that~~of the ~~rule~~Interior ~~cannot~~announced beits ~~enforced~~proposal ~~within~~to ~~the~~rescind ~~plaintiff states pending~~ the ~~outcome~~Public ofLands ~~the litigation~~Rule. ~~Although the rule is currently being implemented in areas not covered by the order~~Further, ~~the future of the rule is uncertain. Additionally~~ in ~~January~~May ~~2021~~2025, the ~~president~~BLM ~~issued~~announced ~~an executive order suspending new leasing activities, but not operations under existing leases, for oil and gas E&P on non-Native American federal lands pending completion of~~ a ~~comprehensive~~policy ~~review~~designed ~~and~~to ~~reconsideration~~expedite ofthe ~~federal~~ oil and gas ~~permitting and~~ leasing ~~practices~~process ~~that take into consideration potential climate and other impacts associated with oil and gas activities~~ on ~~such~~public lands ~~and waters~~. Although the leasing pause was effectively halted by a permanent injunction in August 2022, in response to the executive order, the DOI issued a report recommending various changes to the federal leasing program, though many such changes would require Congressional action. In ~~April 2024~~addition, ~~the BLM finalized a rule updating the fiscal terms of~~ federal oil and gas leases, increasing fees, rents, royalties, and bonding requirements. The rule also adds new criteria for BLM to consider when determining whether to lease nominated land, including the presence of important habitats or wetlands, the presence of historical properties or sacred sites, and recreational use of the land. Any regulations that ban or effectively ban such operations may adversely impact demand for our products and services. Further, legislation to ~~amend~~repeal the Safe Drinking Water Act ~~to repeal the~~ exemption for hydraulic fracturing ~~(except when diesel fuels are used) from the definition of “underground injection”~~ and require ~~federal~~more stringent permitting ~~and regulatory control~~ of hydraulic fracturing, ashas ~~well~~previously asbeen ~~legislative~~proposed ~~proposals to require disclosure of the chemical constituents of the fluids used~~ in ~~the~~Congress. ~~fracturing~~This ~~process,~~federal ~~have~~legislation ~~been~~has ~~proposed~~not ~~in previous sessions of Congress~~passed. ~~Several~~Elsewhere, several states and local jurisdictions in which we or our customers operate also have adopted or are considering adopting regulations that could restrict or prohibit hydraulic fracturing in certain circumstances, impose more stringent operating standards and/or require the disclosure of the composition of hydraulic fracturing fluids.

Federal and state governments have also investigated whether the disposal of produced water into underground injection wells has caused increased seismic activity in certain areas. In response to concerns regarding induced seismicity, regulators in some states, including Oklahoma and Texas, have imposed, or are considering imposing, additional requirements in the permitting of produced water disposal wells or otherwise to assess any relationship between seismicity and the use of such wells. For example, Oklahoma has issued rules for wastewater disposal wells in 2014 that imposed certain permitting and operating restrictions and reporting requirements on disposal wells in proximity to faults and also, from time to time, has implemented plans directing certain wells where seismic incidents have occurred to restrict or suspend disposal well operations. In particular, the ~~Oklahoma~~Texas ~~Corporation~~Railroad Commission released well completion seismicity guidelines for operators in the SCOOP and STACK require hydraulic fracturing operations to be suspended following earthquakes of certain magnitudes in the vicinity. In addition, the Oklahoma Corporation Commission’s Oil and Gas Conservation Division has previously issued an order limiting future increases in the volume of oil and natural gas wastewater injected into the ground in an effort to reduce the number of earthquakes in the state. The (“TRRC”) has ~~adopted~~suspended similar rules and, in September 2021, issued a notice to disposal well operators in the Gardendale Seismic Response Area near Midland, Texas to reduce daily injection volumes following multiple earthquakes above a 3.5 magnitude over an 18 month period. The notice also required disposal well operators to provide injection data to TRRC staff to further analyze seismicity in the area. Subsequently, the TRRC ordered the indefinite suspension of all deep oil and gas produced water ~~injection~~handling wells in the area, effective December 31, 2021. The Gardendale Seismic Response area has since been expanded in response to an additional earthquake in December 2022, covering 17 additional wells. In December 2023, a further 23 deep disposal well permits ~~were~~and ~~suspended~~introduced ininjection the Northern Culberson-Reeves Seismic Response Area. While we cannot predict the ultimate outcome of these actions, any action that temporarily or permanently restricts the availability of disposal capacity for produced water or other oilfield fluids may increase our customers’ costs or require them to suspend operations, which may adversely impact demand for our products and services.

volume curtailment within the boundaries of certain seismic response areas. While we cannot predict the ultimate outcome of these actions, any action that temporarily or permanently restricts the availability of disposal capacity for produced water or other oilfield fluids may increase our customers’ costs or require them to suspend operations, which may adversely impact demand for our products and services.

Increasing trucking regulations may increase our costs and negatively impact our results of operations.

In connection with our business operations, including the transportation and relocation of our hydraulic fracturing and power generation equipment and shipment of frac sand, we operate trucks and other heavy equipment. As such, we operate as a motor carrier in providing certain of our services and therefore are subject to regulation by the DOT and by various state agencies. These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations, driver licensing, insurance requirements, financial reporting and review of certain mergers, consolidations and acquisitions, and transportation of hazardous materials. Our trucking operations are subject to possible regulatory and legislative changes that may increase our costs. Some of these possible changes include increasingly stringent environmental regulations, changes in the hours of service regulations which govern the amount of time a driver may drive or work in any specific period, onboard black box recorder device requirements or limits on vehicle weight and size.

Interstate motor carrier operations are subject to safety requirements prescribed by the DOT. To a large degree, intrastate motor carrier operations are subject to state safety regulations that mirror federal regulations. Matters such as the weight and dimensions of equipment are also subject to federal and state regulations. From time to time, various legislative proposals are introduced, including proposals to increase federal, state, or local taxes, including taxes on motor fuels, which may increase our costs or adversely impact the recruitment of drivers. We cannot predict whether, or in what form, any increase in such taxes applicable to us will be enacted.

Certain motor vehicle operators require registration with the DOT. This registration requires an acceptable operating record. The DOT periodically conducts compliance reviews and may revoke registration privileges based on certain safety performance criteria that could result in a suspension of operations.

Increased attention to ~~ESG~~sustainability matters, conservation measures, commercial development and technological advances could reduce demand for oil and natural gas, power generation and our services.

Fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and natural gas, increased attention to climate change and other ~~ESG~~sustainability-related matters, and technological advances in fuel economy and energy generation devices could reduce demand for oil and natural gas, resulting in reduced demand for energy services. The impact of the changing demand for oil and natural gas services and products may have a material adverse effect on our business, financial condition, results of operations and cash flows.

~~The~~While ~~commercial~~we ~~development~~may ofcreate ~~economically‑viable~~and ~~alternative~~publish ~~energy~~voluntary ~~sources~~or ~~and~~mandatory ~~related~~disclosures ~~products~~regarding ~~(such~~sustainability-related asmatters ~~electric~~from ~~vehicles,~~time ~~wind,~~to ~~solar~~time, ~~geothermal,~~certain ~~tidal,~~statements ~~fuel~~in ~~cells~~those ~~and~~disclosures ~~biofuels)~~may ~~could~~be ~~have~~based aon ~~similar~~expectations ~~effect. The IRA 2022 appropriates significant federal funding for renewable energy initiatives, which could accelerate the use~~ and ~~commercial~~assumptions ~~viability~~or ofhypothetical ~~alternative~~scenarios ~~energy~~that ~~sources~~are ~~and~~necessarily ~~decrease~~uncertain ~~demand for oil~~ and ~~natural~~may ~~gas.~~or ~~The~~may ~~IRA~~not ~~2022~~be ~~has~~representative ~~incentivized the further development~~ of ~~and~~current ~~investment~~or inactual ~~clean~~risks ~~energy~~or ~~through~~events ~~the~~or ~~use~~forecasts of ~~tax~~expected ~~credits,~~risks ~~and~~or ~~future~~events, ~~legislation~~including ~~could~~the ~~expand~~costs ~~these~~associated ~~benefits for alternative energy sources~~therewith. ~~In addition~~Additionally, ~~legislation~~we ~~has~~may ~~been~~announce ~~previously~~various ~~proposed~~targets ~~that~~or ~~would~~product ~~make~~and ~~changes~~service toofferings ~~certain~~in ~~U.S.~~an ~~federal~~attempt ~~income tax provisions currently applicable with respect~~ to ~~oil~~improve ~~and~~our ~~natural~~sustainability ~~gas~~profile. ~~exploration and development companies~~However, ~~including~~such bytargets ~~eliminating~~are ~~the~~often ~~percentage~~aspirational ~~depletion allowance for oil~~ and ~~natural~~we ~~gas~~cannot ~~properties.~~guarantee ~~While~~that itwe ~~remains~~will to be ~~seen~~able ifto ~~the~~meet ~~current administration would modify~~ or ~~repeal~~make ~~some~~progress oragainst ~~all of the IRA 2022,~~ any ~~future~~such ~~decreases~~targets inor ~~the~~that ~~rate~~such attargets ~~which oil and natural gas reserves are discovered~~ or ~~developed,~~offerings ~~whether~~will ~~due~~have to the ~~passage~~intended ofresults ~~legislation, increased governmental regulation leading to limitations, or prohibitions~~ on ~~exploration~~our ~~and~~sustainability ~~drilling activity~~profile, including ~~hydraulic~~but ~~fracturing,~~not orlimited ~~other~~to ~~factors,~~as ~~could have~~ a ~~material~~result ~~adverse~~of ~~effect~~unforeseen oncosts, ~~our~~inaccurate ~~business and financial condition~~forecasts, ~~even~~consequences inor atechnical ~~stronger oil and natural gas price and regulatory environment~~difficulties.

~~Moreover~~Also, ~~while~~despite weany ~~may create and publish~~ voluntary ~~disclosures regarding ESG-related matters from time to time~~actions, ~~certain~~we ~~statements in those voluntary disclosures~~ may bereceive ~~based~~pressure onfrom ~~expectations~~certain ~~and assumptions or hypothetical scenarios that may or may not be representative of current or actual risks or events or forecasts of expected risks or events~~investors, ~~including~~lenders ~~the costs associated therewith. Such expectations and assumptions~~ or ~~hypothetical~~other ~~scenarios~~groups ~~are~~to ~~necessarily~~adopt ~~uncertain~~more ~~and~~aggressive ~~may~~climate ~~be prone to error~~ or ~~subject~~other tosustainability-related ~~misinterpretation~~goals ~~given the long timelines involved and the lack of an established approach to identifying, measuring and reporting on many ESG matters. Additionally, we may announce various targets~~ or ~~product and service offerings in an attempt to improve our ESG profile. However~~policies, ~~such~~but ~~targets are often aspirational and~~ we cannot guarantee that we will be able to ~~meet~~pursue ~~any such targets~~ or ~~that~~implement such ~~targets~~goals orbecause ~~offerings will have the intended results on our ESG profile, including but not limited to as a result~~ of ~~unforeseen~~potential costs, ~~consequences~~ or technical ~~difficulties associated with such targets~~ or ~~offerings.~~operational obstacles.

Additionally, certain statements or initiatives with respect to sustainability-related matters that we may pursue or assert are increasingly subject to heightened scrutiny from the public and governmental authorities, as well as other parties, who may allege that such statements or initiatives are misleading, false or otherwise deceptive (sometimes referred to as “greenwashing”). Additionally, certain employment or business practices and social initiatives are the subject of scrutiny by

~~Also~~both those calling for the continued advancement of such policies, ~~despite~~as ~~any~~well ~~voluntary~~as ~~actions~~those who believe they should be curbed, including government actors, and the complex regulatory and legal frameworks applicable to such initiatives continue to evolve. More recent political developments could mean that we ~~may~~face ~~receive~~increasing ~~pressure~~criticism or litigation risks from certain ~~investors~~“anti-ESG” parties, ~~lenders~~including various governmental agencies. Such sentiment may focus on our environmental commitments (such as reducing GHG emissions) or ~~other~~our ~~groups~~pursuit of certain employment or business practices or social initiatives that are alleged to ~~adopt~~be ~~more~~political ~~aggressive~~or ~~climate~~polarizing in nature or ~~other~~are ~~ESG-related~~alleged ~~goals~~to violate laws based, in part, on changing priorities of, or ~~policies~~interpretations by, ~~but~~federal weagencies ~~cannot~~or ~~guarantee~~state ~~that~~governments, wewhich ~~will~~could adversely affect our reputation, business, financial performance, market access and growth. Accordingly, there may be ~~able~~increased costs related to ~~pursue~~reviewing, implementing and managing such policies, as well as compliance and litigation risks based both on positions we do or ~~implement~~do not take, or work we do or do not perform. The complex regulatory and legal frameworks applicable to such ~~goals~~initiatives ~~because~~continue to evolve. We cannot be certain of ~~potential~~the ~~costs~~impact orof ~~technical~~such regulatory, legal and other developments on our business. To the extent any enforcement actions or ~~operational~~other ~~obstacles~~litigation is brought against us a result of emerging viewpoints and legal interpretations, our business, financial condition and access to financing may be materially and adversely affected.

Additionally, certain statements or initiatives with respect to ESG-related matters that we may pursue or assert are increasingly subject to heightened scrutiny from the public and governmental authorities, as well as other parties. For example, the SEC has recently taken enforcement action against companies for ESG-related misconduct, including alleged “greenwashing,” (i.e., the process of conveying misleading information or making false claims that overstate potential ESG benefits). Certain regulators, such as the SEC and various state agencies, as well as nongovernmental organizations and other private actors have filed lawsuits under various securities and consumer protection laws alleging that certain ESG statements, goals or standards were misleading, false or otherwise deceptive. Additionally, certain employment practices and social initiatives are the subject of scrutiny by both those calling for the continued advancement of such policies, as well as those who believe they should be curbed, including government actors, and the complex regulatory and legal frameworks applicable to such initiatives continue to evolve. More recent political developments could mean that we face increasing criticism or litigation risks from certain “anti-ESG” parties, including various governmental agencies. Such sentiment may focus on our environmental commitments (such as reducing GHG emissions) or our pursuit of certain employment practices or social initiatives that are alleged to be political or polarizing in nature or are alleged to violate laws based, in part, on changing priorities of, or interpretations by, federal agencies or state governments. As a result, we may be subject to pressure in the media or through other means, such as governmental investigations, enforcement actions, or other proceedings, all of which could adversely affect our reputation, business, financial performance, market access and growth. Accordingly, there may be increased costs related to reviewing, implementing and managing such policies, as well as compliance and litigation risks based both on positions we do or do not take, or work we do or do not perform.

In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. While such ratings do not impact all investors’ investment or voting decisions, unfavorable ESG ratings and recent activism directed at shifting funding away from companies with energy-related assets could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our stock price and our access to and costs of capital. Additionally, to the extent ESG matters negatively impact our reputation, we may not be able to compete as effectively to recruit or retain employees, which may adversely affect our operations.

Furthermore, employment practices and social initiatives are also the subject of scrutiny by stakeholders, federal agencies, state governments, regulators and other third-parties. The complex regulatory and legal frameworks applicable to such initiatives continue to evolve. We cannot be certain of the impact of such regulatory, legal and other developments on our business. To the extent any enforcement actions or other litigation is brought against us as a result of emerging viewpoints and legal interpretations, our business, financial condition and access to financing may be materially and adversely affected.

Certain of our completion services, particularly our hydraulic fracturing services, are substantially dependent on the availability of water. Restrictions on our or our customers’ ability to obtain water may have an adverse effect on our financial condition, results of operations and cash flows.

Water is an essential component of unconventional shale oil and natural gas production during both the drilling and hydraulic fracturing processes. Over the past several years, certain of the areas in which we and our customers operate have experienced extreme drought conditions and competition for water in such areas is growing. In addition, some state and local governmental authorities have begun to monitor or restrict the use of water subject to their jurisdiction for hydraulic fracturing to ensure adequate local water supply. For instance, some states require E&P companies to report certain information regarding the water they use for hydraulic fracturing and to monitor the quality of groundwater surrounding some wells stimulated by hydraulic fracturing. Generally, our water requirements are met by our customers from sources on or near their sites, but there is no assurance that our customers will be able to obtain a sufficient supply of water from sources in these areas. Our or our customers’ inability to obtain water from local sources or to effectively utilize flowback water could have an adverse effect on our financial condition, results of operations and cash flows.

~~Risks~~Certain ~~Related~~aspects of our power generation services business are dependent on the availability of specific resources. Inability to obtain those resources could adversely impact our ~~Tax~~business. ~~Matters~~

~~Our~~Several ~~ability~~resources are essential components of certain aspects of our power generation services business. For example, water and ammonia fluids are essential to ~~use~~reciprocating engines and turbines, respectively, which are utilized in exhaust systems to meet emissions regulations. Glycol, which is utilized for gas processing equipment, is a consumable fluid used in heating baths, which regulate temperatures of other fluids used in power generation equipment, helping to ensure performance and uptime. The inability to obtain these and other key resources in the future could result in decreased performance or the inability to perform our ~~NOLs~~services ~~may~~and bemeet ~~limited~~our obligations to our customers, which would adversely impact our business and results of operations.

Risks Related to Tax Matters

Our ability to use our net operating loss carryforwards (“NOLs”) may be limited.

As of December 31, 2025, we had approximately $138.0 million of U.S. federal NOLs, all of which have an unlimited carryforward. As of December 31, 2025, our state NOLs were approximately $42.8 million, all of which are fully offset by valuation allowance.

Utilization of these NOLs depends on many factors, including our future income, which cannot be assured. In addition, Section 382 of the Internal Revenue Code of 1986, as amended (“Section 382”), generally imposes an annual limitation on the amount of taxable income that may be offset by U.S. federal NOLs when a corporation has undergone an “ownership change” (as determined under Section 382). Generally, a change of more than 50% in the ownership of a corporation’s stock, by value, over a three year period constitutes an ownership change for U.S. federal income tax purposes. Any unused annual limitation may, subject to certain limitations, be carried over to later years. We may experience ownership changes in the future as a result of shifts in our stock ownership, which may result in an annual limitation under Section 382 determined by multiplying the value of our stock at the time of the ownership change by the applicable long term tax exempt rate as defined in Section 382, which may be increased under certain circumstances as a result of recognizing built in gains in our assets existing at the time of the ownership change. Similar provisions of state tax law may also apply to limit our use of accumulated state NOLs. The limitations arising from ownership changes may prevent utilization of our NOLs prior to their expiration. Future ownership

Aschanges ofor ~~December 31,~~regulatory ~~2024,~~changes wecould ~~had~~further ~~approximately~~limit ~~$186.1~~our ~~million~~ability ofto ~~U.S.~~utilize ~~federal~~our NOLs,. ~~all~~To ofthe ~~which~~extent ~~will~~we ~~have~~are annot ~~unlimited~~able ~~carryforward.~~to Asoffset ofour ~~December 31,~~future ~~2024,~~income with our ~~state~~NOLs, ~~net~~this ~~operating~~could ~~losses~~adversely ~~were~~affect ~~approximately~~our ~~$42.8~~operating ~~million~~results and ~~will~~cash ~~begin~~flows toif ~~expire~~we inattain ~~2030~~profitability.

Utilization of these NOLs depends on many factors, including our future income, which cannot be assured. In addition, Section 382 (“Section 382”) of the Internal Revenue Code of 1986, as amended, generally imposes an annual limitation on the amount of taxable income that may be offset by NOLs when a corporation has undergone an “ownership change” (as determined under Section 382). Generally, a change of more than 50% in the ownership of a corporation’s stock, by value, over a three‑year period constitutes an ownership change for U.S. federal income tax purposes. Any unused annual limitation may, subject to certain limitations, be carried over to later years. We may experience future ownership changes, which may result in annual limitation under Section 382 determined by multiplying the value of our stock at the time of the ownership change by the applicable long‑term tax‑exempt rate as defined in Section 382, increased under certain circumstances as a result of recognizing built‑in gains in our assets existing at the time of the ownership change. The limitations arising from ownership changes may prevent utilization of our NOLs prior to their expiration. Future ownership changes or regulatory changes could further limit our ability to utilize our NOLs. To the extent we are not able to offset our future income with our NOLs, this could adversely affect our operating results and cash flows if we attain profitability.

Changes to applicable tax laws and regulations or exposure to additional tax liabilities could adversely affect our operating results and cash flows.

We are subject to various complex and evolving U.S. federal, state and local tax laws. U.S. federal, state and local tax laws, policies, statutes, rules, regulations or ordinances could be interpreted, changed, modified or applied adversely to us, in each case, possibly with retroactive effect. Any significant variance in our interpretation of current tax laws or a successful challenge of one or more of our tax positions by the Internal Revenue Service or other tax authorities could increase our future tax liabilities and adversely affect our operating results and cash flows.

Risks Inherent to an Investment in our Common Stock

We are subject to certain requirements of Section 404. If we or our auditors identify and report material weaknesses in internal control over financial reporting, our investors may lose confidence in our reported information and our stock price may be negatively affected.

We are required to comply with certain provisions of Section 404, which requires that we document and test our internal control over financial reporting and issue our management’s assessment of our internal control over financial reporting. This section also requires that our independent registered public accounting firm issue an attestation report on such internal control.

Effective internal controls are necessary for us to provide reliable financial reports and prevent fraud. If we or our auditors identify and report material weaknesses in internal controls over financial reporting or if we fail to maintain an effective system of internal controls, such instances may result in material misstatements of our financial statements, cause us to fail to meet our reporting obligations, investors may lose confidence in our financial reporting, and our stock price may decline as a result.

Certain provisions of our certificate of incorporation, and bylaws, as well as Delaware law, may discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.

Our certificate of incorporation authorizes our board of directors (the “Board”) to issue preferred stock without shareholder approval. If our Board elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our certificate of incorporation and bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our shareholders, including:

•limitations on the removal of directors;

•limitations on the ability of our shareholders to call special meetings;

•advance notice provisions for shareholder proposals and nominations for elections to the Board to be acted upon at meetings of shareholders;

•providing that the Board is expressly authorized to adopt, or to alter or repeal our bylaws; and

•establishing advance notice and certain information requirements for nominations for election to our Board or for proposing matters that can be acted upon by shareholders at shareholder meetings.

Our business could be negatively affected as a result of the actions of activist shareholders.

Publicly traded companies have increasingly become subject to campaigns by investors seeking to increase shareholder value by advocating corporate actions such as financial restructuring, increased borrowing, special dividends, stock repurchases, sales of assets or even a sale of the entire company. Given our shareholder composition and other factors, it is possible such shareholders or future activist shareholders may attempt to effect such changes or acquire control over us. Responding to proxy contests and other actions by such activist shareholders or others in the future would be costly and time-consuming, disrupt our operations and divert the attention of our Board and senior management from the pursuit of business strategies, which could adversely affect our results of operations and financial condition. Additionally, perceived uncertainties as to our future direction as a result of shareholder activism or changes to the composition of the Board may lead to the perception of a change in the direction of our business, instability or lack of continuity which may be exploited by our competitors, cause concern to our current or potential customers, and make it more difficult to attract and retain qualified personnel. If customers choose to delay, defer or reduce transactions with us or transact with our competitors instead of us because of any such issues, then our business, financial condition, revenues, results of operations and cash flows could be adversely affected.

defer or reduce transactions with us or transact with our competitors instead of us because of any such issues, then our business, financial condition, revenues, results of operations and cash flows could be adversely affected.

Our certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our shareholders, which could limit our shareholders’ ability to pursue actions in another judicial forum for disputes with us or our directors, officers, employees or agents.

Our certificate of incorporation provides that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees or agents to us or our shareholders, (iii) any action asserting a claim arising pursuant to any provision of the Delaware General Corporation Law, our certificate of incorporation or our bylaws, or (iv) any action asserting a claim against us that is governed by the internal affairs doctrine, in each such case, subject to ~~such~~the Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein.

The exclusive forum provision would not apply to suits brought to enforce any liability or duty created by the Securities Act or the Exchange Act or any other claim for which the federal courts have exclusive jurisdiction. To the extent that any such claims may be based upon federal law claims, Section 27 of the Exchange Act creates exclusive federal jurisdiction over all suits brought to enforce any duty or liability created by the Exchange Act or the rules and regulations thereunder. Furthermore, Section 22 of the Securities Act creates concurrent jurisdiction for federal and state courts over all suits brought to enforce any duty or liability created by the Securities Act or the rules and regulations thereunder.

The enforceability of similar choice of forum provisions in other companies’ certificates of incorporation or similar governing documents has been challenged in legal proceedings, and it is possible that a court could find the choice of forum provisions contained in our certificate of incorporation to be inapplicable or unenforceable, including with respect to claims arising under the U.S. federal securities laws.

Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the provisions of our certificate of incorporation regarding exclusive forum. This choice of forum provision may limit a shareholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our certificate of incorporation inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition or results of operations.

The market price of our common stock is subject to volatility.

The stock markets in general, and particularly in the past year, have experienced extreme volatility that has often been unrelated to the operating performance of particular companies. As a result, the market price of our common stock could be subject to wide fluctuations in response to, and the level of trading of our common stock may be affected by, numerous factors, many of which are beyond our control. These factors include, among other things, our limited trading volume, the concentration of holdings orof our common stock, actual or anticipated variations in our operating results and cash flow, the nature and content of our earnings releases, announcements or events that impact our products, customers, competitors or markets, business conditions in our markets and the general state of the securities markets, volatility in oil and gas prices and the market for energy-related stocks, as well as general economic and market conditions and other factors that may affect our future results, including those described ~~in this report~~herein. Significant sales of our common stock, or the expectation of these sales, by significant shareholders, officers or directors could materially and adversely affect the market price of our common stock.

31Securities class action litigation has often been instituted against companies following periods of volatility in the overall market and in the market price of a company’s securities. Such litigation, if instituted against us, could result in substantial costs, divert our management’s attention and resources and harm our business, operating results and financial condition.

There may be future sales or other dilution of our equity, which may adversely affect the market price of our common stock.

We are not restricted from issuing additional common stock, including securities that are convertible into or exchangeable for, or that represent a right to receive, common stock. In addition, we may issue common stock as consideration in future mergers and acquisitions, as we did in the ~~Silvertip~~acquisition ~~Acquisition~~of Silvertip. Any issuance of additional shares of our common stock or convertible securities will dilute the ownership interest of our common stockholders. Sales of a substantial number of shares of our common stock or other equity-related securities in the public market, or the perception that these sales could occur, could depress the market price of our common stock and impair our ability to raise capital through the sale of additional equity securities. We cannot predict the effect that future sales of our common stock or other equity-related securities would have on the market price of our common stock.

depress the market price of our common stock and impair our ability to raise capital through the sale of additional equity securities. We cannot predict the effect that future sales of our common stock or other equity-related securities would have on the market price of our common stock.

We are a party to a registration rights agreement with a subsidiary of Exxon Mobil Corporation. That agreement requires us to effect the registration of its shares of common stock in certain circumstances. Any sales of shares of our common stock by such holder, or expectations thereof, could similarly have the effect of depressing the market price of our common stock.

There can be no assurance that we will purchase all the shares authorized under our share repurchase program or that such program will enhance the long-term value of our share price.

OnIn ~~April 24,~~May ~~2024~~2025, our Board approved ana ~~increase~~further ~~and~~ extension toof the share repurchase program ~~previously~~initially authorized on May 17, 2023. ~~The~~As extended, the program permits the ~~share~~ repurchase of up to an additional $~~100~~200.0 million of the Company’s common stock ~~for~~through ~~a total of $200.0 million and extends the expiration date by one year to May~~December 31, ~~2025~~2026. There is no obligation for us to continue to repurchase or to repurchase any specific dollar amount of stock and the program may be suspended, modified or discontinued at any time without prior notice. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of our common stock, the market price of the our common stock, general market and economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The share repurchase program could affect the price of our stock and increase volatility in the market. We cannot guarantee that we will purchase all of the shares authorized under the share repurchase program or that such program will enhance the long-term value of our share price. In addition, repurchase regulations and taxes may add additional payment burden to the Company from our share repurchase program. In the past, there have been proposals to increase the amount of the U.S. federal stock repurchase excise tax from 1% to 4%,; however, it is unclear whether such a change in the amount of the excise tax will be enacted and, if enacted, how soon any such change could take effect.

If securities or industry analysts adversely change their recommendations regarding our common stock or if our operating results do not meet their expectations, our stock price could decline.

The trading market for our common stock will be influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our company or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to decline. Moreover, if one or more of the analysts who cover our company downgrades our common stock or if our operating results do not meet their expectations, our stock price could decline.

Item 1B. Unresolved Staff Comments.

None.

Item 1C. Cybersecurity.

We have established an Information Security Management System (the “ISMS”), which is integrated into our overall risk management system, to help us achieve our business goals. The ISMS defines our information security risk management approach and specifies the requirements for establishing, implementing, operating, monitoring, reviewing, maintaining and improving a risk assessment framework within the context of our overall business risks. The ISMS also specifies the requirements for implementing security controls designed to meet the needs of individual departments or parts thereof.

Risk Management and Strategy

Our cybersecurity strategy focuses on implementing controls, technologies, and other processes to assess, identify, and manage material cybersecurity risks. We have processes in place designed to assess, identify, manage, and address material cybersecurity threats and incidents, including: annual security awareness training for employees, mechanisms designed to detect and monitor unusual network activity, and containment and incident response tools. Our ISMS is designed to help us identify and manage material risks from cybersecurity threats, and as part of our ISMS, we engage a range of third-party service providers, including assessors, consultants, and auditors, to assist us in these processes. Our risk assessment framework involves an information security risk assessment procedure that helps us oversee and identify potential cybersecurity threats and vulnerabilities (including relating to the use of third-party service providers) and then determine strategies to mitigate or counter the threats. As part of this process, we aim to conduct annual penetration testing utilizing a third-party service provider. We have implemented controls designed to identify and mitigate cybersecurity threats associated with our use of third-party service providers. Such providers are subject to security risk assessments at the time of onboarding, contract renewal, and upon detection of an increase in risk profile. We use a variety of inputs in such risk assessments, including information supplied by providers and third parties. In addition, we require our providers to meet appropriate security requirements, controls and responsibilities and investigate security incidents that have impacted our third-party providers, as appropriate. Our Information Technology Director also works with third-party service providers to assess potential cybersecurity threats, ~~and~~ determines risk scores based on the likelihood of threats and the potential impacts of the threats, prioritizes risk and determines and recommends to our management controls aimed to counter such threats. We assess third-party cybersecurity controls through a cybersecurity questionnaire and aim to include security and privacy addenda to our contracts where applicable.

We also maintain procedures designed to protect the security of personally identifiable information, and our Privacy Policy provides details regarding the collection, storage, usage, and destruction of data. We require all employees to engage in data-security training upon hire and receive ongoing training thereafter. In the event of an incident, we intend to follow our incident response plan, which outlines the steps to be followed from incident detection to mitigation, recovery and notification, including notifying functional areas (e.g., legal), as well as senior leadership and the Board, as appropriate.

Governance

Management is responsible for assessing, identifying, and managing risks from cybersecurity threats. Our cybersecurity risk management ~~efforts~~and oversight are led by our Information Technology Director and our Chief Financial Officer, who ~~oversees~~are ~~our~~responsible ~~cybersecurity~~for ~~activities~~evaluating ~~and~~cybersecurity isrisks, ~~informed~~reviewing ~~about~~incident trends, and ~~monitors~~overseeing the ~~prevention,~~effectiveness ~~detection,~~of ~~mitigation~~security controls. Our current Information Technology Director and ~~remediation~~Chief ofFinancial Officer have served in our cybersecurity ~~incidents~~risk asmanagement ~~part~~and oversight function since the second half of ~~our~~fiscal ~~ISMS~~year 2025. ~~The~~Our Information Technology Director ~~reports~~brings extensive experience in information systems, cybersecurity and enterprise technology leadership. His background includes driving our digital transformation, leading the development of the Company’s modern data platform, establishing enterprise-wide data governance, and implementing analytics and core infrastructure strategies to optimize the ~~audit~~Company’s ~~committee~~business ofand ~~our~~operations. ~~Board~~He has successfully aligned technology architecture with ~~respect~~business toobjectives ~~emerging~~and ~~cybersecurity~~executed ~~incidents~~strategic ~~deemed~~technology toinitiatives. ~~have~~Our Chief Financial Officer was formerly the Chief Executive Officer of a ~~moderate~~private orcompany ~~higher~~and ~~business~~ultimately ~~impact,~~responsible ~~even~~for ifmanaging ~~immaterial~~cybersecurity torisks usin that role. Our Information Technology Director and ~~our~~ Chief Financial Officer ~~are~~operate ~~ultimately~~within ~~responsible~~established ~~for~~governance frameworks defined in the ~~implementation~~Company’s policies and supported by independent third-party assessments aligned with the U.S. National Institute of ~~our~~Standards ~~cybersecurity~~and ~~risk~~Technology ~~management~~Cybersecurity ~~processes~~Framework. ToThe ~~facilitate~~Information ~~effective~~Technology ~~oversight,~~Director ~~they~~directs ~~hold~~the ~~discussions~~information onsecurity ~~cybersecurity~~program, assesses operational risks, ~~incident~~and ~~trends~~prioritizes mitigation activities, ~~and~~while the ~~effectiveness~~Chief ofFinancial ~~cybersecurity~~Officer ~~measures~~participates asin ~~necessitated~~enterprise bylevel ~~emerging~~risk ~~cybersecurity risks~~oversight. They ~~have~~hold ~~experience~~regular ~~managing~~discussions ~~enterprises~~to ~~relying~~review onall ~~technology~~operational matters, including cybersecurity posture, emerging threats, and ~~business~~ongoing ~~systems~~initiatives. To ensure continuous improvement of the Company's cybersecurity posture, they work throughout the year with external cybersecurity experts to evaluate the Company's security maturity, monitor evolving risks, and ~~consults~~support ~~with~~the ~~trusted~~development ~~advisors~~of ~~where~~annual ~~appropriate~~cybersecurity roadmaps. The Information

Technology Director reports to the audit committee of our Board with respect to emerging cybersecurity incidents deemed to have a moderate or higher business impact, even if immaterial to us. Our Information Technology Director and our Chief Financial Officer are ultimately responsible for the implementation of our cybersecurity risk management processes.

The audit committee of our Board is responsible for oversight of risks from cybersecurity threats. The Information Technology Director presents an update on cybersecurity risk management to the audit committee of our Board during quarterly meetings and the audit committee provides relevant updates to the Board.

Impact of Risks from Cybersecurity Threats

As of the date of this report, though the Company and our service providers have experienced certain cybersecurity incidents, we are not aware of any ~~previous~~ cybersecurity incidents that have materially affected or are reasonably likely to materially affect us, including our business strategy, results of operations and financial condition. We acknowledge that cybersecurity threats are continually evolving, and the possibility of future cybersecurity incidents remains. Despite the implementation of our cybersecurity processes, our security measures cannot guarantee that a significant cybersecurity attack will not occur. While we devote resources to our security measures designed to protect our systems and information, no security measure is infallible. See Part I, “Item 1A. Risk Factors” of this Annual Report for additional information about the risks to our business associated with a breach or other compromise to our information and operational technology systems.

affect us, including our business strategy, results of operations and financial condition. We acknowledge that cybersecurity threats are continually evolving, and the possibility of future cybersecurity incidents remains. Despite the implementation of our cybersecurity processes, our security measures cannot guarantee that a significant cybersecurity attack will not occur. While we devote resources to our security measures designed to protect our systems and information, no security measure is infallible. See Part I, "Item 1A. Risk Factors" of this Annual Report for additional information about the risks to our business associated with a breach or other compromise to our information and operational technology systems.

Item 2. Properties.

Our corporate headquarters is located at ~~303~~One WMarienfeld Place, 110 N. ~~Wall~~Marienfeld Street, Suite ~~102~~300, Midland, Texas 79701. In addition to our headquarters, we also own and lease other properties that are used for field offices, yards, or storage in the Permian Basin. We believe that our facilities are adequate for our current operations.

Item 3. Legal Proceedings.

Disclosure concerning legal proceedings is incorporated by reference to "“Note 18. Commitments and Contingencies— Contingent Liabilities"” of our Consolidated Financial Statements contained in this Annual Report.

From time to time, we may be subject to various other legal proceedings and claims incidental to or arising in the ordinary course of our business.

Item 4. Mine ~~and~~ Safety Disclosures.

None.

PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities.

Market Information

On March 22, 2017, we consummated our initial public offering of our common stock at a price of $14.00 per share. Our common stock is traded on the New York Stock Exchange under the symbol "“PUMP."”

Holders

As of December 31, ~~2024~~2025, there were ~~102~~104,~~994~~310,~~958~~266 shares of common stock outstanding, held of record by ~~five~~seven holders. The number of record holders of our common stock does not include Depository Trust Company participants or beneficial owners holding shares through nominee names.

Dividends

We do not anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to finance the growth of our business and repay borrowings under our ABL Credit Facility, ifour Caterpillar Equipment Loan Agreement and any other financing arrangements. Our future dividend policy is within the discretion of our Board and will depend upon then‑existing conditions, including our results of operations, financial condition, capital requirements, investment opportunities, statutory restrictions on our ability to pay dividends and other factors ~~our Board may deem relevant. In addition, our ABL Credit Facility places certain restrictions on our ability to pay cash dividends.~~

our Board may deem relevant. In addition, our ABL Credit Facility places certain restrictions on our ability to pay cash dividends.

Share Repurchase Program

The following sets forth information with respect to our repurchases of shares of common stock during the three months ended December 31, ~~2024~~2025:

Period	Total number of shares purchased	Average price paid per share ~~(2)~~		Total number of shares purchased as part of publicly announced plans or programs (1)	Approximate dollar value of shares that may yet be purchased under the plans or programs (1)
October 1, 2024 to October 31, 2024	353,171	$	8.15	353,171	$	89,654,253
October 1, 2025 to October 31, 2025	—	$	—	—	$	89,152,858
November 1, 2024 to November 30, 2024	70,305	$	7.13	70,305	$	89,152,858
November 1, 2025 to November 30, 2025	—	$	—	—	$	89,152,858
December 1, 2024 to December 31, 2024	—	$	—	—	$	89,152,858
December 1, 2025 to December 31, 2025	—	$	—	—	$	89,152,858
Total	~~423,476~~—	$	~~7.98~~—	~~423,476~~—	$	89,152,858

(1)OnIn ~~April~~May 242025, ~~2024,~~ the Board approved ana ~~increase~~further ~~and~~ extension of the share purchase program ~~previously~~initially authorized on May 17, 2023. ~~The~~As extended, the program permits the repurchase of up to ~~an additional~~ $~~100~~200 million of the Company’s common stock ~~for~~through aDecember ~~total of $200 million and extends the expiration date by one year to May~~ 31, ~~2025~~2026. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, privately negotiated transactions, derivative transactions or otherwise, certain of which may be made pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Exchange Act, as amended, in compliance with applicable state and federal securities laws.

(2)The average price paid per share includes commissions.

Performance Graph

The annual changes for the periods shown in the following graph are based on the assumption that $100 had been invested in our common stock, the Russell 2000 Index (“Russell 2000”) and a self-constructed peer group index of comparable companies (“~~Updated~~ Peer Group”) on December 31, ~~2019~~2020, and that all dividends were reinvested at the closing prices of the dividend payment dates. The relevant companies included in our ~~Updated~~ Peer Group consists of Liberty Energy Inc., Patterson-UTI Energy, Inc., RPC, Inc., Calfrac Well Services Ltd., Mammoth Energy Services, Inc. and ProFrac Holding Corp. ~~(added in 2024). We have also included our previous peer group (“Former Peer Group”) which did not include ProFrac Holding Corp. in the following graph.~~ The total cumulative dollar returns shown onin the graph represent the value that such investments would have had on the last trading date of ~~2024~~2025. The calculations exclude trading commissions and taxes. The stock price performance on the following graph and table is not necessarily indicative of future stock price performance.

Date	~~Former~~ Peer Group		~~Updated~~Russell ~~Peer Group~~2000		~~Russell~~ProPetro ~~2000~~Holding Corp.		~~ProPetro Holding Corp.~~
12/31/2019	$	100.0	$	100.0	$	100.0	$	100.0
12/31/2020	$	100.0	$	100.0	$	100.0
12/31/2020	$	64.1	$	64.1	$	120.0	$	65.7
12/31/2021	$	125.4	$	114.8	$	109.6
12/31/2021	$	80.3	$	80.3	$	137.7	$	72.0
12/31/2022	$	239.1	$	91.4	$	140.3
12/31/2022	$	153.1	$	153.1	$	109.6	$	92.2
12/31/2023	$	166.2	$	106.8	$	113.4
12/31/2023	$	130.0	$	106.4	$	128.1	$	74.5
12/31/2024	$	149.5	$	119.1	$	126.3
12/31/2024	$	116.6	$	95.7	$	142.9	$	82.9
12/31/2025	$	124.4	$	134.4	$	128.7

Item 6. [Reserved]

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

You should read the following discussion and analysis of our financial condition and results of operations together with our audited consolidated financial statements and the related notes included in this Annual Report. Some of the information contained in this discussion and analysis or set forth elsewhere in this Annual Report, including information with respect to our plans and strategy for our business and related financing, includes forward‑looking statements that involve risks and uncertainties. You should read the "Risk Factors" section of this Annual Report for a discussion of important factors that could cause actual results to differ materially from the results described in or implied by the forward‑looking statements contained in the following discussion and analysis.

Basis of Presentation

This discussion of our results omits our results of operations and cash flows for the year ended December 31, ~~2022~~2023, and the comparison of our results of operations for the years ended December 31, ~~2023~~2024, and ~~2022~~2023, which may be found in our Annual Report on Form 10-K for the year ended December 31, ~~2023~~2024, filed with the SEC on ~~March~~February 1320, ~~2024~~2025.

Unless otherwise indicated, references in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” to “ProPetro Holding Corp.,” “the Company,” “we,” “our,” “us” or like terms refer to ProPetro Holding Corp. and its subsidiaries.

Overview

Our Business

We are a leading integrated energy service company, located in Midland, Texas, focused on providing innovative hydraulic fracturing, wireline and other complementary energy and power generation services to leading upstream oil and gas companies engaged in the exploration and production (“E&P”) of North American oil and natural gas resources. Our operations are primarily focused in the Permian Basin, where we have cultivated longstanding customer relationships with some of the region’s most active and well‑capitalized E&P companies. The Permian Basin is widely regarded as one of the most prolific oil‑producing areas in the United States, and we believe we are one of the leading providers of completion services in the region.

Our completion services includes our operating segments comprised of hydraulic fracturing, wireline and cementing operations. Our hydraulic fracturing operations account for approximately 7573.62% of our total revenues and operations. Our total available hydraulic horsepower (“HHP”) at December 31, ~~2024~~2025, was 1,~~556~~259,500 HHP, which was comprised of ~~450~~445,000 HHP of our Tier IV Dynamic Gas Blending (“DGB”) dual-fuel equipment, ~~294~~312,000 HHP of FORCE® electric-powered equipment and ~~812~~502,500 HHP of conventional Tier II equipment. Our hydraulic fracturing fleets range from approximately 50,000 to 80,000 HHP depending on the job design and customer demand at the wellsite. Our equipment has been designed to handle the operating conditions commonly encountered in the Permian Basin and the region’s increasingly high-intensity well completions (including simultaneous hydraulic fracturing ("Simul-Frac"), which involves fracturing multiple wellbores at the same time), which are characterized by longer horizontal wellbores, more stages per lateral and increasing amounts of proppant per well. With the industry transition to lower emissions equipment and Simul-Frac, in addition to several other changes to our customers' job designs, we believe that our available fleet capacity could decline if we decide to reconfigure our fleets to increase active HHP and backup HHP at wellsites. In ~~addition, in~~ 2021 ~~and 2022~~, we ~~committed~~began to ~~additional~~transition ~~conversions of~~ our ~~Tier~~fleet IIfrom traditional equipment to Tier IV DGB, ~~and to purchase new Tier IV DGB~~ dual-fuel equipment. As such, we entered into conversion and purchase agreements with our equipment manufacturers and have received all of the converted and new Tier IV DGB dual-fuel equipment by the end of 2023, representing 450,000 HHP of our Tier IV DGB dual-fuel equipment as of December 31, 2024. In 2022, we entered into three-year electric fleet leases which commenced in 2023 and 2024 for four FORCE® electric-powered hydraulic fracturing fleets worth of equipment with 60,000 HHP per fleet and in ~~June~~ 2024, we entered into an additional three-year lease for aone ~~fifth~~more FORCE® electric-powered hydraulic fracturing fleet worth of equipment with 72,000 HHP (collectively the “Electric Fleet Leases”). As of December 31, ~~2024~~2025, we have received ~~294~~312,000 HHP of FORCE® electric-powered equipment representing ~~four~~five fleets ~~and~~worth ~~a portion~~ of ~~the fifth fleet. We currently expect to receive the remaining~~ equipment ~~associated with the fifth fleet in the first half of 2025~~.

In ~~the~~December ~~fourth quarter of~~ 2024, we formed a new subsidiary, ProPetro Energy Solutions, LLC, (“PROPWR”), towhich ~~provide~~provides turnkey power generation services to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers using mobile power generation equipment installed at customers’ sites. This subsidiary began revenue-generating activities during the third quarter of fiscal year 2025 and has ~~ordered~~entered into contractual arrangements with equipment manufacturers to purchase mobile natural gas-fueled power generation equipment, ~~but~~including itturbine ~~has~~generator ~~not~~sets, ~~yet~~reciprocating ~~begun~~engines, ~~revenue~~auxiliary equipment and battery energy storage solution equipment. As of February 19, 2026 we had total committed capacity of approximately 240 megawatts and total delivered or on-~~generating~~order ~~activities~~generation capacity of approximately 550 megawatts, split approximately 70% and 30% between high-efficiency reciprocating engine generators and low emissions modular turbines, respectively. We anticipate all ordered units will be delivered by year-end 2027. We continue to actively

~~secured~~negotiate byadditional ~~substantially~~contracts ~~all~~amid ~~assets~~increasing ofdemand ~~the~~for ~~former~~power ~~employee’s~~solutions ~~business~~ and ~~the former employee’s ownership interests in and distributions from the business. The note receivable is~~ to beexplore ~~paid~~various tofinancing ~~the~~alternatives ~~Company~~for in quarterly installments with interest of 10% per annum from March 31, 2025, to December 31, 2029. We recorded a gain on disposal of $8.2 million related to the sale of the business. The former employee was part of our ~~cementing~~power ~~operations until November 1, 2024, and is no longer affiliated with the Company~~equipment.

On November 1, 2024, we sold our cementing business located in Vernal, Utah, to a business owned by a former employee as part of a strategic repositioning. We received a promissory note for $13.0 million as consideration, and recorded a gain on disposal of $8.2 million related to the sale of the business. The note receivable was secured by substantially all assets of the divested operations and the former employee’s ownership interests in and distributions from the business. The note receivable was to be paid to the Company in quarterly installments with interest of 10% per annum from March 31, 2025, to December 31, 2029, but was fully repaid with interest in December 2025. The former employee was part of our cementing operations until November 1, 2024, and is no longer affiliated with the Company.

On May 31, 2024, we consummated the acquisition of all of the outstanding equity interests in Aqua Prop, LLC (“AquaProp”), which provides wet sand solutions for hydraulic fracturing sand requirements at oil well sites (the “AquaProp Acquisition”). The cash consideration for the AquaProp Acquisition includes $13.7 million paid to the seller, $7.2 million paid to settle the seller’s outstanding debt, and $0.3 million paid for the seller’s transaction expenses. As a result of the AquaProp Acquisition, we expanded our operations into the wet sand service business unit.

On December 1, 2023, we consummated the purchase of the assets and operations of Par Five Energy Services LLC (“Par Five”), which provides cementing services in the Delaware Basin, in exchange for $25.4 million of cash, including deferred cash consideration of $3.1 million which is payable to Par Five or its beneficiary on June 1, 2025, with interest of 4.0% per annum (the “Par Five Acquisition”). The Par Five Acquisition complemented our existing cementing business and enabled us to serve both the Midland and Delaware sub-basins of the Permian Basin.

On November 1, 2022, we consummated the acquisition of all of the outstanding limited liability company interests of Silvertip Completion Services Operating, LLC (the “Silvertip Acquisition”), which provides wireline perforation and ancillary services in the Permian Basin in exchange for 10.1 million shares of our common stock valued at $106.7 million, $30.0 million of cash, the payoff of $7.2 million of assumed debt, and the payment of certain other closing and transaction costs. At December 31, 2024, we had 26 wireline units available to provide wireline perforation and ancillary services. Collectively, the AquaProp Acquisition, the Par Five Acquisition and the Silvertip Acquisition have positioned the Company as a more integrated and diversified completions-focused energy service provider. See Note 4. Business Acquisitions in the financial statements for additional disclosures.

We believe that our substantial market presence in the Permian Basin positions us well to capitalize on drilling and completion activity in the region. Primarily, our operational focus has been in the Permian Basin's Midland sub-basin, where our customers have operated. However, we have increased our operations in the Delaware sub-basin and are well-positioned to support further increases to our activity in this area in response to demand from our customers. Over time, we expect the Permian Basin's Midland and Delaware sub-basins to continue to command a disproportionate share of future North American E&P spending.

WeAs ~~have~~of ~~historically~~December 31, 2025, we conducted our business through four operating segments: ~~hydraulic~~Hydraulic ~~fracturing~~Fracturing, ~~wireline~~Wireline, ~~cementing~~Cementing and ~~coiled~~Power ~~tubing.~~Generation, ~~Prior~~all ~~to the fourth quarter~~ of ~~fiscal~~which ~~year~~meet ~~2023, our operating segments met~~ the ~~aggregation~~ criteria ~~and~~of ~~were~~a ~~aggregated into the “Completion Services”~~ reportable segment ~~and our coiled tubing operations (which were divested in September 2022) were shown in the “All Other” category~~. ~~Effective~~Prior into the ~~the~~third ~~fourth~~ quarter of fiscal year ~~2023~~2025, weour ~~revised~~Power ~~our~~Generation segment ~~reporting~~did asnot wemeet ~~determined~~the ~~that~~quantitative ~~our~~thresholds ~~three~~for ~~operating~~a ~~segments~~reportable nosegment ~~longer~~and ~~met~~prior ~~the criteria~~ to ~~be aggregated. In~~ the fourth quarter of fiscal year 2024, weour ~~formed~~Cementing ~~PROPWR~~segment todid ~~provide~~not ~~power~~meet ~~generation~~the ~~services~~quantitative tothresholds ~~oil~~for ~~and~~a ~~gas~~reportable ~~producers~~segment. ~~and~~Accordingly, ~~non-oil~~they ~~and~~were ~~gas~~shown ~~applications~~in ~~such~~the as“All ~~general~~Other” ~~industrial projects and data centers~~category. ~~This~~Effective ~~new~~as ~~subsidiary~~of ~~has~~the ~~ordered~~third ~~equipment,~~quarter ~~but~~of itfiscal ~~has~~year ~~not~~2025 ~~yet begun revenue-generating activities. Our hydraulic fracturing, wireline~~ and ~~cementing operating segments meet~~ the ~~criteria~~fourth quarter of afiscal ~~reportable~~year ~~segment.~~2024, ~~Our~~Power ~~divested~~Generation ~~coiled tubing~~ and ~~our~~Cementing, ~~newly~~respectively, ~~formed~~are ~~power~~shown ~~generation~~as ~~services~~reportable segments dosince ~~not~~they meet the ~~reportable segment~~ criteria ~~and~~of ~~are~~a ~~included~~reportable ~~within the “All Other” category~~segment. Additionally, our corporate administrative activities do not involve business activities from which it may earn revenues and its results are not regularly reviewed by the Company’s Chief Operating Decision Maker (the “CODM”) when making key operating and resource decisions. As a result, corporate administrative expenses have been included under “Reconciling Items.” For additional financial information on our reportable segments presentation, please see reportable segment information in Part II - Item 8, “Financial Statements and Supplementary Data.”

Pioneer Pressure Pumping Acquisition

On December 31, 2018, we consummated the purchase of certain pressure pumping assets and real property from Pioneer Natural Resources USA, Inc. (“Pioneer”) and Pioneer Pumping Services, LLC in the Pioneer Pressure Pumping Acquisition in exchange for 16.6 million shares of our common stock and $110.0 million in cash. In May 2024, Pioneer merged with and into a wholly owned subsidiary of ExxonMobil after which ExxonMobil became the owner of these shares. The Company currently provides pressure pumping, wireline and other services to ExxonMobil and previously provided such services to Pioneer.

On April 22, 2024, we entered into a sub-agreement for hydraulic fracturing services with XTO, a wholly owned subsidiary of ExxonMobil, pursuant to which we will provide hydraulic fracturing, wireline and pumpdown services with two committed FORCE® electric-powered hydraulic fracturing fleets and the option to add a third FORCE® fleet (also with wireline and pumpdown services) for a certain number of contracted hours with respect to each fleet, subject to certain termination and release rights. This agreement will expire in approximately late 2026. At this time, we do not expect such agreement to be renewed or extended and, if we are not able to procure additional work from XTO, we will be required to redeploy the equipment associated with the affected fleets with other customers.

Commodity Price and Other Economic Conditions

The geopolitical and macroeconomic consequences of military action in the Middle East, the Russian invasion of Ukraine, including the associated sanctions, and ~~the~~actions ~~adverse~~taken ~~impacts~~by of the ~~COVID-19~~Organization ~~pandemic~~of ~~have~~the ~~resulted~~Petroleum inExporting ~~volatility~~Countries in(“OPEC”) ~~supply~~ and ~~demand~~Russia ~~dynamics~~(together ~~for~~with ~~crude~~OPEC ~~oil~~ and ~~associated~~other ~~volatility~~allied inproducing ~~crude~~countries, ~~oil~~“OPEC+”) ~~pricing.~~have Ascontributed ~~the global response~~ to ~~the~~volatility ~~COVID-19~~in ~~pandemic~~supply ~~began~~and ~~to wane, the~~ demand ~~and~~dynamics ~~prices~~ for crude oil ~~increased~~and ~~from~~associated ~~the~~volatility ~~lows experienced~~ in ~~2020, with the WTI average~~ crude oil ~~price~~pricing ~~reaching approximately $94 per barrel~~ in ~~2022,~~recent ~~the highest average price in the prior ten~~ years. ~~However~~More recently, the WTI average crude oil price declined to approximately $7865 per barrel in ~~2023~~2025 ~~and~~compared to approximately $76 per barrel in 2024. Wein ~~believe~~response ~~that~~to ~~the~~tariff ~~volatility~~policies ofimplemented ~~crude~~by ~~oil~~the ~~prices~~United inStates ~~recent~~government, ~~years~~an ~~has~~anticipated ~~been~~increase ~~partly~~in ~~driven~~global bysupply ~~declines~~of in crude oil ~~supplies,~~and concerns ~~over~~of ~~sanctions~~a potential global recession resulting from ~~Russia's~~high ~~invasion~~inflation, ofinterest ~~Ukraine~~rates, ~~concerns~~impacts ~~over~~of atariff ~~potential~~policies ~~disruption~~on ofsupply ~~Middle~~chains ~~Eastern~~and ~~oil~~increased ~~supplies~~costs ~~resulting~~as ~~from~~whole. ~~the~~Additionally, ~~conflict~~we inhave ~~the~~recently ~~Middle~~experienced ~~East,~~a ~~slower~~decrease ~~crude~~in ~~oil~~the ~~production~~Permian ~~growth~~Basin ~~due~~rig count to 304 at the ~~lack~~end of ~~reinvestment~~2024 ~~in the oil~~ and ~~gas~~a ~~industry~~further indecrease ~~the~~to ~~last~~247 ~~three~~at ~~years,~~ the ~~extension~~end of ~~OPEC+~~2025, ~~production~~according ~~cuts~~to ofthe ~~approximately~~Baker ~~3.9~~Hughes ~~million~~Company ~~barrels~~(“Baker ~~per~~Hughes”), ~~day~~which ~~originally~~resulted ~~announced~~ in ~~2023,~~a ~~and~~reduction ~~concerns~~in ofthe ademand ~~potential~~for ~~global~~completion ~~recession~~services ~~resulting~~and ~~from~~pressure ~~high~~on ~~inflation~~pricing ~~and~~of ~~interest~~our ~~rates~~services.

~~With~~Sustained levels of high inflation likewise caused the ~~significant~~U.S. ~~increase~~Federal inReserve ~~global~~and ~~crude~~other ~~oil~~central ~~prices~~banks ~~from~~to ~~2021~~increase interest rates, ~~including~~and to the ~~WTI~~extent ~~crude~~elevated ~~oil~~inflation ~~price~~remains, ~~there~~we ~~was~~may aexperience ~~significant~~further ~~increase~~cost inincreases ~~the~~for ~~Permian~~our ~~Basin~~operations, ~~rig~~including ~~count~~interest ~~from~~rates, ~~approximately~~labor ~~179~~costs atand ~~the~~equipment. ~~beginning~~We ofcannot ~~2021~~predict toany ~~approximately~~future ~~353~~trends atin the ~~end~~rate of ~~2022,~~inflation ~~according~~and tocrude ~~the~~oil ~~Baker Hughes~~prices. ~~Following~~A ~~the~~significant increase in ~~rig~~or ~~count~~continued ~~and~~high ~~the~~levels ~~WTI~~of ~~crude oil price~~inflation, to the ~~energy~~extent ~~service~~we ~~industry~~are ~~has~~unable ~~experienced~~to ~~increased~~timely ~~demand~~pass-through ~~for~~the ~~its~~cost ~~completion~~increases ~~services,~~to ~~and~~our ~~improved pricing. However~~customers, ~~the~~further ~~Permian~~declines ~~Basin~~in ~~rig~~crude ~~count~~oil ~~experienced~~prices, aor ~~13%~~potential ~~decrease~~changes in ~~2023~~the toUnited ~~309~~States’ attrade policy, including the ~~end~~imposition of ~~2023~~tariffs and ~~further~~the ~~decreased~~resulting toconsequences, ~~304~~would atnegatively ~~the~~impact ~~end~~our ofbusiness, ~~2024~~financial ~~which~~condition ~~resulted~~and inresults aof ~~reduction~~operations. inSee ~~the~~Part ~~demand~~II, ~~for~~Item ~~completion~~1A. ~~services~~“Risk ~~and~~Factors—We ~~pressure~~may onbe ~~pricing~~adversely ofaffected ~~our~~by ~~services~~the effects of inflation.”

~~Sustained~~Government ~~levels~~regulations ofand ~~high~~investors ~~inflation~~are ~~likewise~~demanding ~~caused~~ the ~~U.S.~~oil ~~Federal Reserve~~ and ~~other~~gas ~~central~~industry ~~banks~~transition to ~~increase~~a ~~interest~~lower ~~rates~~emissions operating environment, including upstream and toenergy ~~the~~service ~~extent~~companies. ~~elevated~~As ~~inflation~~a ~~remains~~result, we ~~may~~are ~~experience~~working ~~further~~with ~~cost~~our ~~increases~~customers ~~for~~and equipment manufacturers to transition our ~~operations,~~equipment ~~including~~into ~~interest~~a ~~rates~~lower emissions profile. Currently, ~~labor~~a ~~costs~~number ~~and~~of lower emission solutions for pumping equipment., Weincluding ~~cannot~~Tier ~~predict~~IV ~~any~~DGB ~~future~~dual-fuel, ~~trends~~FORCE® inelectric, ~~the~~direct ~~rate~~drive ofgas ~~inflation~~turbine and ~~crude~~other ~~oil~~technologies ~~prices.~~have Abeen ~~significant~~developed, ~~increase~~and inwe orexpect ~~continued~~additional ~~high~~lower ~~levels~~emission ofsolutions ~~inflation,~~will tobe developed in the ~~extent~~future. weWe are ~~unable~~continually toevaluating ~~timely~~these ~~pass-through~~technologies ~~the~~and ~~cost~~other ~~increases~~investment toand acquisition opportunities that would support our ~~customers,~~existing ~~further~~and ~~declines~~new incustomer ~~crude~~relationships. ~~oil~~The ~~prices,~~transition orto ~~potential~~lower ~~change~~emissions inequipment Uis quickly evolving and will be capital intensive.S ~~trade~~Over ~~policy~~time, ~~including~~we ~~the~~may ~~imposition~~be required to convert substantially all of ~~tariffs~~our ~~and~~conventional ~~the~~Tier ~~resulting~~II ~~consequences,~~equipment ~~would~~to ~~negatively~~lower ~~impact~~emissions equipment. To the extent any of our ~~business,~~customers ~~financial~~have ~~condition~~certain ~~and~~expectations ~~results~~or ofrequirements ~~operations.~~with ~~See~~respect ~~Part~~to IIemissions reductions from their contractors, ~~Item~~if ~~1A.~~we ~~“Risk~~are ~~Factors—We~~unable ~~may~~to becontinue ~~adversely~~quickly ~~affected~~transitioning byto lower emissions equipment, the ~~effects~~demand offor ~~inflation~~our services could be adversely impacted.”

~~Government~~If ~~regulations~~the ~~and~~Permian ~~investors~~Basin ~~are~~rig ~~demanding~~count ~~the oil~~ and ~~gas~~market ~~industry~~conditions ~~transition to a lower emissions operating environment~~improve, including ~~upstream~~improved ~~and~~pricing ~~energy~~for ~~service companies. As a result, we are working with~~ our ~~customers~~services and ~~equipment~~labor ~~manufacturers to transition our equipment to a lower emissions profile. Currently~~availability, ~~a number of lower emission solutions for pumping equipment, including Tier IV DGB dual-fuel, FORCE® electric, direct drive gas turbine~~ and ~~other technologies have been developed, and~~ we ~~expect additional lower emission solutions will be developed in the future. We~~ are ~~continually~~able ~~evaluating~~to ~~these~~meet ~~technologies and other investment and acquisition opportunities that would support~~ our ~~existing~~customers' ~~and new customer relationships. The transition to~~ lower emissions equipment ~~is quickly evolving and will be capital intensive. Over time~~demands, we ~~may~~believe ~~be required to convert substantially all of~~ our ~~conventional~~operational ~~Tier~~and IIfinancial ~~equipment~~results towill ~~lower~~also ~~emissions equipment~~improve. WeIf ~~have~~the ~~transitioned~~rig ~~our~~count ~~hydraulic~~or ~~fracturing~~market ~~available~~conditions ~~equipment~~do ~~portfolio~~not ~~from~~improve ~~approximately~~or ~~10%~~decline ~~lower emissions equipment~~ in ~~2021~~the ~~to approximately 35% in 2022~~future, ~~60%~~and inwe ~~2023,~~are ~~70%~~unable ~~in 2024, and expect~~ to increase ~~to approximately 75% by the end of the first quarter of 2025. To the extent any of~~ our ~~customers~~pricing ~~have certain expectations~~ or ~~requirements~~pass-through ~~with~~future ~~respect~~cost increases to ~~emissions~~our ~~reductions from their contractors~~customers, ifthere wecould ~~are~~be ~~unable~~a tomaterial ~~continue~~adverse ~~quickly~~impact ~~transitioning~~on toour ~~lower emissions equipment~~business, ~~the~~results ~~demand~~of ~~for~~operations ~~our~~and ~~services~~cash ~~could be adversely impacted~~flows.

IfOur ~~the~~results ~~Permian~~of ~~Basin~~operations ~~rig~~have ~~count~~historically ~~and~~reflected ~~market~~seasonal ~~conditions improve~~tendencies, ~~including~~typically ~~improved~~in ~~pricing~~the ~~for~~fourth ~~our~~quarter, ~~services~~relating ~~and~~to ~~labor~~the ~~availability~~holiday season, ~~and~~inclement wewinter ~~are~~weather ~~able~~and tothe ~~meet~~exhaustion of our customers' ~~lower~~annual ~~emissions~~budgets. ~~equipment~~As ~~demands~~a result, we ~~believe~~typically experience declines in our ~~operational~~operating and financial results in November and December, even in a stable commodity price and operations environment.

~~financial~~2025 ~~results~~Operational will also continue to improve. If the rig count or market conditions do not improve or decline in the future, and we are unable to increase our pricing or pass-through future cost increases to our customers, there could be a material adverse impact on our business, results of operations and cash flows.Highlights

~~Our~~Over ~~results of operations have historically reflected seasonal tendencies, typically in~~ the ~~fourth~~course ~~quarter,~~of ~~relating to~~ the ~~holiday~~year ~~season,~~ended ~~inclement winter weather and exhaustion of our customers' annual budgets. As a result, we typically experience declines in our operating and financial results in November and~~ December 31, ~~even in a stable commodity price and operations environment.~~2025:

~~2024~~•we ~~Operational~~maintained ~~Highlights~~operational and financial stability during a challenging operating environment faced by the broader energy markets and the completions market in the Permian Basin through our disciplined approach to cost and fleet management and focusing on consistent performance;

~~Over~~•our active hydraulic fracturing fleet count declined from 15 active fleets at the ~~course~~beginning of the year ~~ended~~to ~~December 31~~11 at the end of the year as we idled certain fleets to preserve them for more favorable market conditions, ~~2024:~~rather than run them at sub-economic levels; and

•we secured contracts with multiple customers for our PROPWRSM power generation business and deployed ~~two~~our ~~FORCE®~~first ~~electric-powered~~mobile ~~hydraulic~~power ~~fracturing~~generation ~~fleets~~equipment ~~with~~in athe field during the third quarter of fiscal year 2025 and ended the year with total delivered or on-order generation capacity of ~~120~~approximately 550 megawatts,~~000~~ ~~HHP~~split approximately 70% and 30% between high-efficiency reciprocating engine generators and low emissions modular turbines, respectively. ~~Four~~We ~~FORCE®~~anticipate ~~electric~~all ordered units will be delivered by year-~~powered~~end ~~hydraulic~~2027. ~~fracturing~~As ~~fleets~~of ~~are~~February ~~now~~19, ~~operating~~2026, ~~under~~we ~~contract~~had ~~with~~total ~~leading~~committed ~~customers;~~capacity of approximately 240 megawatts.

~~•our~~2025 ~~available~~Financial ~~equipment portfolio is expected to be comprised of approximately 75% lower emissions (FORCE® electric and Tier IV DGB dual-fuel), and 25% conventional diesel equipment by the end of 2025;~~Highlights

~~•despite~~Financial ~~market~~highlights ~~volatility,~~for ~~our~~the ~~average~~year ~~active~~ended ~~hydraulic fracturing fleet count was approximately 14 fleets~~December 31, ~~a decrease from 15 active fleets in 2023;~~2025:

•wenet ~~published~~income ~~our~~was ~~second~~$0.8 ~~annual~~million, ~~sustainability~~compared ~~report~~to net loss of $137.9 million for the year ended December 31, ~~which~~2024. ~~describes~~Diluted ~~our~~net ~~commitment~~income per common share was $0.01, compared to ~~building~~diluted anet ~~sustainable~~loss ~~business~~of ~~that~~$1.31 ~~supports~~for the ~~safe~~year ended December 31, ~~reliable~~2024. ~~production~~Net ofloss for the ~~energy~~year ~~the~~ended ~~world~~December 31, ~~needs~~2024 byincluded ~~offering~~property ~~competitive,~~and ~~value~~equipment impairment expense of $188.6 million related to our conventional Tier II diesel-~~driving~~only ~~services~~hydraulic fracturing pumping units and associated conventional assets (“Tier II Units”) and goodwill impairment expense of $23.6 million related to ~~customers,~~the ~~while~~goodwill ~~benefitting~~in our ~~shareholders~~Wireline operating segment. Adjusted EBITDA of approximately $208.4 million decreased 26.4%, ~~communities~~compared to $283.2 million for the year ended December 31, ~~and~~2024 ~~other~~(see ~~stakeholders~~reconciliation of Adjusted EBITDA to net income in the subsequent section “How We Evaluate Our Operations”);

•wecapital ~~consummated~~expenditures ~~the~~incurred ~~purchase~~increased ofto ~~all~~$281.2 ofmillion, ~~the~~an ~~outstanding~~increase ~~equity~~of ~~interests~~111% inas ~~AquaProp~~compared onto ~~May~~2024. ~~31,~~Capital ~~2024,~~expenditures ~~which~~incurred ~~provides~~included ~~wet~~$198.4 ~~sand~~million ~~solutions~~related ~~for~~to ~~hydraulic~~equipment ~~fracturing~~orders ~~sand~~for ~~requirements~~our atPower ~~oil~~Generation ~~well~~operating ~~sites~~segment; ~~and~~

•wesecured ~~formed~~a ~~PROPWR~~financing inarrangement ~~the~~with ~~fourth~~Caterpillar ~~quarter~~Financial ofServices ~~2024,~~Corporation to(“Caterpillar”) ~~provide~~for ~~power~~a ~~generation~~maximum ~~services~~total toavailable ~~oil~~amount ~~and~~of ~~gas producers and non-oil and gas applications such as general industrial projects and data centers~~$103.7 ~~This~~million ~~subsidiary~~to ~~has~~support ~~ordered~~the ~~equipment,~~purchase ~~but~~of ~~has~~certain ~~not~~natural ~~yet~~gas-fueled ~~begun~~power ~~revenue-generating~~generation ~~activities.~~equipment;

~~2024~~•secured ~~Financial~~a ~~Highlights~~lease facility described in “Note 17. Leases” with Stonebriar Commercial Finance LLC for the right, but not the obligation, to fund up to $350.0 million of purchases of power generator equipment;

~~Financial~~•net ~~highlights~~cash ~~for~~provided ~~the~~by ~~year~~operating ~~ended~~activities ~~December 31,~~less net cash used in investing activities declined by $15.4 million compared to 2024:; and

•~~net~~our ~~loss~~total liquidity was $~~137~~205.94 million, ~~compared~~as ~~to net income~~ of ~~$85.6 million for the year ended~~ December 31, ~~2023~~2025. ~~Diluted~~consisting ~~net~~of ~~loss~~cash ~~per~~and ~~common~~cash ~~share~~equivalents ~~was $1.31, compared to diluted net income~~ of $091.763 ~~for~~million ~~the year ended December 31, 2023. Net loss for included property~~ and ~~equipment~~remaining ~~impairment~~availability ~~expense~~ of $~~188~~114.61 million ~~related~~under to our ~~conventional~~ABL ~~Tier~~Credit IIFacility; ~~diesel-only~~we ~~hydraulic~~had ~~fracturing~~total ~~pumping~~outstanding ~~units~~debt ~~and associated conventional assets and goodwill impairment expense~~ of $23122.6 million ~~related~~as toof ~~the~~December 31, ~~goodwill~~2025, incomprising ~~our~~of ~~wireline operating segment~~$45.0 ~~Adjusted~~million ~~EBITDA~~ of ~~approximately~~borrowings ~~$283.2~~under ~~million~~our ~~decreased~~ABL ~~29.9%,~~Credit ~~compared~~Facility toand $~~404~~77.06 million ~~for the year ended December 31, 2023 (see reconciliation~~ of ~~Adjusted~~equipment ~~EBITDA~~financing tointerim ~~net~~and ~~income~~term inloans under the ~~subsequent~~Caterpillar ~~section~~Equipment ~~“How~~Loan WeAgreement ~~Evaluate~~(as ~~Our~~defined ~~Operations”~~below);.

~~•capital~~Recent ~~expenditures were reduced to $133.4 million or 57% as compared to 2023;~~Developments

~~•net~~In ~~cash~~January ~~provided~~2026, bythe ~~operating~~Company ~~activities~~sold ~~less~~17.3 ~~net~~million ~~cash~~shares ~~used~~of its common stock in ~~investing~~an ~~activities~~underwritten ~~improved~~public byoffering for $~~106~~10.600 per share, pursuant to an effective shelf registration statement on Form S-3 filed with the SEC, including shares sold pursuant to the option granted to the underwriters to purchase up to an additional 2.3 million ~~compared~~shares of our common stock (the “2026 Common Stock Offering”). The Company received approximately $163.3 million in net proceeds from this sale after deducting underwriting discounts and commissions and estimated offering expenses. The Company intends to ~~2023;~~use the net proceeds from this sale for general corporate purposes, including to fund growth capital for additional power generation equipment.

•our accounts receivable to accounts payable ratio increased to 2.1 from 1.5. Working capital (current assets less current liabilities) increased to $70.0 million from $39.7 million;

•our total liquidity was $160.9 million as of December 31, 2024. consisting of cash and cash equivalents of $50.4 million and remaining availability of $110.5 million under our ABL Credit Facility; we had $45.0 million of borrowings as of December 31, 2024, under our ABL Credit Facility; and

•the Company repurchased and retired 7.2 million shares of common stock for an aggregate of $59.1 million, an average price per share of $8.21 including commissions, under the share repurchase program. As of December 31, 2024, $89.2 million remained authorized for future repurchases of common stock under the share repurchase program.

In February 2026, the Company entered into an amendment to the Caterpillar Equipment Loan Agreement, under which Caterpillar increased the availability of funds by $53.6 million, which resulted in a maximum total available amount of $157.3 million to support the purchase of certain natural gas-fueled power generation equipment.

Our Assets and Operations

Completion services ~~includes~~include our hydraulic fracturing, wireline and cementing operations. We primarily provide these services to E&P companies in the Permian Basin. We also provide turnkey power generation services to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers. During the year ended December 31, ~~2024~~2025, our hydraulic fracturing, wireline, cementing and ~~cementing~~power generation operations accounted for 75approximately 73.62%, 1416.15%, ~~and~~ 10.3%, and 0% of our total revenue, respectively. Our completion services equipment has been designed to handle Permian Basin specific operating conditions and the region’s increasingly high‑intensity well completions, which are characterized by longer horizontal wellbores, more frac stages per lateral and increasing amounts of proppant per well. Our power generation operations consist of mobile natural gas-fueled power generation equipment, including turbine generator sets, reciprocating engines, auxiliary equipment and battery energy storage solution equipment. We plan to continually reinvest in our equipment to ensure optimal performance and reliability.

How We Generate Revenue

We generate revenue predominantly through our completion services, and more specifically, by providing hydraulic fracturing services to our customers. We operate a fleet of mobile hydraulic fracturing, wireline and cementing units and other auxiliary equipment to perform completion services to E&P companies. Additionally, we generate revenue through our PROPWRSM power generation business by providing turnkey power generation services to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers using mobile power generation equipment installed at customers’ sites. These services are generally provided through contractual arrangements in which we set a price per unit of power generated or a price per period and a minimum quantity of power per period under our contracts. We also provide personnel and services that are tailored to meet each of our customers’ needs.

Hydraulic fracturing operations account for a significant portion of our total revenue. We charge our customers on a per‑job basis, in which we set pricing terms after receiving full specifications for the requested job, including the lateral length of the customer’s wellbore, the number of frac stages per well, the amount of proppant and chemicals to be used and other parameters of the job.

In addition to hydraulic fracturing services, we generate revenue through other completion services that we provide to our customers, including wireline, cementing and other related services. These completion services are complementary to each other and are undertaken in unison with hydraulic fracturing services. They are provided through various contractual arrangements, including on a turnkey contract basis, in which we set a price to perform a particular job, or a daywork contract basis, in which we are paid a set price per day for our services. We are also sometimes paid by the hour for these complementary services.

Demand for our completion services is largely dependent on oil and natural gas prices, and our customers’ well completion budgets and rig count. Our revenue, profitability and cash flows are highly dependent upon prevailing crude oil prices and expectations about future prices. For many years, oil prices and markets have been extremely volatile. Prices are affected by many factors beyond our control. The average WTI oil price per barrel was approximately $7665, $7876, and $9478 for the years ended December 31, ~~2024~~2025, ~~2023~~2024, and ~~2022~~2023, respectively. In January ~~2025~~2026, the WTI oil price was approximately $7460 per barrel. If the WTI oil price declines in the future or remains highly volatile, demand for our services may be negatively impacted, which could result in a significant decrease in our future profitability and cash flows. We monitor oil and natural gas prices and the Permian Basin rig count to enable us to more effectively plan our business and forecast the demand for our services.

The historical weekly average Permian Basin rig count based on Baker Hughes rig count information was as follows:

	Year Ended December 31,
Drilling Rig Type (Permian Basin)	~~2024~~2025		~~2023~~2024		~~2022~~2023
Directional	310		3		3
Horizontal	~~296~~257		~~323~~296		~~318~~323
Vertical	105		910		149
Total	~~309~~272		~~335~~309		335
Average Permian Basin rig count to U.S. rig count	5148.65	%	4851.76	%	4648.37	%

Costs of Conducting our Business

The principal direct costs involved in operating our business are direct labor, expendables and other direct costs.

Direct Labor Costs. Payroll and benefit expenses related to our crews and other employees that are directly or indirectly attributable to the effective delivery of services are included in our operating costs. Direct labor costs amounted to 3028.25% and 2830.72% of total costs of service for the years ended December 31, ~~2024~~2025, and ~~2023~~2024, respectively. The ~~increase~~decrease in our direct labor costs percentage is driven by ~~wage~~the ~~adjustments~~implementation ~~and~~of ~~higher~~reactive ~~headcount~~cost ~~resulting~~reductions ~~from~~to ~~business~~align ~~acquisitions~~our costs with the decrease in customer activity experienced in fiscal year 2025.

Expendables. Expendables include the product and freight costs associated with proppant, chemicals and other consumables used in our completion services and other operations. These costs comprise a substantial variable component of our service costs, particularly with respect to the quantity and quality of sand and chemicals demanded when providing hydraulic fracturing services. Expendable product costs comprised approximately 2526.78% and 3225.97% of total costs of service for the years ended December 31, 2025, and 2024, respectively. The percentage increase in our expendables was primarily attributable to the impact of general cost inflation.

41Other Direct Costs. We incur other direct expenses related to our service offerings, including the costs of fuel, repairs and maintenance, general supplies, equipment rental, lease costs on our FORCE® electric-powered hydraulic fracturing fleets, and other miscellaneous operating expenses. Fuel is consumed both in the operation and movement of our equipment. Repairs and maintenance costs are expenses directly related to upkeep of equipment, which have been amplified by the demand for higher horsepower jobs. Capital expenditures to upgrade or extend the useful life of equipment are capitalized and are not included in other direct costs. Other direct costs were 44.7% and 44.1% of total costs of service for the years ended December 31, 2025, and 2024, respectively. The percentage increase in our expendables was primarily attributable to the impact of general cost inflation.

December 31, 2024, and 2023, respectively. The percentage decrease in our expendables was primarily attributable to certain customers electing to directly source sand and the associated logistics.

Other Direct Costs. We incur other direct expenses related to our service offerings, including the costs of fuel, repairs and maintenance, general supplies, equipment rental, lease costs on our FORCE® electric-powered hydraulic fracturing fleets, and other miscellaneous operating expenses. Fuel is consumed both in the operation and movement of our equipment. Repairs and maintenance costs are expenses directly related to upkeep of equipment, which have been amplified by the demand for higher horsepower jobs. Capital expenditures to upgrade or extend the useful life of equipment are capitalized and are not included in other direct costs. Other direct costs were 44.1% and 38.4% of total costs of service for the years ended December 31, 2024, and 2023, respectively. The percentage increase in our other direct costs was primarily attributable to lease costs on our FORCE® fleets.

How We Evaluate Our Operations

Our management uses Adjusted EBITDA or Adjusted EBITDA margin to evaluate and analyze the performance of our various operating segments.

Adjusted EBITDA and Adjusted EBITDA Margin

We view Adjusted EBITDA and Adjusted EBITDA margin as important indicators of performance. We define EBITDA as our earnings, before (i) interest expense, (ii) income taxes and (iii) depreciation and amortization. We define Adjusted EBITDA as EBITDA, plus (i) loss/(gain) on disposal of assets and businesses, (ii) stock-based compensation, (iii) business acquisition contingent consideration adjustments, (iv) other expense/(income), (v) other unusual or nonrecurring (income)/expenses, such as impairment expenses, costs related to asset acquisitions, insurance recoveries, one-time professional fees and legal settlements and (vi) retention bonuses and severance expense. Adjusted EBITDA margin reflects our Adjusted EBITDA as a percentage of our revenues.

Adjusted EBITDA and Adjusted EBITDA margin are supplemental measures utilized by our management and other users of our financial statements such as investors, commercial banks, and research analysts, to assess our financial performance because it allows us and other users to compare our operating performance on a consistent basis across periods by removing the effects of our capital structure (such as varying levels of interest expense), asset base (such as depreciation and amortization), nonrecurring expenses/(income) ~~expenses~~ and items outside the control of our management team (such as income taxes). Adjusted EBITDA and Adjusted EBITDA margin have limitations as analytical tools and should not be considered as an alternative to net income (loss), operating income (loss), cash flow from operating activities or any other measure of financial performance presented in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

Note Regarding Non‑GAAP Financial Measures

Adjusted EBITDA and Adjusted EBITDA margin are not financial measures presented in accordance with GAAP (“non-GAAP”), except when specifically required to be disclosed by GAAP in the financial statements. We believe that the presentation of Adjusted EBITDA and Adjusted EBITDA margin provide useful information to investors in assessing our financial condition and results of operations because it allows them to compare our operating performance on a consistent basis across periods by removing the effects of our capital structure, asset base, nonrecurring expenses (income) and items outside the control of the Company. Net income (loss) is the GAAP measure most directly comparable to Adjusted EBITDA. Adjusted EBITDA and Adjusted EBITDA margin should not be considered as alternatives to the most directly comparable GAAP financial measure. Each of these non-GAAP financial measures has important limitations as analytical tools because they exclude some, but not all, items that affect the most directly comparable GAAP financial measures. You should not consider Adjusted EBITDA and Adjusted EBITDA margin in isolation or as a substitute for an analysis of our results as reported under GAAP. Because Adjusted EBITDA and Adjusted EBITDA margin may be defined differently by other companies in our industry, our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

The following tables set forth certain financial information with respect to the Company’s reportable segments; intersegment revenues are shown under “Reconciling Items” (in thousands):

	Hydraulic Fracturing		Wireline		Cementing		All Other		Reconciling Items		Total
Year ended December 31, 2024
Service revenue	$	1,092,000	$	203,182	$	149,411	$	—	$	(307)	$	1,444,286
Adjusted EBITDA	$	270,505	$	43,857	$	26,539	$	(370)	$	(57,288)	$	283,243
Depreciation and amortization	$	182,188	$	20,633	$	8,812	$	—	$	100	$	211,733
Property and equipment impairment expense (1)	$	188,601	$	—	$	—	$	—	$	—	$	188,601
Goodwill impairment expense (2)	$	—	$	23,624	$	—	$	—	$	—	$	23,624
Operating lease expense on FORCE® fleets (3)	$	47,141	$	—	$	—	$	—	$	—	$	47,141
Capital expenditures	$	116,257	$	7,713	$	9,376	$	—	$	42	$	133,388
Goodwill	$	920	$	—	$	—	$	—	$	—	$	920
Total assets	$	961,485	$	156,349	$	73,935	$	—	$	31,876	$	1,223,645

Adjusted EBITDA and Adjusted EBITDA margin in isolation or as a substitute for an analysis of our results as reported under GAAP. Because Adjusted EBITDA and Adjusted EBITDA margin may be defined differently by other companies in our industry, our definitions of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

	Hydraulic Fracturing		Wireline		Cementing		All Other		Reconciling Items		Total
Year ended December 31, 2023
Service revenue	$	1,280,523	$	229,599	$	120,277	$	—	$	—	$	1,630,399
Adjusted EBITDA	$	366,809	$	61,930	$	24,665	$	—	$	(49,444)	$	403,960
Depreciation and amortization	$	156,057	$	18,762	$	5,845	$	—	$	222	$	180,886
Operating lease expense on FORCE® fleets (3)	$	5,087	$	—	$	—	$	—	$	—	$	5,087
Capital expenditures	$	294,377	$	12,203	$	3,440	$	—	$	—	$	310,020
Goodwill	$	—	$	23,624	$	—	$	—	$	—	$	23,624
Total assets	$	1,189,526	$	198,957	$	78,475	$	—	$	13,354	$	1,480,312

The following tables set forth certain financial information with respect to the Company’s reportable segments; intersegment revenues are shown under “Reconciling Items” (in thousands):

	Hydraulic Fracturing		Wireline		Cementing		~~All~~Power ~~Other~~Generation		Reconciling Items		Total
Year ended December 31, 2022
Year ended December 31, 2025
Service revenue	$	1929,~~143,216~~210	$	31209,~~188~~034	$	91130,~~857~~266	$	131,~~440~~538	$	—(890)	$	1,~~279~~269,~~701~~158
Adjusted EBITDA	$	~~339~~208,~~186~~566	$	741,~~926~~563	$	1422,~~897~~011	$	(111,~~463~~580)	$	(4352,~~956~~117)	$	~~316~~208,~~590~~443
Depreciation and amortization	$	~~117~~143,~~753~~785	$	222,~~619~~269	$	58,~~089~~098	$	~~2,240~~673	$	~~407~~71	$	~~128~~174,~~108~~896
Property and equipment impairment expense (1)	$	57,454	$	—	$	—	$	—	$	—	$	57,454
Operating lease expense on FORCE® fleets (1)	$	61,274	$	—	$	—	$	—	$	—	$	61,274
Capital expenditures	$	347,757	$	2,265	$	7,769	$	1,876	$	5,649	$	365,316
Capital expenditures incurred	$	69,149	$	7,922	$	5,752	$	198,373	$	—	$	281,196
Goodwill	$	—920	$	~~23,624~~—	$	—	$	—	$	—	$	~~23,624~~920
Total assets	$	1,092,658	$	173,489	$	46,944	$	—	$	22,695	$	1,335,786
Total assets (2)	$	841,180	$	162,225	$	69,396	$	201,481	$	16,608	$	1,290,890


	Hydraulic Fracturing		Wireline		Cementing		Power Generation		Reconciling Items		Total
Year ended December 31, 2024
Service revenue	$	1,092,000	$	203,182	$	149,411	$	—	$	(307)	$	1,444,286
Adjusted EBITDA	$	270,505	$	43,857	$	26,539	$	(370)	$	(57,288)	$	283,243
Depreciation and amortization (3)	$	194,557	$	20,633	$	8,819	$	—	$	100	$	224,109
Property and equipment impairment expense (4)	$	188,601	$	—	$	—	$	—	$	—	$	188,601
Goodwill impairment expense (5)	$	—	$	23,624	$	—	$	—	$	—	$	23,624
Operating lease expense on FORCE® fleets (1)	$	47,141	$	—	$	—	$	—	$	—	$	47,141
Capital expenditures incurred	$	116,257	$	7,713	$	9,376	$	—	$	42	$	133,388
Goodwill	$	920	$	—	$	—	$	—	$	—	$	920
Total assets (2)	$	961,485	$	156,349	$	73,935	$	—	$	31,876	$	1,223,645


	Hydraulic Fracturing		Wireline		Cementing		Power Generation		Reconciling Items		Total
Year ended December 31, 2023
Service revenue	$	1,280,523	$	229,599	$	120,277	$	—	$	—	$	1,630,399
Adjusted EBITDA	$	366,809	$	61,930	$	24,665	$	—	$	(49,444)	$	403,960
Depreciation and amortization (3)	$	194,745	$	18,762	$	5,879	$	—	$	222	$	219,608
Operating lease expense on FORCE® fleets (1)	$	5,087	$	—	$	—	$	—	$	—	$	5,087
Capital expenditures incurred	$	294,377	$	12,203	$	3,440	$	—	$	—	$	310,020
Goodwill	$	—	$	23,624	$	—	$	—	$	—	$	23,624
Total assets (2)	$	1,189,526	$	198,957	$	78,475	$	—	$	13,354	$	1,480,312

____________________

(1)Represents ~~noncash~~amortization ~~property~~of ~~and equipment impairment expense on our conventional Tier II diesel~~right-~~only~~of-use ~~hydraulic~~assets ~~fracturing pumps~~ and ~~associated~~interest ~~conventional~~expense ~~assets~~on ~~(“Tier~~lease IIliabilities ~~Units”)~~related ~~for~~to ~~the~~operating ~~year~~leases ~~ended December 31, 2024, and noncash impairment expense~~ on our ~~DuraStim~~FORCE® electric-powered hydraulic fracturing ~~equipment for the year ended December 31, 2022~~fleets. ~~There~~This ~~was~~cost nois ~~property~~recorded ~~and~~within ~~equipment~~cost ~~impairment~~of ~~expense~~services ~~for~~in ~~the~~our ~~year~~consolidated ~~ended~~statements ~~December 31,~~of ~~2023~~operations.

(2)~~Represents~~Total ~~noncash~~assets ~~impairment~~under “Reconciling Items” comprise of ~~goodwill~~cash inon ~~our~~hand, ~~wireline~~certain property, equipment and operating ~~segment~~lease right-of-use assets pertaining to our corporate administrative activities.

(3)Represents amortization of right-of-use assets and interest expense on lease liabilities related to operating leases on our FORCE® electric-powered hydraulic fracturing fleets. This cost is recorded within cost of services in our consolidated statements of operations. We did not have this cost for the year ended December 31, 2022.

(3)The write-offs of remaining book value of prematurely failed power ends and other components are recorded as depreciation in 2025. In order to conform to current period presentation, we have reclassified the corresponding amounts of $12.4 million and $38.7 million from loss on disposal of assets to depreciation for the years ended December 31, 2024 and 2023, respectively.

(4)Represents noncash property and equipment impairment expense on our Tier II Units. There was no property and equipment impairment expense for the years ended December 31, 2025 and 2023.

(5)Represents noncash impairment of goodwill in our Wireline operating segment. There was no goodwill impairment expense for the years ended December 31, 2025 and 2023.

A reconciliation of net (loss) income to Adjusted EBITDA is provided in the table below (in thousands):

	Year Ended December 31,
	2024		2023		2022
	2025		2024		2023
Net (loss) income	$	(137,859)	$	85,634	$	2,030
Net income (loss)	$	824	$	(137,859)	$	85,634
Depreciation and amortization	211,733		180,886		128,108
Depreciation and amortization (1)	174,896		224,109		219,608
Property and equipment impairment expense (1)	188,601		—		57,454
Property and equipment impairment expense (2)	—		188,601		—
Goodwill impairment expense (2)	23,624		—		—
Goodwill impairment expense (3)	—		23,624		—
Interest expense	78,~~815~~238		57,~~308~~815		15,~~605~~308
Income tax (benefit) expense	(31,385)		29,868		5,356
Income tax expense (benefit)	6,997		(31,385)		29,868
Loss on disposal of assets and businesses, net	7,451		73,015		102,150
Loss (gain) on disposal of assets and businesses, net (1)	12,179		(4,925)		34,293
Stock‑based compensation	1716,~~288~~946		1417,~~450~~288		2114,~~881~~450
Business acquisition contingent consideration adjustments	(24,~~600~~900)		—(2,600)		—
Other (income) expense, net (3)	(5,531)		9,533		(11,582)
Other (income) expense, net (4)	(9,709)		(5,531)		9,533
Other general and administrative expense, net (4)	1,782		2,969		8,460
Other general and administrative expense, net (5)	339		1,782		2,969
Retention bonus and severance expense	2,~~324~~633		2,~~297~~324		12,~~128~~297
Adjusted EBITDA	$	~~283~~208,~~243~~443	$	~~403~~283,~~960~~243	$	~~316~~403,~~590~~960

____________________

(1)~~Represents~~The ~~noncash~~write-offs ~~property~~of ~~and~~remaining ~~equipment~~book ~~impairment~~value ~~expense~~of onprematurely ~~our~~failed ~~Tier~~power IIends ~~Units~~and ~~for~~other ~~the~~components ~~year~~are ~~ended~~recorded ~~December 31,~~as ~~2024,~~depreciation ~~and~~in ~~noncash~~2025. ~~impairment~~In ~~expense~~order onto ~~our~~conform ~~DuraStim®~~to ~~electric-powered~~current ~~hydraulic~~period ~~fracturing~~presentation, ~~equipment~~we ~~for~~have reclassified the ~~year~~corresponding ~~ended~~amounts ~~December 31,~~of ~~2022~~$12.4 ~~These~~million ~~impairment~~and ~~expenses~~$38.7 ~~are~~million ~~included~~from inloss ~~our~~on ~~Hydraulic~~disposal ~~Fracturing~~of ~~reportable~~assets ~~segment~~to depreciation for the years ended December 31, 2024 and 2023, respectively.

(2)Represents noncash impairment ofexpense ~~goodwill~~on our Tier II Units. This impairment expense is included in our ~~wireline~~Hydraulic Fracturing operating segment.

(3)~~Other~~Represents income for the year ended December 31, 2024 is primarily comprised of tax refunds (net of advisory fees) totaling $5.0 million and insurance reimbursements of $2.0 million, partially offset by a $2.0 million loss to a customer related to an accidental cementing job failure. Other expense for the year ended December 31, 2023 is primarily comprised of settlement expenses resulting from routine audits and true-up health insurance costs totaling approximately $7.4 million and a $2.5 million unrealized loss on short-term investment. Other income for the year ended December 31, 2022 includes tax refunds (net of advisory fees) totaling $10.7 million, a $2.7 million noncash ~~income~~impairment ~~from fixed asset inventory received as part~~ of agoodwill ~~settlement~~in ofour ~~warranty~~Wireline ~~claims~~operating ~~with an equipment manufacturer, and a $1~~segment.~~6 million unrealized loss on short-term investment.~~

(4)Other ~~general~~income ~~and administrative expense~~ for the ~~years~~year ended December 31, ~~2024~~2025 is primarily comprised of direct payment tax refunds and ~~2023~~well ~~primarily~~service ~~relates~~tax torefunds ~~nonrecurring~~(net ~~professional~~of advisory fees) ~~paid~~totaling to$3.3 ~~external~~million, ~~consultants~~a in$2.4 ~~connection~~million ~~with~~unrealized ~~our~~gain on short-term investment, interest income from note receivable from sale of business ~~acquisitions~~of $1.2 million, adjustments to workers' compensation and ~~legal~~general ~~settlements,~~liability ~~net~~insurance premiums of ~~reimbursements~~$1.0 ~~from~~million, insurance ~~carriers.~~reimbursements ~~Other~~of ~~general~~$0.8 million and ~~administrative~~$1.0 ~~expense~~million of other income. Other income for the year ended December 31, ~~2022~~2024 is primarily ~~relates~~comprised toof ~~nonrecurring~~tax ~~professional~~refunds ~~fees~~(net ~~paid~~of toadvisory ~~external~~fees) ~~consultants~~totaling in$5.0 ~~connection~~million ~~with~~and ~~the~~insurance ~~Company's~~reimbursements ~~audit~~of ~~committee~~$2.0 ~~review~~million, ~~SEC~~partially ~~investigation,~~offset ~~shareholder~~by ~~litigation,~~a ~~legal~~$2.0 million ~~settlements~~loss ~~and~~to ~~other~~a ~~legal~~customer ~~matters~~related to an accidental cementing job failure. Other expense for the year ended December 31, ~~net~~2023 is primarily comprised of ~~reimbursements~~settlement expenses resulting from routine audits and true-up health insurance ~~carriers~~costs totaling approximately $7.4 million and a $2.5 million unrealized loss on short-term investment.

(5)Other general and administrative expense for the years ended December 31, 2024 and 2023 primarily relates to nonrecurring professional fees paid to external consultants in connection with our business acquisitions and legal settlements, net of reimbursements from insurance carriers.

Results of Operations

In 2024, we conducted our business through four operating segments: ~~hydraulic~~Hydraulic ~~fracturing~~Fracturing, ~~wireline~~Wireline, ~~cementing~~Cementing, and ~~power~~Power ~~generation~~Generation ~~services~~Services (started in the fourth quarter of fiscal year 2024 ~~and has not begun any revenue-generating activities yet~~). Our ~~power~~Power ~~generation~~Generation ~~services~~ operating ~~segments~~segment ~~are~~is shown in the “All Other” category for segment reporting purposes.

Year Ended December 31, ~~2024~~2025 Compared to Year Ended December 31, ~~2023~~2024

(in thousands, except percentages)
	Year Ended December 31,						Change
	2024			2023			Variance			%
	2025			2024			Variance			%
Revenue
Hydraulic Fracturing	$	1929,~~092,000~~210		$	1,~~280~~092,~~523~~000		$	(~~188~~162,~~523~~790)		(14.79)	%
Wireline	~~203~~209,~~182~~034			~~229~~203,~~599~~182			~~(26~~5,~~417)~~852			~~(11~~2.5)9	%
Cementing	~~149~~130,~~411~~266			~~120~~149,~~277~~411			29(19,~~134~~145)			24(12.28)	%
Elimination of intersegment service revenue	(307)			—			(307)			100.0	%
Power Generation	1,538			—			1,538			100.0	%
Total revenue	1,444,286			1,630,399			(186,113)			(11.4)	%
Elimination of intersegment service revenue	(890)			(307)			(583)			(189.9)	%
Total revenue	1,269,158			1,444,286			(175,128)			(12.1)	%
Cost of services (1)
Hydraulic Fracturing	~~800~~702,~~202~~593			~~886~~800,~~157~~202			(8597,~~955~~609)			(912.72)	%
Wireline	~~148~~156,~~125~~472			~~155~~148,~~357~~125			(78,~~232)~~347			(45.7)6	%
Cementing	~~117~~103,~~490~~388			90117,~~287~~490			27(14,~~203~~102)			30(12.10)	%
All Other (2)	4			—			4			100.0	%
Power Generation	6,612			4			6,608			165,200.0	%
Elimination of intersegment cost of services	(~~307~~890)			—(307)			(~~307~~583)			~~100~~(189.09)	%
Total cost of services	1968,~~065,514~~175			1,~~131~~065,~~801~~514			(6697,~~287~~339)			(5.9.1)	%
General and administrative expense (3)	114,323			114,354			(31)			—	%
General and administrative expense (2)	107,558			114,323			(6,765)			(5.9)	%
Depreciation and amortization	211,733			180,886			30,847			17.1	%
Depreciation and amortization (3)	174,896			224,109			(49,213)			(22.0)	%
Property and equipment impairment expense	~~188,601~~—			—188,601			(188,601)			(100.0)	%
Goodwill impairment expense	~~23,624~~—			—23,624			(23,624)			(100.0)	%
Loss on disposal of assets and business, net	7,451			73,015			(65,564)			(89.8)	%
Loss (gain) on disposal of assets and business, net (3)	12,179			(4,925)			17,104			347.3	%
Interest expense	78,~~815~~238			57,~~308~~815			~~2,507~~423			475.24	%
Other (income) expense, net	(5,531)			9,533			(15,064)			(158.0)	%
Other income, net	(9,709)			(5,531)			(4,178)			(75.5)	%
Income tax (benefit) expense	(31,385)			29,868			(61,253)			(205.1)	%
Income tax expense (benefit)	6,997			(31,385)			38,382			122.3	%
Net (loss) income	$	(137,859)		$	85,634		$	(223,493)		(260.99)	%
Net income (loss)	$	824		$	(137,859)		$	138,683		100.60	%
Adjusted EBITDA (4)	$	~~283~~208,~~243~~443		$	~~403~~283,~~960~~243		$	(~~120~~74,~~717~~800)		(2926.8841)	%
Adjusted EBITDA Margin (4)	19.6		%	24.8		%	(5.2)		%	(20.97)	%
Adjusted EBITDA margin (4)	16.4		%	19.6		%	(3.2)		%	(16.33)	%
Net income (loss) margin (5)	0.1		%	(9.5)		%	9.6		%	101.05	%
Hydraulic Fracturing segment results of operations:
Revenue	$	1929,~~092,000~~210		$	1,~~280~~092,~~523~~000		$	(~~188~~162,~~523~~790)		(14.79)	%
Cost of services	$	~~800~~702,~~202~~593		$	~~886~~800,~~157~~202		$	(8597,~~955~~609)		(912.72)	%
Adjusted EBITDA	$	~~270~~208,~~505~~566		$	~~366~~270,~~809~~505		$	(9661,~~304~~939)		(2622.39)	%
Adjusted EBITDA Margin (5)	24.8		%	28.6		%	(3.8)		%	(13.3)	%
Adjusted EBITDA margin (6)	22.4		%	24.8		%	(2.4)		%	(9.7)	%

____________________

(1) Exclusive of depreciation and amortization.

(2) Includes our newly formed power generation services business.

(3) Inclusive of stock‑based compensation.

(42) ~~For~~Inclusive ~~definitions~~ of ~~the non~~stock‑~~GAAP~~based financial measures of Adjusted EBITDA and Adjusted EBITDA margin and reconciliation of Adjusted EBITDA and Adjusted EBITDA margin to our most directly comparable financial measures calculated in accordance with GAAP, please read “How We Evaluate Our Operationscompensation.”

(53) The ~~non‑GAAP~~write-offs ~~financial~~of ~~measure~~remaining book value of ~~Adjusted~~prematurely ~~EBITDA~~failed ~~margin~~power ~~for~~ends ~~the~~and ~~Hydraulic~~other ~~Fracturing~~components ~~segment~~are isrecorded ~~calculated~~as bydepreciation ~~taking~~in ~~Adjusted~~2025. ~~EBITDA~~In ~~for~~order to conform to current period presentation, we have reclassified the ~~Hydraulic~~corresponding ~~Fracturing~~amount ~~segment~~of as$12.4 amillion ~~percentage~~from loss on disposal of ~~our~~assets ~~revenues~~to depreciation for the ~~Hydraulic~~year ~~Fracturing~~ended ~~segment~~December 31, 2024.

~~Revenue. Revenue~~(4) For ~~decreased~~definitions ~~11.4%,~~of orthe ~~$186.1~~non‑GAAP ~~million,~~financial tomeasures ~~$1,444.3~~of ~~million for~~Adjusted ~~the~~EBITDA ~~year~~and ~~ended~~Adjusted ~~December 31,~~EBITDA ~~2024,~~margin asand ~~compared~~reconciliation of Adjusted EBITDA and Adjusted EBITDA margin to ~~$1,630.4~~our ~~million~~most ~~for~~directly ~~the~~comparable ~~year~~financial ~~ended~~measure ~~December 31~~calculated in accordance with GAAP, ~~2023.~~please ~~Revenue~~read by“How ~~reportable~~We ~~segment~~Evaluate ~~was~~Our asOperations.” ~~follows:~~

~~Hydraulic Fracturing. Our hydraulic fracturing segment revenues decreased 14.7%, or $188.~~(5) Net ~~million~~loss ~~for~~margin ~~the~~reflects ~~year ended December 31, 2024, as compared to the year ended December 31, 2023. The decrease was primarily attributable to a decrease in~~ our ~~customers’~~net ~~activity~~loss ~~levels~~ as a ~~result~~percentage of a decrease in drilling activity and decreased customer pricing, partially offset by the addition of AquaProp's operations in May 2024, which contributed $44.1 million in revenues during 2024. Our average active hydraulic fracturing fleet count was approximately 14 fleets for the year ended December 31, 2024, a decrease from 15 fleets for the year ended December 31, 2023. Intersegment revenues, consisting of revenues derived from our ~~wireline segment, totaled $0~~revenue.~~3 million and $0 for the years ended December 31, 2024 and 2023, respectively.~~

~~Wireline.~~(6) The ~~Our~~non‑GAAP ~~wireline~~financial ~~segment~~measure ~~revenue~~of ~~decreased~~Adjusted ~~11.5%,~~EBITDA ormargin ~~$26.4 million~~ for the ~~year~~Hydraulic ~~ended~~Fracturing ~~December 31,~~segment ~~2024,~~is ascalculated ~~compared~~by totaking ~~the~~Adjusted ~~year~~EBITDA ~~ended~~for ~~December 31,~~the ~~2023.~~Hydraulic ~~The~~Fracturing ~~decrease~~segment ~~was primarily attributable to a decrease in our customers' activity levels~~ as a ~~result~~percentage of aour ~~decrease~~revenues infor ~~drilling~~the ~~activity~~Hydraulic ~~and~~Fracturing ~~decreased customer pricing~~segment.

~~Cementing~~Revenues. Revenues ~~Our~~decreased ~~cementing segment revenue increased 24~~12.21%, or $29175.1 million, to $1,269.2 million for the year ended December 31, ~~2024~~2025, as compared to ~~the year ended December 31~~$1, ~~2023~~444.3 ~~The~~million ~~increase~~for ~~was primarily attributable to~~ the ~~addition~~year ofended ~~Par Five's operations in~~ December ~~2023~~ 31, ~~which contributed to $35~~2024.3 ~~million~~Revenue ofby ~~the~~reportable ~~increase~~segment inwas ~~revenues.~~as follows:

~~Cost~~Hydraulic ~~of Services~~Fracturing. ~~Cost~~ ofOur ~~services~~Hydraulic Fracturing segment revenues decreased 514.9%, or $66162.38 million for the year ended December 31, 2025, as compared to $1the year ended December 31,~~065~~ 2024.5 The decrease was primarily attributable to decreased customer activity, reduced customer pricing, and idling of fleets, partially offset by the addition of AquaProp's operations in May 2024, which resulted in a $41.9 million increase in revenues during fiscal year 2025 due to the impact of AquaProp’s operations for the full year ended December 31, 2025 compared to only 215 days of activity during fiscal year 2024,. ~~from~~Intersegment revenues totaled $~~1,131~~0.89 million ~~during~~and $0.3 million for the ~~year~~years ended December 31, ~~2023~~2025 and 2024, respectively. ~~Cost~~Intersegment ofrevenues ~~services~~were byderived ~~reportable~~from our Wireline, Cementing and Power Generation segments for the year ended December 31, 2025, and from our Wireline segment ~~was~~for asthe ~~follows:~~year ended December 31, 2024.

~~Hydraulic Fracturing~~Wireline. ~~Cost~~Our ofWireline ~~services~~segment ~~for~~revenues ~~our~~increased ~~hydraulic~~2.9%, ~~fracturing~~or ~~segment decreased~~ $865.09 million ~~during~~for the year ended December 31, ~~2024~~2025, as compared to the year ended December 31, ~~2023. As a percentage of hydraulic fracturing segment revenues (including equipment reservation fees), hydraulic fracturing cost of services was 73.3% for the year ended December 31,~~ 2024~~, as compared to 69~~.2% ~~for the year ended December 31, 2023 driven by the decreased activity levels, customer price decreases and the impact of general cost inflation.~~ The ~~decrease~~increase ~~in cost of services~~ was ~~partially~~primarily ~~offset~~attributable ~~by an increase of $7.6 million in insurance expense resulting from higher allocation of workers' compensation, general liability and automobile insurance costs~~ to ~~cost~~increased ofcustomer ~~services~~activity ~~in 2024 compared to 2023 since these costs are primarily incurred for our operational workforce,~~ and ~~the addition of AquaProp's operations in May 2024, which added $42~~utilization.~~5 million in cost of services during the year ended December 31, 2024.~~

~~Wireline~~Cementing. Our ~~wireline~~Cementing segment ~~cost~~revenues ~~of services~~ decreased 412.78%, or $719.21 million for the year ended December 31, ~~2024~~2025, as compared to the year ended December 31, ~~2023~~2024. ~~due~~The todecrease ~~scaling~~was ~~back~~primarily inattributable ~~response~~ to ~~decreased~~the ~~revenues.~~sale ~~Intersegment cost~~ of ~~services,~~our ~~consisting~~cementing ofbusiness ~~cost~~located ofin ~~services~~Vernal, ~~incurred~~Utah toin ~~our~~November ~~hydraulic~~2024 ~~fracturing~~which ~~segment,~~contributed ~~totaled~~ $022.3 million ~~and~~in $0revenues ~~for~~during fiscal year 2024, partially offset by increases resulting from synergies gained with customers after the ~~years~~acquisition ~~ended~~of ~~December 31,~~Par ~~2024~~Five ~~and~~Energy ~~2023,~~Services ~~respectively~~LLC.

~~Cementing~~Power Generation. Our ~~cementing~~Power ~~cost~~Generation ofsegment ~~services~~revenue ~~increased~~was ~~30.1%, or~~ $271.25 million for the year ended December 31, ~~2024,~~2025. asOur ~~compared~~Power toGeneration ~~the~~segment ~~year~~began ~~ended~~revenue ~~December 31,~~generating ~~2023.~~activities ~~The~~during ~~increase was primarily attributable to~~ the ~~addition~~third ofquarter ~~Par Five's operations in December 2023, which resulted in $27.9 million~~ of ~~the~~fiscal ~~net~~year ~~increase in cost of services~~2025.

~~General~~Cost ~~and~~of ~~Administrative Expenses~~Services. ~~General~~Cost ~~and~~of ~~administrative~~services ~~expenses~~decreased ~~remained~~9.1%, ~~flat~~or at $~~114~~97.3 million, to $968.2 million for the year ended December 31, ~~2024~~2025, asfrom ~~compared to~~ $~~114~~1,065.45 million ~~for~~during the year ended December 31, ~~2023~~2024. Cost of services by reportable segment was as follows:

~~Excluding~~Hydraulic ~~nonrecurring~~Fracturing. ~~and~~Our ~~noncash~~Hydraulic ~~items~~Fracturing ~~(i.e.,~~segment ~~stock-based~~cost ~~compensation~~ of services decreased $1797.36 million during the year ended December 31, ~~legal~~2025, ~~settlements~~as ~~(net~~compared ofto ~~insurance~~the ~~reimbursements)~~year ofended $0December 31, 2024.2 ~~million~~As a percentage of hydraulic fracturing segment revenues, ~~transaction~~Hydraulic ~~expenses~~Fracturing cost of $1services was 75.6% ~~million~~for ~~and~~the ~~retention~~year ~~bonuses~~ended ~~and~~December 31, ~~severance~~2025, ~~expenses~~as ofcompared $2to 73.3% ~~million~~for the year ended December 31, ~~partially~~2024 ~~offset~~driven by ~~business~~customer ~~acquisition~~price ~~contingent~~decreases ~~consideration~~and ~~adjustments~~the impact of $2general cost inflation.6 ~~million),~~The ~~general~~decrease ~~and~~in ~~administrative~~cost ~~expenses~~of ~~were~~services ~~$95.5~~was ~~million~~partially ~~for~~offset by the ~~year~~addition ~~ended~~of ~~December 31,~~AquaProp's operations in May 2024, aswhich ~~compared~~resulted toin a $9433.68 million ~~for~~increase ~~the~~in ~~year~~cost ~~ended~~of ~~December 31,~~services ~~2023~~during fiscal year 2025.

~~Depreciation~~Wireline. ~~and~~Our ~~Amortization. Depreciation~~Wireline ~~and~~segment ~~amortization~~cost of services increased 175.16%, or $~~30.~~8.3 million for the year ended December 31, to2025, ~~$211.7~~as ~~million~~compared ~~for~~to the year ended December 31, 2024 due to increased customer activity and the impact of general cost inflation. Intersegment cost of services, asconsisting ~~compared~~of cost of services incurred to our Hydraulic Fracturing segment, totaled $~~180~~0.97 million and $0.3 million for the ~~year~~years ended December 31, ~~2023.~~2025 ~~The~~and ~~increase~~2024, ~~was~~ respectively.

Cementing. Our Cementing cost of services decreased 12.0%, or $14.1 million for the year ended December 31, 2025, as compared to the year ended December 31, 2024. The decrease was primarily attributable to the sale of our cementing business located in Vernal, Utah in November 2024 which incurred $14.7 million in cost of services during fiscal year 2024. Intersegment cost of services, consisting of cost of services incurred to our Hydraulic Fracturing segment, totaled $0.1 million and $0 for the years ended December 31, 2025 and 2024, respectively.

~~primarily~~Power ~~attributable~~Generation. toOur ~~(i)~~Power ~~assets~~Generation ~~placed~~segment ~~into~~cost ~~service~~of ~~since~~services ~~December 31,~~was ~~2023,~~$6.6 ~~(ii)~~million for the ~~addition~~year ofended aDecember 31, ~~finance~~2025. ~~lease~~Our ~~for~~Power ~~certain~~Generation ~~power~~segment ~~generation~~began ~~equipment~~revenue ingenerating ~~August~~activities ~~2023~~during ~~which~~the ~~resulted~~third inquarter ~~$19~~of fiscal year 2025.0 ~~million~~Intersegment cost of ~~amortization~~services, ~~(iii)~~consisting ~~the~~of ~~addition~~cost of ~~Par~~services ~~Five's~~incurred ~~operations~~to inour ~~December~~Hydraulic ~~2023~~Fracturing ~~which~~segment, ~~resulted~~totaled ~~in a~~ $30.51 million ~~increase in depreciation~~ and ~~(iv)~~$0 for the ~~addition~~years ofended ~~AquaProp's~~December 31, ~~operations~~2025 inand ~~May~~ 2024, ~~which included $3~~respectively.~~5 million of depreciation and amortization.~~

~~Property~~General and ~~Equipment~~Administrative ~~Impairment Expense~~Expenses. ~~During~~General and administrative expenses decreased 5.9% or $6.7 million, to $107.6 million for the year ended December 31, ~~2024~~2025, weas ~~recorded~~compared ~~noncash~~to ~~property~~$114.3 ~~and~~million ~~equipment~~for ~~impairment~~the ~~expense~~year ofended December 31, 2024. The net decrease was primarily attributable to a $~~188~~4.65 million decrease in ~~connection~~professional ~~with~~fees, ~~the~~a ~~impairment~~$2.3 ofmillion ~~our~~increase ~~Tier~~in IIbusiness ~~Units~~acquisition contingent consideration adjustments, ~~which~~a is$2.0 ~~included~~million decrease in ~~our~~dues ~~Hydraulic~~and ~~Fracturing~~subscriptions, ~~reportable~~a ~~segment~~$1.6 Nomillion ~~property~~decrease in transaction expenses and ~~equipment~~a ~~impairment~~$0.4 ~~expense~~million ~~was~~net ~~recorded~~decrease ~~during~~in ~~the~~other ~~year~~general ~~ended~~and ~~December 31~~administrative expenses, ~~2023~~partially offset by a $4.1 million increase in payroll.

~~Goodwill~~Excluding ~~Impairment~~nonrecurring ~~Expense~~and noncash items (i. ~~During~~e., ~~the~~stock-based ~~year~~compensation ~~ended~~of ~~December 31~~$16.9 million, ~~2024~~retention bonuses and severance expenses of $2.7 million and legal settlements (net of insurance reimbursements) of $0.3 million, wepartially ~~recorded~~offset ~~goodwill~~by ~~impairment~~business ~~expense~~acquisition contingent consideration adjustments of $234.69 million), ingeneral ~~our~~and ~~Wireline~~administrative ~~reportable~~expenses ~~segment~~were ~~during~~$92.6 million for the year ended December 31, ~~2024.~~2025, Noas ~~goodwill~~compared ~~impairment~~to ~~expense~~$95.5 ~~was~~million ~~recorded~~for ~~during~~ the year ended December 31, ~~2023~~2024.

~~Loss~~Depreciation ~~on Disposal of Assets~~ and ~~Business~~Amortization. ~~Loss~~Depreciation ~~on the disposal of assets~~ and ~~business~~amortization decreased 8922.80%, or $6549.52 million, to $7174.59 million for the year ended December 31, ~~2024~~2025, as compared to $73224.01 million for the year ended December 31, ~~2023~~2024. The decrease was primarily attributable to anassets ~~$8.2~~fully ~~million~~depreciating ~~gain~~and ~~related~~a toreduction ~~the sale of our cementing business located~~ in ~~Vernal, Utah, during 2024, losses incurred during 2023 from~~ the ~~decommissioning~~cost ofbasis ~~certain hydraulic fracturing equipment, replacement~~ of ~~certain~~Tier ~~major~~II ~~components~~Units impaired in ~~connection~~the ~~with~~third ~~our~~quarter ~~conversion~~ of ~~certain~~fiscal ~~Tier~~year II2024, ~~hydraulic~~partially ~~fracturing~~offset ~~equipment~~by ~~to Tier IV DGB, and~~ the ~~write-off~~addition of ~~certain~~AquaProp's ~~hydraulic~~operations ~~fracturing~~in ~~equipment~~May as2024 awhich ~~result~~resulted ofin ana ~~accidental~~$2.7 ~~fire~~million atincrease ~~a wellsite~~ in ~~March~~depreciation ~~2023~~and amortization.

~~Interest~~Property and Equipment Impairment Expense. ~~Interest~~There ~~expense~~was ~~increased~~no toimpairment ~~$7.8~~expense ~~million~~during ~~for~~ the year ended December 31, ~~2024, as compared to $5~~2025.3 ~~million~~During ~~for~~ the year ended December 31, ~~2023.~~2024, ~~The~~we ~~increase~~recorded ~~was~~a ~~primarily~~noncash ~~attributable~~impairment toexpense ~~higher~~of ~~average~~$188.6 ~~outstanding~~million ~~borrowings~~in ~~under~~connection ~~our~~with ~~ABL~~the ~~Credit~~impairment ~~Facility~~of ~~during~~our ~~the~~Tier ~~year~~II ~~ended December 31~~Units, ~~2024~~which ~~and~~is ~~the~~included ~~addition~~in ofour aHydraulic ~~finance~~Fracturing ~~lease~~reportable ~~for certain power generation equipment in August 2023~~segment.

~~Other~~Goodwill ~~(Income)~~Impairment Expense. ~~Other~~There ~~income~~ was ~~approximately~~no ~~$5.5~~goodwill ~~million~~impairment ~~for the year ended December 31, 2024, as compared to other~~ expense ofduring ~~$9.5 million for~~ the year ended December 31, ~~2023~~2025. ~~Other~~During ~~income during~~ the year ended December 31, 2024, iswe ~~primarily~~recorded ~~comprised~~goodwill ofimpairment ~~tax~~expense ~~refunds (net~~ of ~~advisory fees) totaling~~ $523.~~0 million,~~6 ~~insurance reimbursements of $2.0~~ million ~~and a $2.6 million decrease~~ in ~~estimated fair value of the contingent consideration payable on~~ our ~~acquisition~~Wireline ofreportable ~~AquaProp, partially offset by a $2~~segment.~~0 million~~ loss to a customer related to an accidental cementing job failure. Other expense for the year ended December 31, 2023 is comprised of settlement expenses resulting from routine audits and true-up health insurance costs totaling approximately $7.4 million and a $2.5 million unrealized loss on short-term investment.

~~Income~~Loss ~~Taxes. Total~~(Gain) ~~income~~on ~~tax~~Disposal ~~benefit~~of ~~was~~Assets ~~$31~~and Business.4 Loss ~~million~~on ~~resulting~~the indisposal anof ~~effective~~assets ~~tax~~increased ~~rate~~347.3%, ofor 18$17.5%1 million, to $12.2 million for the year ended December 31, ~~2024~~2025, as compared to ~~income~~a ~~tax~~gain ~~expense~~on ofthe ~~$29.9~~disposal ~~million~~of ~~resulting~~assets inand anbusiness ~~effective tax rate~~ of 25$4.9% million for the year ended December 31, ~~2023~~2024. The ~~change~~increase inwas ~~income~~primarily ~~tax~~attributable ~~benefit~~to ~~recorded~~losses incurred during ~~the~~fiscal year ~~ended~~2025 ~~December 31,~~from ~~2024, compared to~~ the ~~change~~sale inof ~~income~~certain ~~tax~~Tier ~~expense~~II ~~recorded~~hydraulic ~~during~~fracturing ~~the~~equipment ~~year~~and ~~ended~~a ~~December 31,~~$8.2 ~~2023,~~million isgain ~~primarily~~related ~~attributable~~ to the ~~difference~~sale ~~in the impact~~ of ~~nondeductible~~our ~~expenses~~cementing ~~and~~business ~~state~~located ~~taxes~~in onVernal, ~~the pre-tax loss for 2024~~Utah, asduring ~~compared~~fiscal toyear ~~pre-tax income for 2023~~2024.

Interest Expense. Interest expense increased to $8.2 million for the year ended December 31, 2025, as compared to $7.8 million for the year ended December 31, 2024. The increase was primarily attributable to the addition of loans under the Caterpillar Equipment Loan Agreement (as defined below) to support the purchase of certain mobile natural gas-fueled power generation equipment during the year ended December 31, 2025.

Other Income. Other income was approximately $9.7 million for the year ended December 31, 2025, as compared to other income of $5.5 million for the year ended December 31, 2024. Other income for the year ended December 31, 2025 is primarily comprised of direct payment tax refunds and well service tax refunds (net of advisory fees) totaling $3.3 million, a $2.4 million unrealized gain on short-term investment, interest income from note receivable from sale of business of $1.2 million, adjustments to workers' compensation and general liability insurance premiums of $1.0 million, insurance reimbursements of $0.8 million and $1.0 million of other income. Other income for the year ended December 31, 2024 is primarily comprised of tax refunds (net of advisory fees) totaling $5.0 million and insurance reimbursements of $2.0 million, partially offset by a $2.0 million loss to a customer related to an accidental cementing job failure.

Income Taxes. Total income tax expense was $7.0 million resulting in an effective tax rate of 89.5% for the year ended December 31, 2025, as compared to income tax benefit of $31.4 million resulting in an effective tax rate of 18.5% for the year ended December 31, 2024. The change in income tax expense recorded during the year ended December 31, 2025, compared to the change in income tax expense recorded during the year ended December 31, 2024, is primarily attributable to the difference in the impact of nondeductible expenses, state taxes, and valuation allowances on the pre-tax income for fiscal year 2025, as compared to fiscal year 2024.

Liquidity and Capital Resources

Our liquidity is currently provided by (i) existing cash balances, including proceeds from the 2026 Common Stock Offering, (ii) operating cash flows, ~~and~~ (iii) borrowings under our ABL Credit Facility (as defined below) and (iv) borrowings under our Caterpillar Equipment Loan Agreement (as defined below). See “Credit Facility and Other Financing Arrangements” below. Additionally, on December 29, 2025, we entered into the Stonebriar Equipment Lease Facility to support the lease of certain mobile power generation equipment, including turbine generator sets along with auxiliary equipment, for our PROPWRSM business line, and in January 2026, we received approximately $163.3 million from the 2026 Common Stock Offering. Our cash is primarily used to fund our operations, support growth opportunities, fund share repurchases under our share repurchase program and satisfy future debt repayments and lease payments. Our Borrowing Base (as defined below), under our ABL Credit Facility, as redetermined monthly, is tied to the sum of 85% to 90% of monthly eligible accounts receivable and 80% of eligible unbilled accounts (up to a maximum of 25% of the Borrowing Base), in each case, depending on the credit ratings of our accounts receivable counterparties, less customary reserves (the “Borrowing Base”). Changes to our operational activity levels and our customers’' credit ratings have an impact on our total eligible accounts receivable, which could result in significant changes to our Borrowing Base and, therefore, our availability under our ABL Credit Facility.

We received advance payments from acustomers ~~customer~~ for our services, and the amount outstanding in connection with the advance payments ~~was $11.8 million and $19.2 million~~ as of December 31, ~~2024~~2025 ~~and~~was ~~2023, respectively~~$8.1 ~~There~~million, ~~were~~which nodoes ~~amounts~~not ofinclude any restricted cash ~~as of December 31, 2024 and 2023~~.

As of December 31, ~~2024~~2025, our borrowings under our ABL Credit Facility were $45.0 million, our borrowings under our Caterpillar Equipment Loan Agreement were $77.6 million and our total liquidity was $~~160~~205.4 million, consisting of cash and cash equivalents of $91.3 million and $114.1 million of availability under our ABL Credit Facility. As of January 31, 2026, our borrowings under our ABL Credit Facility were $45.0 million, our borrowings under our Caterpillar Equipment Loan Agreement were $86.9 million and our total liquidity was $325.0 million, consisting of cash and cash equivalents of $50236.45 million and $~~110~~88.5 million of availability under our ABL Credit Facility.

OnIn ~~April~~May 242025, ~~2024,~~ the Company's board of directors (the “Board”) approved ana ~~increase~~further ~~and~~ extension to the share repurchase program ~~previously~~initially authorized on May 17, 2023. ~~The~~As extended, the program permits the repurchase of up to ~~an additional~~ $~~100~~200 million of the Company’s common stock ~~for~~through aDecember ~~total of $200 million and extends the expiration date by one year to May~~ 31, ~~2025~~2026. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, privately negotiated transactions, derivative transactions or otherwise, certain of which may be made pursuant to a trading plan meeting the requirements of Rule 10b5-1 under the Exchange Act, as amended, in compliance with applicable state and federal securities laws. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of the Company's common stock, the market price of the Company's common stock, general market and economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the share repurchase program, and the program may be suspended, modified, or discontinued at any time without prior notice. The Company expects to fund the repurchases using cash on hand and expected free cash flow to be generated through ~~May~~December ~~2025~~2026. During the year ended December 31, ~~2024~~2025, the Company ~~repurchased~~made ~~and~~no ~~retired~~share ~~7.2~~repurchases ~~million~~under ~~shares~~the ofshare ~~common~~repurchase ~~stock~~program ~~for~~as anit ~~aggregate~~prioritized the launch and scaling of ~~$59~~its PROPWRSM business line.1 ~~million,~~The anCompany ~~average~~intends ~~price~~to ~~per~~continue ~~share~~to ofprioritize ~~$8.21~~investing ~~including~~in ~~commissions,~~its ~~under~~PROPWRSM ~~the~~business ~~share~~line ~~repurchase~~in ~~program~~the near future. As of December 31, ~~2024~~2025, $89.2 million remained authorized for future repurchases of common stock under the share repurchase program.

OnIn ~~May~~October 312025, ~~2024,~~ the Company ~~consummated~~sold ~~the~~its ~~acquisition~~short-term ofinvestment ~~all~~in of2.6 ~~the~~million ~~outstanding~~common ~~equity~~shares ~~interests~~of inSTEP ~~AquaProp~~Energy Services Ltd. (“STEP”), which ~~provides~~it ~~wet~~received ~~sand~~in ~~solutions~~2022 as part of the consideration for ~~hydraulic~~its ~~fracturing~~sale ~~sand~~of ~~requirements~~its atcoiled ~~oil~~tubing ~~well~~assets ~~sites~~to STEP. The ~~cash~~Company ~~consideration~~received ~~for~~$9.4 ~~this~~million ~~acquisition~~in ~~includes~~proceeds and recognized a $130.78 million ~~paid~~loss toon sale of assets from the ~~seller~~sale of this investment. In December 2025, the Company received $711.29 million ~~paid~~in toproceeds ~~settle~~as ~~the~~full ~~seller’s~~repayment of the outstanding ~~debt,~~balance and $0accrued interest on its note receivable from Big 4 Services LLC (“Big 4”).3 ~~million~~The ~~paid~~Company received this note receivable from Big 4 on November 1, 2024 as consideration for the ~~seller’s~~sale ~~transaction~~of ~~expenses~~its cementing business located in Vernal, Utah.

OnIn ~~November~~January 12026, ~~2024,~~the weCompany sold ~~our~~17.3 ~~cementing~~million ~~business~~shares ~~located in Vernal, Utah, to a business owned by a former employee as part~~ of aits ~~strategic~~common ~~repositioning.~~stock Weunder ~~received~~an aunderwritten ~~promissory~~public ~~note~~offering for $1310.000 ~~million~~per asshare, ~~consideration.~~pursuant ~~The~~to ~~note~~an ~~receivable~~effective isshelf ~~secured~~registration bystatement ~~substantially~~on ~~all~~Form ~~assets~~S-3 offiled ~~the~~with ~~former employee’s business and~~ the ~~former employee’s ownership interests in and distributions from the business~~SEC. The ~~note~~Company ~~receivable~~received isapproximately to$163.3 bemillion ~~paid to the Company~~ in ~~quarterly~~net ~~installments~~proceeds ~~with interest of 10% per annum~~ from ~~March~~this ~~31,~~sale ~~2025~~after todeducting ~~December~~underwriting ~~31,~~discounts ~~2029.~~and Wecommissions ~~recorded~~and aestimated ~~gain~~offering ~~on disposal of $8~~expenses.2 ~~million~~The ~~related~~Company intends to ~~the~~use ~~sale of~~ the ~~business.~~net ~~The~~proceeds ~~former~~from ~~employee~~this ~~was~~sale ~~part~~for ofgeneral ~~our~~corporate ~~cementing operations until November 1~~purposes, ~~2024~~including ~~and~~to isfund nogrowth ~~longer~~capital ~~affiliated~~for ~~with~~additional ~~the~~power ~~Company.~~generation equipment.

There can be no assurance that our operations and other capital resources will provide cash in sufficient amounts to maintain planned or future levels of capital expenditures and to continue with our share repurchases under our share repurchase program or fund future business acquisitions. Future cash flows are subject to a number of variables, and are highly dependent on the drilling and completion, and production activity by our customers, which in turn is highly dependent on oil and natural gas prices. Depending upon market conditions and other factors, we may issue equity and debt securities or take other actions necessary to fund our business, strategy or meet our future long-term liquidity requirements.

drilling and completion, and production activity by our customers, which in turn is highly dependent on oil and natural gas prices. Depending upon market conditions and other factors, we may issue equity and debt securities or take other actions necessary to fund our business, strategy or meet our future long-term liquidity requirements.

Cash and Cash Flows

The following table sets forth our net cash provided by (used in) operating, investing and financing activities during the years ended December 31, ~~2024~~2025 and ~~2023~~2024, respectively.

	Year Ended December 31,
(in thousands)
(in thousands)	2024		2023
	Year Ended December 31,
Net cash provided by operating activities	$	252,295	$	374,742
	2025		2024
Net cash used in investing activities	$	(155,099)	$	(384,127)
Net cash provided by operating activities	$	231,607	$	252,295
Net cash used in financing activities	$	(80,107)	$	(46,123)
Net cash used in investing activities	$	(149,811)	$	(155,099)
Net cash used in financing activities	$	(40,905)	$	(80,107)

Operating Activities

Net cash provided by operating activities was $~~252~~231.36 million for the year ended December 31, ~~2024~~2025, as compared to $~~374~~252.73 million for the year ended December 31, ~~2023~~2024. The net decrease of $~~122~~20.47 million was primarily ~~due~~attributable to lower net income adjusted for noncash expenses and the timing of our receivable collections from our customers and payments to our vendors.

Investing Activities

Net cash used in investing activities decreased to $~~155~~149.18 million for the year ended December 31, ~~2024~~2025, from $~~384~~155.1 million for the year ended December 31, ~~2023~~2024. The net decrease was primarily attributable to ~~our~~the ~~capital~~acquisition ~~light~~of ~~strategy~~AquaProp ~~and~~which resulted in a $21.0 million net cash outflow for the ~~completion~~year ended December 31, 2024, a $17.3 million increase in proceeds from sale of ~~our~~assets ~~planned~~(including ~~investments~~$9.4 million from the sale of the Company’s short-term investment discussed in ~~Tier~~“Note IV5. ~~DGB~~Fair ~~equipment~~Value Measurements”) and $13.0 million in proceeds from note receivable from sale of business further discussed in “Note 16. Related Party Transactions,” partially offset by a $46.0 million increase in capital expenditures primarily related to our PROPWRSM power generation business.

The following table reconciles our capital expenditures paid to capital expenditures incurred for the periods indicated:


(in thousands)
	Year Ended December 31,
	2025		2024
Capital expenditures paid (1)	$	186,316	$	140,297
Less: Capital expenditures included in accounts payable and accrued liabilities - beginning of period	(14,695)		(21,604)
Add: Capital expenditures included in accounts payable and accrued liabilities - end of period	28,095		14,695
Add: Capital expenditures related to financed equipment purchases	81,130		—
Add: Capital expenditures financed by operating lease landlord	350		—
Capital expenditures incurred (1)	$	281,196	$	133,388

____________________

(1)This table reconciles cash basis capital expenditures reported in the Company's consolidated statements of cash flows to accrual basis capital expenditures reported in "Note 11. - Reportable Segment Information" and below.

The following table summarizes our capital expenditures incurred by reportable segment for the periods indicated:

(in thousands)
	Year Ended December 31,
(in thousands)	2024		2023
	2025		2024
Reportable Segments:
Hydraulic Fracturing	$	~~116~~69,~~257~~149	$	~~294~~116,~~377~~257
Wireline	7,~~713~~922		127,~~203~~713
Cementing	95,~~376~~752		39,~~440~~376
Reconciling Items (1)	42		—
Power Generation	198,373		—
Total capital expenditures (2)	$	133,388	$	310,020
Reconciling Items (1)	—		42
Total capital expenditures incurred (2)	$	281,196	$	133,388

_________________

(1) Reconciling Items include our corporate facilities.

(2) See “Note 3. Supplemental Cash Flows Information” in the financial statements for noncash reconciling items.

Financing Activities

Net cash used in financing activities ~~increased~~decreased to $8040.19 million for the year ended December 31, ~~2024~~2025, compared to $4680.1 million for the year ended December 31, ~~2023~~2024. The net ~~increase~~decrease was primarily driven by ~~net~~a ~~borrowings~~$59.1 ofmillion decrease in share repurchases, partially offset by a $156.08 million ~~under~~increase ~~our~~in ~~ABL~~payment ~~Credit~~of ~~Facility~~business ~~during~~acquisition ~~the~~deferred ~~year~~cash ~~ended December 31~~consideration, ~~2023,~~ a $133.06 million increase in ~~payments~~repayments of ~~finance~~equipment ~~lease~~financing ~~obligation~~term ~~and~~loans, a $73.45 million increase in ~~share repurchases and~~ repayments of insurance financing, ofa $12.08 million ~~during~~increase ~~the~~in ~~year~~payment ~~ended~~of ~~December 31,~~financing ~~2024,~~origination ~~partially~~and ~~offset~~debt byissuance costs and a $12.63 million ~~decrease~~increase in tax withholdings paid for net settlement of equity awards ~~and payment of debt issuance costs of $1~~.~~2 million during the year ended December 31, 2023.~~

Credit Facility and Other Financing Arrangements

~~Our~~The ~~revolving~~Company ~~credit~~is ~~facility,~~a asparty ~~amended and restated in April 2022, prior~~ to ~~giving effect to~~ the ~~amendment~~ABL toCredit ~~the~~Facility ~~revolving~~that ~~credit~~provides ~~facility~~for ~~in June 2023, had a total~~ borrowing capacity of ~~$150.0 million.~~up ~~The revolving credit facility had a borrowing base of 85%~~ to 90%, depending on the credit ratings of our accounts receivable counterparties, of monthly eligible accounts receivable less customary reserves. The revolving credit facility included a springing fixed charge coverage ratio to apply when excess availability was less than the greater of (i) 10% of the lesser of the facility size or the borrowing base or (ii) $10225.0 million. ~~Under the revolving credit facility we were required to comply,~~ (subject to certain exceptions and materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens, indebtedness, changes in the ~~nature~~Borrowing ofBase ~~our business~~limit), ~~mergers~~ and ~~other~~matures ~~fundamental~~on ~~changes,~~June ~~disposal of assets~~2, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities2028.

ABL Credit Facility: Effective ~~June~~December 226, ~~2023~~2025, the Company entered into an amendment to its amended and restated revolving credit facility (the revolving credit facility, as amended and restated in April 2022, as amended in June 2023, as amended in June 2024, as amended in December 2025 and as may be amended further, the “ABL Credit Facility”). The amendment increased the ~~borrowing~~debt ~~capacity~~basket ~~under~~for ~~the~~capital/finance ~~ABL~~leases, ~~Credit~~purchase ~~Facility~~money debt, and other similar financing facilities to $~~225~~425.0 million. The Borrowing Base as of December 31, 2025, was approximately $167.7 million. ~~(subject~~The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10% of the lesser of the facility size or the Borrowing Base ~~limit~~or (ii) $15.0 million. Under the ABL Credit Facility, we are required to comply, subject to certain exceptions and ~~extended~~materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens or indebtedness, changes in the ~~maturity~~nature ~~date~~of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to ~~June~~our 2organizational documents or accounting policies, ~~2028~~prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company excluding certain mobile natural gas-fueled power generation equipment purchased under a financing arrangement.

~~Effective~~Borrowings ~~June~~under ~~26, 2024,~~ the ~~company~~ABL ~~entered~~Credit ~~into~~Facility anaccrue ~~amendment~~interest tobased ~~its~~on ~~amended~~a ~~and~~three-tier ~~restated~~pricing ~~revolving~~grid ~~credit~~tied ~~facility~~to ~~(the revolving credit facility~~availability, ~~as amended~~ and ~~restated~~we inmay ~~April~~elect ~~2022,~~for asloans ~~amended~~to inbe ~~June~~based ~~2023,~~on aseither ~~amended~~the inSecured ~~June~~Overnight ~~2024~~Financing ~~and~~Rate ~~as may be amended further, the~~ (“~~ABL Credit Facility~~SOFR”). ~~The~~or ~~amendment increased~~ the ~~amount~~base ofrate, ~~noncash~~plus ~~consideration~~the ~~that~~applicable ~~may~~margin, bewhich ~~considered~~ranges ~~cash~~from ~~pursuant to certain permitted dispositions~~1. ~~The ABL Credit Facility has a borrowing base of the sum of 85~~75% to 902.25% offor ~~monthly~~SOFR ~~eligible~~loans ~~accounts receivable~~ and 800.75% ~~of eligible unbilled accounts (up~~ to ~~a maximum of~~ 1.25% offor ~~the borrowing~~ base), inrate ~~each~~loans. ~~case,~~The ~~depending~~weighted onaverage ~~the~~annual ~~credit~~interest ~~ratings~~rate offor our ~~accounts~~ABL ~~receivable~~Credit ~~counterparties,~~Facility ~~less~~for ~~customary reserves (~~the ~~“Borrowing~~year ~~Base”)~~ended ~~as redetermined monthly. The Borrowing Base as of~~ December 31, ~~2024~~2025, was ~~approximately $164~~6.~~1 million. The ABL Credit Facility includes a springing fixed charge coverage ratio to apply when excess availability is less than the greater of (i) 10~~29% ~~of the lesser of the facility size or the Borrowing Base or (ii) $15~~.0 million. Under the ABL Credit Facility we are required to comply, subject to certain exceptions and materiality qualifiers, with certain customary affirmative and negative covenants, including, but not limited to, covenants pertaining to our ability to incur liens or indebtedness, changes in the nature of our business, mergers and other fundamental changes, disposal of assets, investments and restricted payments, amendments to our organizational documents or accounting policies, prepayments of certain debt, dividends, transactions with affiliates, and certain other activities. Borrowings under the ABL Credit Facility are secured by a first priority lien and security interest in substantially all assets of the Company.

~~Borrowings~~As ~~under~~of ~~the~~December 31, ~~ABL Credit Facility accrue interest based on a three-tier pricing grid tied to availability~~2025, and ~~we may elect for loans to be based on either the Secured Overnight Financing Rate (“SOFR”) or the base rate~~2024, ~~plus~~we ~~the~~had ~~applicable~~outstanding ~~margin,~~borrowings ~~which~~under ~~ranges from 1.75% to 2.25% for SOFR loans and 0.75% to 1.25% for base rate loans. The weighted average annual interest rate for~~ our ABL Credit Facility ~~for~~of ~~the~~$45.0 ~~year~~million ~~ended~~and ~~December 31,~~$45.0 ~~2024~~million, ~~was 7~~respectively.~~12%.~~

The loan origination costs relating to the ABL Credit Facility are classified as an asset on our balance sheet. As of December 31, 2024, and 2023, we had outstanding borrowings under our ABL Credit Facility of $45.0 million and $45.0 million, respectively.50

WeCaterpillar Equipment Loan Agreement: On April 2, 2025, we entered into a ~~contractual~~financing arrangement ~~with~~and on February 6, 2026, we entered into an ~~equipment~~amendment ~~manufacturer~~to this financing arrangement with Caterpillar Financial Services Corporation (collectively, the “Caterpillar Equipment Loan Agreement”) to support the purchase of certain mobile natural gas-fueled power generation equipment, including turbine generator sets along with auxiliary equipment, for our ~~PROPWR~~PROPWRSM business line, ~~with~~under which the lender, Caterpillar Financial Services Corporation (an affiliate of the equipment manufacturer), will fund progress payments beyond the initial down payment on the equipment for a maximum total ~~cost~~available amount of $~~122~~157.03 million, ofand ~~which~~provide ~~approximately~~us ~~$103~~interim loans in connection with each progress payment made on our behalf.7 ~~million~~Such interim loans will accrue interest at a floating rate per annum based on SOFR, ~~representing~~plus ~~progress~~a ~~payments~~3.85% ~~beyond~~margin, plus any increase or minus any decrease in the ~~initial~~Bloomberg ~~down~~Industrial Single A Total Return Index since November 15, 2024. Such interim loans will be combined and converted to a term loan for each unit of equipment after the final progress payment is funded for such unit. Interest on ~~this~~interim loans is payable on a monthly basis until conversion to term loans. Each term loan will accrue interest at a fixed rate per annum based on the three-year U.S Treasury rate as of the date of conversion of interim loans to the term loan for each unit of equipment, plus a 3.70% margin, plus any increase or minus any decrease in the Bloomberg Industrial Single A Total Return Index since November 15, 2024 and will be ~~financed.~~payable Wein ~~currently~~equal ~~expect~~monthly installments over a period not to ~~start~~exceed ~~receiving~~five ~~this~~years. Each loan will be secured on a first lien basis by equipment collateral and support documents, casualty proceeds and other proceeds or products related thereto, and any proceeds from the ~~end~~equipment ofloan must be used for payment or reimbursement for the ~~second~~equipment ~~quarter~~subject to such loan. Each loan will be fully and unconditionally guaranteed by the guarantors set forth in the Caterpillar Equipment Loan Agreement. The weighted average interest rate on our interim loans (short-term loans) as of December 31, 2025 ~~through~~was ~~early~~7.69%. ~~2026~~The weighted average interest rate on our term loans (long-term loans) for the year ended December 31, 2025 was 7.34%.

~~Off~~Under ~~Balance~~the ~~Sheet~~Caterpillar ~~Arrangements~~Equipment Loan Agreement, we have incurred interim loans and term loans with outstanding amounts of $2.1 million and $75.4 million, respectively, as of December 31, 2025, related to funding for equipment under construction and equipment received. See “Note 8. Interim and Long-Term Debt.” The financed payments from the lender (an affiliate of the equipment manufacturer) are presented as non-cash investing and financing activities within the “Supplemental Disclosure of Non-Cash Investing and Financing Activities” section of our consolidated statements of cash flows. The repayments of term loans are presented as cash outflows under cash flows from financing activities in our consolidated statements of cash flows.

WeStonebriar ~~had~~Equipment noLease ~~material~~Facility. ~~off~~On December 29, 2025, ProPetro Energy Solutions, LLC (“PROPWR”), a wholly owned subsidiary of the Company, entered into an Interim Funding Agreement and a Master Lease Agreement with Stonebriar for the right, but not the obligation, to fund up to $350.0 million of purchases of power generator equipment . Under the Interim Funding Agreement, Stonebriar provides funding to finance down payments and progress payments owing to equipment suppliers. Monthly rent under the Interim Funding Agreement is based on the unpaid balance ~~sheet~~of ~~arrangements~~the aggregate amounts advanced under the Interim Funding Agreement and not yet converted to a lease schedule under the Master Lease Agreement, times a per annum lease rate factor equal to sum of 1-Month SOFR plus 6.25%. Upon delivery and acceptance of a power generator, amounts outstanding under the Interim Funding Agreement with respect to such equipment are converted into a lease schedule under the Master Lease Agreement. Stonebriar will hold legal title to such leased equipment. The lease term for each item of equipment will be 84 months, and the rental payment amounts will be based on the equipment cost times a lease rate factor set forth in the applicable lease schedule. PROPWR will have certain early termination and purchase options with respect to the leased equipment at various points during the lease, as set forth in the Master Lease Agreement and related lease schedule for such equipment. Upon exercise of ~~December 31~~such rights and payment of the required amounts, ~~2024~~PROPWR would acquire legal title to such equipment.

Off-Balance Sheet Arrangements

We had no material off balance sheet arrangements as of December 31, 2025.

Capital Requirements, Future Sources and Use of Cash

Capital expenditures incurred were $~~133~~281.42 million during the year ended December 31, ~~2024~~2025, as compared to $~~310~~133.04 million during the year ended December 31, ~~2023~~2024. The significant portion of our total capital expenditures incurred during the year ended December 31, ~~2024,~~2025 were ~~maintenance~~for ~~capital~~our ~~expenditures~~Power ~~and~~Generation ~~conversion~~segment oftotaling ~~our~~$198.4 ~~hydraulic~~million ~~fracturing~~including ~~equipment~~$81.1 tomillion ~~lower~~of ~~emissions~~financed equipment purchases for this business, and maintenance capital expenditures.

Our future material use of cash will be to fund our capital expenditures. ~~Capital~~and ~~expenditures for 2025 are projected~~ to berepay ~~primarily~~debt related to capital expenditures to extend the useful life of our existing completion services assets, costs to convert some existing equipment to lower emissions equipment, purchase power generation equipment, strategic purchases and other ~~ancillary~~financing ~~equipment purchases~~obligations, ~~subject~~if ~~to market conditions and customer demand~~any. ~~Our~~Although ~~future~~we ~~capital~~intend ~~expenditures depend on our projected operational activity, emission requirements and planned conversions~~ to ~~lower~~prioritize ~~emissions~~investing ~~equipment,~~in ~~among~~our ~~other~~PROPWRSM ~~factors,~~business ~~which~~line ~~could~~in ~~vary significantly throughout~~ the ~~year.~~near ~~Based on our current plan and projected activity levels for 2025~~future, we ~~expect~~may ~~our~~also ~~capital~~use ~~expenditures~~material toamounts ~~range~~of ~~between~~cash ~~$300 million~~ to ~~$400~~repurchase ~~million~~shares ~~which~~under ~~includes approximately $150 million to $200 million for~~ our ~~completion~~share ~~services~~repurchase ~~business~~program. ~~and~~Capital ~~approximately~~expenditures ~~$150 million to $200 million~~ for ~~our~~2026 ~~PROPWR~~are ~~business.~~projected ~~We entered into a contractual arrangement with an equipment manufacturer~~ to ~~purchase mobile natural gas-fueled power generation equipment for our PROPWR business line, with a total cost of $122.0 million, of which approximately $103.7 million will~~ be ~~financed,~~primarily representing progress payments beyond the initial down payment on this equipment. We currently expect receive this equipment beginning with the end of the second quarter of 2025 through early 2026. We entered into a contractual arrangement with another related ~~equipment~~to ~~manufacturer~~capital expenditures to purchase ~~additional natural gas-fueled~~ power generation equipment ~~for our PROPWR business line~~, ~~with~~costs ~~a total cost of $25.0 million. We currently expect~~ to ~~receive~~extend ~~this equipment in~~ the ~~first~~useful ~~half~~life of ~~2025. We could incur significant additional capital expenditures if~~ our ~~projected~~existing ~~activity~~completion ~~levels~~services ~~increase during the course of the year~~assets, ~~inflation~~costs ~~and supply chain tightness continues~~ to ~~adversely~~convert ~~impact~~some ~~our~~existing ~~operations or we invest in new or different lower emissions~~ equipment. ~~The Company will continue~~ to ~~evaluate the emissions profile of its equipment over the coming years and may, depending on market conditions, convert or retire additional conventional Tier II equipment in favor of~~ lower emissions equipment~~. The Company’s decisions regarding the retirement or conversion of equipment or the addition of lower emissions equipment will be subject to a number of factors~~, ~~including~~potential ~~(among~~buyout ~~other factors) the availability~~ of ~~equipment,~~leased ~~including~~FORCE® ~~parts~~electric-powered ~~and~~hydraulic ~~major~~fracturing ~~components~~fleets, ~~supply~~strategic ~~chain~~purchases ~~disruptions, prevailing~~ and ~~expected commodity prices, customer demand and requirements and the Company’s evaluation of projected returns on conversion or~~ other ~~capital~~ancillary ~~expenditures.~~equipment ~~Depending on the impact of these factors~~purchases, ~~the~~subject ~~Company may decide~~ to ~~retain conventional equipment for a longer period of time or accelerate the retirement, replacement or conversion of that equipment.~~

We anticipate our capital expenditures will be funded by existing cash, cash flows from operations, and if needed, borrowings under our ABL Credit Facility. Our cash flows from operations will be generated from services we provide to our customers.51

market conditions and customer demand. Our future capital expenditures depend on our projected operational activity, emission requirements and planned conversions to lower emissions equipment and demand for our power generation services, among other factors, which could vary significantly throughout the year. Based on our current plan and projected activity levels for 2026, we expect our capital expenditures to range between $390 million and $435 million, which includes approximately $140 million to $160 million for our completion services business, including approximately $40 million to $50 million related to lease buyouts for a portion of our FORCE® electric-powered hydraulic fracturing fleets. Additionally, we expect to incur approximately $250 million to $275 million in 2026 for our PROPWRSM business line. We entered into contractual arrangements with an equipment manufacturer to purchase mobile natural gas-fueled power generation equipment, including turbine generator sets along with auxiliary equipment, for our PROPWRSM business line, with a total cost of $186.6 million. The total remaining commitment (after initial down payment and financed payments) under these arrangements as of December 31, 2025 was $87.1 million, of which $76.1 million will be financed under the Caterpillar Equipment Loan Agreement. We expect to receive the remaining equipment currently on order under these arrangements from the first quarter through the third quarter of fiscal year 2026. We also entered into contractual arrangements with other equipment manufacturers to purchase additional power generation and auxiliary equipment for our PROPWRSM business line, with a total remaining commitment of approximately $203.0 million. We expect to receive the remaining equipment currently on order under these arrangements from the middle of fiscal year 2026 through the end of fiscal year 2027. We could incur significant additional capital expenditures if our projected activity levels increase during the course of the year, inflation and supply chain tightness continue to adversely impact our operations or we invest in new or different lower emissions equipment. The Company will continue to evaluate the emissions profile of its equipment over the coming years and may, depending on market conditions, convert or retire additional conventional Tier II equipment in favor of lower emissions equipment. The Company’s decisions regarding the retirement or conversion of equipment or the addition of lower emissions equipment will be subject to a number of factors, including (among other factors) the availability of equipment, including parts and major components, supply chain disruptions, prevailing and expected commodity prices, customer demand and requirements and the Company’s evaluation of projected returns on conversion or other capital expenditures. Depending on the impact of these factors, the Company may decide to retain conventional equipment for a longer period of time or accelerate the retirement, replacement or conversion of that equipment. The Company may also decide to exercise its buyout options on its leased FORCE® electric-powered hydraulic fracturing fleets at the end of their leases.

We anticipate our capital expenditures will be funded by existing cash, including proceeds from the 2026 Common Stock Offering, cash flows from operations, the Caterpillar Equipment Loan Agreement, other financing arrangements including the Stonebriar Equipment Lease Facility, and borrowings under our ABL Credit Facility. Our cash flows from operations will be generated from services we provide to our customers.

Contractual Obligations

The following table presents our contractual obligations and other commitments as of December 31, ~~2024~~2025:

(in thousands)	~~Period~~
	Period
	Total		1 year or less		More than 1 year
ABL Credit Facility (1)	$	45,000	$	—	$	45,000
Operating leases (2)(3)	126,550		51,238		75,312
Equipment financing interim loans (2)	2,135		2,135		—
Finance lease (4)	34,377		20,915		13,462
Equipment financing term loans (3)	90,402		19,329		71,073
Sand commitments (5)	1,500		1,500		—
Operating leases (4)(5)	84,984		47,426		37,558
Equipment purchase commitments (6)	147,000		120,160		26,840
Finance lease (6)	12,767		12,767		—
Par Five deferred cash consideration (7)	3,109		3,109		—
Equipment purchase commitments (7)	290,122		225,984		64,138
AquaProp deferred cash consideration (8)	3,664		3,664		—
Unused commitment fee on equipment lease facility (8)	1,750		—		1,750
Total	$	~~361~~527,~~200~~160	$	~~200~~307,~~586~~641	$	~~160~~219,~~614~~519

____________________

(1)Exclusive of future commitment fees, amortization of deferred financing costs, interest expense or other fees on our ABL Credit Facility because obligations thereunder are floating rate instruments and we cannot determine with accuracy the timing of future loan advances, repayments ofor future interest rates to be changed. However, assuming a weighted average interest rate of 76.1229%, and that our ABL Credit Facility debt balance remains the same, our estimated annual interest payment will be $3.2.8 million.

(2)~~Operating~~Excludes ~~leases~~interest ~~exclude~~expense ~~short-term~~because ~~leases~~obligations ~~and~~under ~~other~~our ~~commitments~~equipment ~~(see~~financing ~~Note~~interim ~~17.~~loans ~~Leases~~have ~~and~~floating ~~Note~~rates ~~18.~~of ~~Commitments~~interest and ~~Contingencies~~we incannot determine with accuracy the ~~financial~~timing ~~statements~~of ~~for~~conversion ~~additional~~to ~~disclosures)~~term loans, repayments or future interest rates to be changed.

~~(3)Includes our leases for FORCE® electric-powered hydraulic fracturing fleets (312,000 HHP). We expect to receive the remaining equipment under these leases in the first half of 2025.~~52

(43)~~Finance~~Includes ~~lease~~interest ~~for~~expense ~~certain~~since ~~power~~obligations ~~generation~~under our equipment ~~(70~~financing ~~MW)~~term toloans ~~support~~have ~~electric-powered~~fixed ~~hydraulic~~rates ~~fracturing~~of ~~equipment~~interest and predetermined repayment schedules.

(54)~~Relates~~Operating toleases aexclude ~~take~~short-~~or-pay~~term ~~sand~~leases ~~commitment~~and ~~with~~other ~~one~~commitments of(see ~~our~~“Note ~~sand~~17. ~~vendors~~Leases” and “Note 18. Commitments and Contingencies” in the financial statements for additional disclosures).

(65)~~Represents~~Includes ~~contractual~~our ~~commitments~~leases ~~with~~for ~~two~~FORCE® ~~equipment manufacturers to purchase 140 megawatts of mobile natural gas~~electric-~~fueled~~powered ~~power~~hydraulic ~~generation~~fracturing ~~equipment~~fleets ~~for our PROPWR business line~~ (~~see~~312,000 ~~Note 18. Commitments and Contingencies in the financial statements for additional disclosures~~HHP).

(76)~~Represents~~Finance ~~the~~lease ~~unpaid~~for ~~portion~~certain ofpower ~~the~~generation ~~purchase~~equipment ~~consideration on our acquisition of Par Five to be used to cover~~ (i)70 ~~the amount by which the estimated purchase price exceeds the final purchase price, if any, and (ii~~megawatts) ~~any~~to ~~indemnity~~support ~~obligations~~electric-powered ofhydraulic ~~the~~fracturing ~~seller, if any~~equipment.

(87)Represents ~~the~~contractual ~~unpaid~~commitments ~~portion~~with ofequipment ~~the~~manufacturers to purchase ~~consideration~~power ongeneration ~~our~~and ~~acquisition~~auxiliary ofequipment ~~AquaProp~~for toour bePROPWRSM ~~used~~business toline ~~cover~~ (i)see ~~the~~“Note ~~amount~~18. byCommitments ~~which~~and ~~the~~Contingencies” ~~estimated~~in ~~purchase price exceeds~~ the ~~final~~financial ~~purchase~~statements ~~price,~~for ifadditional ~~any, and (ii~~disclosures) ~~any indemnity obligations of the seller, if any~~.

We(8)Represents ~~enter into other purchase agreements with Sand Suppliers to secure~~ the ~~supply~~maximum ofamount ~~sand in the normal course of our business. The agreements with the Sand Suppliers require that~~ we purchase a minimum volume of sand, based primarily on a certain percentage of our sand requirements from our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties (shortfall fees) may beowe ~~charged.~~under ~~The shortfall fee represents liquidated damages and is either a fixed percentage of~~ the ~~purchase~~Stonebriar ~~price~~Equipment ~~for~~Lease ~~the~~Facility ~~minimum~~described ~~volumes~~in or“Note ~~a fixed price per ton of unpurchased volumes~~17. ~~Our~~Leases” current agreements with Sand Suppliers expire at different times prior to December 31, 2025. Our agreed upon sand requirements or minimum volumes are based on certain future events such as our customer demand, which cannot be reasonably estimated. If the activity level of our customers declines and the future demand for ~~our~~any ~~services~~unused isportion ~~materially and adversely affected, we may be required to pay for more sand from one~~ of ~~our Sand Suppliers than we need in~~ the ~~performance~~lease ~~of our services, regardless of whether we take physical delivery of such sand~~facility. In such an event, we may be required to pay shortfall fees or other penalties under the purchase agreement, which could have a material adverse effect on our business, financial condition, or results of operations.

We enter into other purchase agreements with Sand Suppliers to secure the supply of sand in the normal course of our business. The agreements with the Sand Suppliers require that we purchase a minimum volume of sand, based primarily on a certain percentage of our sand requirements from our customers or in certain situations based on predetermined fixed minimum volumes, otherwise certain penalties (shortfall fees) may be charged. The shortfall fee represents liquidated damages and is either a fixed percentage of the purchase price for the minimum volumes or a fixed price per ton of unpurchased volumes. Our existing agreements with the Sand Suppliers expire on May 31, 2029. Our agreed upon sand requirements or minimum volumes are based on certain future events such as our customer demand, which cannot be reasonably estimated. If the activity level of our customers declines and the future demand for our services is materially and adversely affected, we may be required to pay for more sand from one of our Sand Suppliers than we need in the performance of our services, regardless of whether we take physical delivery of such sand. In such an event, we may be required to pay shortfall fees or other penalties under the purchase agreement, which could have a material adverse effect on our business, financial condition, or results of operations.

Recent Accounting Pronouncements

Disclosure concerning recently issued accounting standards is incorporated by reference to "“Note 2-. Significant Accounting Policies"” of our Consolidated Financial Statements contained in this Annual Report.

Critical Accounting ~~Policies and~~ Estimates

The discussion and analysis of our financial condition and results of operations is based on our consolidated financial statements, which have been prepared in accordance with GAAP. The preparation of these financial statements requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the dates of the financial statements and the reported revenues and expenses during the years. We evaluate these estimates and assumptions on an ongoing basis and base our estimates on historical experience, current conditions and various other assumptions that we believe to be reasonable under the circumstances. The results of these estimates form the basis for making judgments about the carrying values of assets and liabilities as well as identifying and assessing the accounting treatment with respect to commitments and contingencies. Our actual results may materially differ from these estimates.

Listed below are the accounting ~~policies~~estimates that we believe are critical to our financial statements ~~due~~since tothese ~~the~~estimates ~~degree~~require ofa ~~uncertainty~~high ~~regarding~~degree ~~the~~of ~~estimates~~complexity orand ~~assumptions involved~~judgment, and that we believe are critical to ~~the~~ understanding of our operations.

~~Business~~Depreciation ~~Combinations~~and Amortization

~~Business~~Our ~~combinations~~property and equipment are ~~accounted~~recorded ~~for~~at ~~under~~cost, ~~the~~less ~~acquisition~~accumulated ~~method~~depreciation. The estimated useful lives and salvage values of ~~accounting.~~our ~~Under~~property ~~this~~and ~~method,~~equipment ~~the~~are ~~assets~~subject ~~acquired~~to key assumptions such as maintenance, utilization and ~~liabilities~~job ~~assumed~~variation. ~~are~~These ~~recognized~~estimates atmay ~~their~~change ~~respective~~due ~~fair~~to ~~values~~a asnumber of ~~the~~factors ~~date~~such ofas ~~acquisition~~changes in operating conditions or advances in technology. ~~The~~Unanticipated ~~excess,~~future ifchanges ~~any,~~in ofthese ~~the~~assumptions ~~acquisition~~could ~~price~~negatively ~~over~~or ~~the~~positively ~~fair~~impact ~~values~~our ofnet income (loss). A 10% change in the ~~assets~~useful ~~acquired~~lives of our property and ~~liabilities~~equipment ~~assumed~~would ishave ~~recorded~~resulted asin ~~goodwill~~approximately if$14.7 ~~the~~million ~~definition~~impact ofon apre-tax ~~business~~income isduring ~~met~~the year ended December 31, 2025. ~~For~~Intangible ~~significant~~assets, ~~acquisitions~~other than goodwill, weconsist ~~utilize~~of ~~third-party~~trademark/trade ~~appraisal~~name, ~~firms~~customer torelationships ~~assist~~and usfavorable incontracts. ~~determining~~The ~~the~~estimated ~~fair~~useful ~~values~~lives ~~for~~of ~~certain~~these intangible assets ~~acquired~~could ~~and~~be ~~liabilities~~sensitive ~~assumed~~to ~~using~~changes ~~discounted~~in ~~cash~~market ~~flows~~conditions and ~~other~~management’s ~~applicable~~judgment, ~~valuation~~and ~~techniques.~~are Welikely ~~record~~to ~~any~~change ~~acquisition~~in ~~related~~the ~~costs~~future asif ~~expenses~~certain ~~when~~events ~~incurred~~occur. Presently, there are no events or circumstances that will cause us to believe that our estimated useful life for our intangible assets are likely to change.

Adjustments to the fair values of assets acquired and liabilities assumed are made until we obtain all relevant information regarding the facts and circumstances that existed as of the acquisition date (the “measurement period”), not to exceed one year from the date of the acquisition. We recognize measurement period adjustments in the period in which we determine the amounts, including the effect on earnings of any amounts we would have recorded in previous periods if the accounting had been completed at the acquisition date.53

The estimation of the fair values of assets and liabilities acquired in business combinations requires significant judgment. Our fair value estimates require us to use significant observable and unobservable inputs. The estimates of fair value are also subject to significant variability, are sensitive to changes in market conditions, and are reasonably likely to change in the future. A significant change in the observable and unobservable inputs and determination of fair value of the assets and liabilities acquired could significantly impact our consolidated financial statements.

Property and Equipment

Our property and equipment are recorded at cost, less accumulated depreciation.

Upon sale or retirement of property and equipment, the cost and related accumulated depreciation are removed from the balance sheet and the net amount, less proceeds from disposal, is recognized as a gain or loss in earnings.

We primarily retire certain components of equipment such as fluid ends and power ends, rather than the entire pieces of equipment. The associated loss is recorded in our statement of operations as part of net loss on disposal of assets and businesses, which was $7.5 million, $73.0 million, and $102.1 million for the years ended December 31, 2024, 2023, and 2022, respectively.

The estimated useful lives and salvage values of property and equipment are subject to key assumptions such as maintenance, utilization and job variation. Unanticipated future changes in these assumptions could negatively or positively impact our net income (loss). A 10% change in the useful lives of our property and equipment would have resulted in approximately $18.5 million impact on pre-tax loss during the year ended December 31, 2024. Depreciation of property and equipment is provided on the straight‑line method over estimated useful lives as shown in the table below.

Land			Indefinite
Buildings and property improvements			5 - 30 years
Vehicles			1 ‑ 5 years
Equipment			1 ‑ 22 years
Leasehold improvements			5 ‑ 20 years

Impairment of Long-Lived Assets

InWe ~~accordance~~review ~~with~~our ~~the~~long‑lived ~~Financial~~assets, ~~Accounting~~other ~~Standards~~than ~~Board~~goodwill, ~~Accounting~~for ~~Standards~~impairment ~~Codification~~whenever ~~(“ASC”)~~events ~~360~~or ~~regarding~~circumstances ~~Accounting~~indicate ~~for~~that the ~~Impairment~~carrying orvalue ~~Disposal~~ of ~~Long‑Lived~~those ~~Assets,~~assets wemay ~~review~~not be recoverable. For the impairment testing on long‑-lived assets, ~~including~~other ~~intangible~~than ~~assets~~goodwill, toa belong-lived ~~held~~asset ~~and~~is ~~used~~grouped ~~whenever~~at ~~events~~the orlowest ~~circumstances~~level ~~indicate~~for ~~that~~which identifiable cash flows are largely independent of the ~~carrying~~cash ~~value~~flows of ~~those~~other assets ~~may~~and ~~not~~liabilities. beEstimated ~~recoverable~~future undiscounted cash flows expected to result from the use and eventual disposition of the asset group are compared to the carrying amount of the underlying assets. An impairment loss is indicated if the sum of the expected future undiscounted cash flows attributable to the ~~assets~~asset group is less than the carrying amount of such assets. In this circumstance, we recognize an impairment loss for the amount by which the carrying amount of the assets exceeds the estimated fair value of the asset. Our cash flow forecasts require us to make certain judgments regarding long‑term forecasts of future revenue and costs and cash flows related to the assets subject to review. The significant ~~assumption~~assumptions in our cash flow forecasts isare our estimated equipment utilization and profitability. ~~The~~These ~~significant~~assumptions ~~assumption~~are is uncertain in that itthey isare driven by future demand for our services and utilization, which could be impacted by crude oil market prices, future market conditions and technological advancements. Our fair value estimates for certain long‑lived assets require us to use significant other observable inputs, including assumptions related to market based on recent auction sales or selling prices of comparable equipment. The estimates of fair value are also subject to significant variability, are sensitive to changes in market conditions, and are reasonably likely to change in the future.

IfDuring the ~~crude~~years ~~oil~~ended ~~market~~December 31, ~~declines~~2025 orand ~~the~~2023, ~~demand~~we ~~for~~did ~~our services does~~ not ~~recover,~~recognize ~~and~~any ifimpairment of our ~~equipment~~long-lived ~~remains~~assets. ~~idle~~During ~~or underutilized,~~ the ~~estimated~~year ~~fair~~ended ~~value~~December of31, ~~such equipment may decline~~2024, ~~which~~we ~~could~~recognized ~~result~~property inand ~~future~~equipment impairment ~~charges.~~expense ~~Though the impacts~~ of ~~variations~~approximately in$188.6 ~~any~~million ~~of these factors can have compounding or offsetting impacts, a 10% decline~~ in ~~the~~connection ~~estimated~~with ~~future~~our ~~cash~~conventional ~~flows~~Tier ofII ~~our~~diesel-only ~~existing~~hydraulic ~~asset~~fracturing ~~groups~~pumping ~~will~~units ~~not~~and ~~indicate~~associated anconventional ~~impairment~~assets.

During the year ended December 31, 2024, we recorded property and equipment impairment expense of approximately $188.6 million in connection with our conventional Tier II diesel-only hydraulic fracturing pumping units and associated conventional assets. In 2022, we recorded property and equipment impairment expense of $57.5 million on our DuraStim® electric-powered hydraulic fracturing equipment within the hydraulic fracturing operating segment.

Intangible assets consist of trademark/trade name, customer relationships and favorable contracts. Trademark/trade names are amortized on a straight‑line basis over useful lives of ten and fifteen years. Customer relationships are amortized on a straight‑line basis over useful lives of six and ten years. Favorable contracts are amortized on a straight‑line basis over useful lives of thirty months and five years. Internally developed software will be amortized on a straight‑line basis over a useful life of twenty-nine months. Our estimated useful life could be sensitive to changes in market conditions and management’s judgment, and are likely to change in the future if certain events occur. Presently, there are no events or circumstances that will cause us to believe that our estimated useful life for our intangible assets are likely to change.

Goodwill

Goodwill is the excess of the consideration transferred over the fair value of the tangible and identifiable intangible assets and liabilities recognized. Goodwill is not amortized. We perform an annual impairment test of goodwill and intangible assets as of December 31, or more frequently if circumstances indicate that impairment may exist.

In connection with the AquaProp Acquisition, we added $0.9 million of goodwill in our hydraulic fracturing operating segment during the year ended December 31, 2024. We recorded goodwill impairment expense of $23.6 million in our wireline reporting unit during the year ended December 31, 2024. There were no additions to goodwill during the year ended December 31, 2023. The hydraulic fracturing operating segment was the only segment with goodwill at December 31, 2024. The wireline operating segment was the only segment with goodwill at December 31, 2023. There were no goodwill impairment losses during the year ended December 31, 2023. We performed our annual goodwill impairment test in accordance with ASC 350, Intangibles—Goodwill and Other, on December 31, 2024, at which time, we determined that the fair value of our wireline reporting unit was substantially in excess of its carrying value resulting in impairment. The quantitative impairment test we perform for goodwill utilizes certain assumptions, including forecasted equipment utilization, pricing and cost assumptions. Our discounted cash flow analysis includes significant assumptions regarding discount rates, utilization, expected profitability margin, forecasted maintenance capital expenditures, and the timing of expected cash flow. As such, our goodwill analysis incorporates inherent uncertainties that are difficult to predict in volatile economic environments and could result in impairment charges in future periods if actual results materially differ from the estimated assumptions utilized in our forecast. As of December 31, 2024, and 2023, our goodwill carrying value was $0.9 million and $23.6 million, respectively.

Leases

In accordance with ASC Topic 842, the Company determines if a contract is a lease at inception and evaluates identified leases for operating and finance lease accounting. Operating or finance lease right-of-use assets and liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. The Company uses a discount rate based on its estimated incremental borrowing rate on a collateralized basis with similar terms and economic considerations as its lease payments at the lease commencement in determining the present value of lease payments. Lease terms may include options to renew the lease or purchase the underlying assets, however, the Company typically cannot determine its intent to renew the lease or purchase the assets with reasonable certainty at inception. The Company elected the short-term lease recognition practical expedient provided by ASC 842 in which leases with a term of twelve months or less will not be recognized on the balance sheet, and the practical expedient to not separate lease and non-lease components for real estate class of assets. We elected to analogize to the measurement guidance of ASC 360 to capitalize costs incurred to place a leased asset into its intended use and to present such capitalized costs as part of the related lease right-of-use asset cost as initial direct costs.

Income Taxes

Income taxes are accounted for under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the consolidated financial statements. Under this method, deferred tax assets and liabilities are determined on the basis of differences between the consolidated financial statements and tax bases of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. We recognize deferred tax assets to the extent that we believe these assets are more likely than not to be realized. In making such a determination, we consider all positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, and the results of recent operations. If we determine that we would not be able to fully realize our deferred tax assets in the future in excess of their net recorded amount, we would record a valuation allowance, which would increase our provision for income taxes. We believe the valuation allowance is a critical accounting estimate because it is susceptible to change from period to period, requires assumptions about our future income over the lives of the deferred tax assets, and because the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations. In determining our need for a valuation allowance as of December 31, 2025, we have considered and made judgments and estimates regarding estimated future taxable income. These estimates and judgments include some degree of uncertainty and changes in these estimates and assumptions could require us to record additional valuation allowances for our deferred tax assets and the ultimate realization of tax assets depends on the generation of sufficient taxable income.

WeOur ~~recognize~~methodology ~~deferred~~for ~~tax~~recording ~~assets~~income totaxes ~~the~~requires ~~extent~~a ~~that~~significant weamount ~~believe~~of ~~these~~judgment ~~assets~~in ~~are~~the ~~more~~use ~~likely~~of ~~than~~assumptions ~~not~~and ~~to be realized~~estimates. ~~In making such a determination~~Additionally, we ~~consider~~forecast ~~all~~certain ~~positive~~tax ~~and negative evidence~~elements, ~~including~~such as future ~~reversals of existing~~ taxable ~~temporary differences~~income, ~~projected~~as ~~future~~well ~~taxable~~as ~~income,~~evaluate ~~and~~ the ~~results~~feasibility of ~~recent~~implementing ~~operations.~~tax Ifplanning westrategies. ~~determine~~Given ~~that~~the weinherent ~~would~~uncertainty ~~not~~involved bewith ~~able~~the touse ~~fully~~of ~~realize~~such ~~our~~variables, ~~deferred~~there ~~tax~~can ~~assets~~be insignificant ~~the~~variation ~~future~~between inanticipated ~~excess~~and ofactual ~~their~~results. ~~net~~Unforeseen ~~recorded~~events ~~amount,~~may wesignificantly ~~would~~impact ~~record~~these ~~a valuation allowance~~variables, ~~which~~and ~~would~~changes ~~increase~~to ~~our~~these ~~provision~~variables ~~for~~could ~~income~~have ~~taxes.~~a Inmaterial ~~determining~~impact on our ~~need~~income ~~for~~tax aaccounts. ~~valuation~~The ~~allowance~~final asdetermination of ~~December 31,~~our ~~2024,~~income wetax ~~have~~liabilities ~~considered~~involves ~~and~~the ~~made~~interpretation ~~judgments~~of ~~and~~local ~~estimates~~tax ~~regarding~~laws ~~estimated~~and ~~future~~related ~~taxable~~authorities ~~income.~~in ~~These~~each ~~estimates~~jurisdiction. ~~and~~Changes ~~judgments~~in ~~include~~the ~~some~~operating ~~degree~~environments, ofincluding ~~uncertainty and~~ changes in ~~these~~tax ~~estimates~~law, ~~and assumptions~~ could ~~require~~impact usthe todetermination ~~record~~of ~~additional valuation allowances for~~ our ~~deferred~~income tax ~~assets~~liabilities ~~and~~for ~~the~~a ~~ultimate realization of~~ tax ~~assets depends on the generation of sufficient taxable income~~year.

Our methodology for recording income taxes requires a significant amount of judgment in the use of assumptions and estimates. Additionally, we forecast certain tax elements, such as future taxable income, as well as evaluate the feasibility of implementing tax planning strategies. Given the inherent uncertainty involved with the use of such variables, there can be significant variation between anticipated and actual results. Unforeseen events may significantly impact these variables, and changes to these variables could have a material impact on our income tax accounts. The final determination of our income tax

liabilities involves the interpretation of local tax laws and related authorities in each jurisdiction. Changes in the operating environments, including changes in tax law, could impact the determination of our income tax liabilities for a tax year.

Item 7A. Quantitative and Qualitative Disclosure of Market Risks

Foreign Currency Exchange Risk

Our operations are currently conducted entirely within the U.S.; therefore, we had no significant exposure to foreign currency exchange risk in ~~2024~~2025.

Commodity Price Risk

Our materials and fuel purchases expose us to commodity price risk. Our material costs primarily include the cost of inventory consumed while performing our completion services such as proppants, perforating guns, chemicals, guar, trucking and fluid supplies. Our fuel costs consist primarily of diesel and natural gas used by our various trucks and other motorized equipment. The prices for fuel and materials in our inventory are volatile and are impacted by changes in supply and demand, as well as market uncertainty and regional shortages. Historically, we have generally been able to pass along a significant portion of our commodity price risk to our customers; however, we may be unable to do so in the future. We do not engage in commodity price hedging activities.

Interest Rate Risk

We may be subject to interest rate risk on variable rate borrowings under our ABL Credit Facility and Caterpillar Equipment Loan Agreement. We do not currently engage in interest rate derivatives to hedge our interest rate risk. The impact of a 1% increase in interest rates on our variable rate debt would have resulted in an increase in interest expense and corresponding decrease/(increase) in pre‑tax income/(loss) of approximately $0.5 million, $0.5 million, and $0.15 million, for the years ended December 31, ~~2024~~2025, ~~2023~~2024, and ~~2022~~2023, respectively.

Credit Risk

Financial instruments that potentially subject us to concentrations of credit risk are trade receivables. We extend credit to customers and other parties in the normal course of business. We have established various procedures to manage our credit exposure, including maintaining an allowance for doubtful accounts.

Item 8. Financial Statements and Supplementary Data.

FINANCIAL STATEMENTS

Reports of Independent Registered Public Accounting Firm (PCAOB ID: 49)			5356
Report of Independent Registered Public Accounting Firm (PCAOB ID: 34)			58
Consolidated Balance Sheets as of December 31, 2025 and 2024			59
Consolidated Balance Sheets as of December 31, 2024 and 2023			59
Consolidated Statements of Operations for the years ended December 31, 2025, 2024 and 2023			60
Consolidated Statements of Operations for the years ended December 31, 2024, 2023 and 2022			60
Consolidated Statements of Changes in Shareholders’ Equity for the years ended December 31, 2025, 2024 and 2023			61
Consolidated Statements of Changes in Shareholders’ Equity for the years ended December 31, 2024, 2023 and 2022			61
Consolidated Statements of Cash Flows for the years ended December 31, 2025, 2024 and 2023			62
Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023 and 2022			62
Notes to Consolidated Financial Statements			63
Notes to Consolidated Financial Statements			64

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Directors of ProPetro Holding Corp.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of ProPetro Holding Corp. and its subsidiaries (the Company) as of December 31, ~~2024~~2025 and ~~2023~~2024, the related consolidated statements of operations, shareholders' equity and cash flows for each of the ~~two~~three years in the period ended December 31, ~~2024~~2025, and the related notes to the consolidated financial statements (collectively, the financial statements). In our opinion, the financial statements ~~referred to above~~ present fairly, in all material respects, the financial position of the Company as of December 31, ~~2024~~2025 and ~~2023~~2024, and the results of its operations and its cash flows for each of the ~~two~~three years in the period ended December 31, ~~2024~~2025, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, ~~2024~~2025, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013, and our report dated February 2019, ~~2025,~~2026 expressed an unqualified opinion on the effectiveness of the Company's internal control over financial reporting.

As discussed in Notes 2 and 11 to the financial statements, the Company adopted ASU 2023-07, Segment Reporting (Topic 280) as of December 31, 2024, and changed the composition of its segment information in 2023. We also have audited the adjustments necessary to restate the 2022 segment information and to reflect the adoption of ASU 2023-07, Segment Reporting (Topic 280) to the 2022 segment information, as provided in Note 11. In our opinion, such adjustments are appropriate and have been properly applied. We were not engaged to audit, review or apply any procedures to the 2022 financial statements of the Company other than with respect to the adjustments and, accordingly, we do not express an opinion or any other form of assurance on the 2022 financial statements taken as a whole.

Basis for Opinion

These financial statements are the responsibility of the Company'’s management. Our responsibility is to express an opinion on the Company'’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit ~~matters~~matter communicated below ~~are~~is ~~matters~~a matter arising from the current period audit of the financial statements that ~~were~~was communicated or required to be communicated to the audit committee and that: (1) ~~relate~~relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective or complex judgments. The communication of a critical audit ~~matters~~matter does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit ~~matters~~matter below, providing a separate ~~opinions~~opinion on the critical audit ~~matters~~matter or on the accounts or disclosures to which ~~they~~it ~~relate~~relates.

~~Business~~Accounting ~~Combination—Aqua~~for ~~Prop,~~Power ~~LLC~~Generation Arrangements

As ~~discussed~~disclosed in Note 2 4to of the ~~consolidated~~ financial statements, the Company’s ~~completed~~power ~~the~~generation ~~acquisition~~arrangements ofinvolve ~~all~~providing ofturnkey ~~the~~power ~~outstanding~~generation ~~equity~~services ~~interests~~to incustomers ~~Aqua~~using ~~Prop~~mobile ~~LLC~~power ~~(AquaProp)~~generation onequipment ~~May~~installed ~~31,~~at ~~2024,~~customers’ ~~for~~sites. ~~total~~The ~~consideration~~evaluation ~~transferred~~ of ~~$35.8~~the ~~million,~~accounting ~~which~~implications ~~included~~of ~~contingent~~these ~~consideration~~power ~~with~~generation anarrangements ~~acquisition~~requires ~~date~~the ~~fair~~application ~~value~~ of ~~$10.9~~complex ~~million.~~accounting ~~The~~rules ~~Company~~and ~~accounted~~consideration ~~for~~of ~~this~~several ~~transaction~~factors ~~under~~which can impact the ~~acquisition~~amount ~~method~~and timing of ~~accounting~~revenue ~~for~~recognized. ~~business~~The ~~combinations~~Company ~~whereby~~evaluates whether the ~~fair~~use ~~value~~ of ~~the~~its ~~consideration~~power ~~transferred~~generation ~~was~~equipment ~~allocated~~installed at customers’ sites to ~~the~~provide ~~assets~~power ~~acquired,~~generation ~~including~~services represents a ~~customer~~lease ~~relationship~~in ~~intangible~~accordance ~~asset~~with ofthe ~~$18~~applicable accounting guidance.6 ~~million~~If a lease is identified, ~~and~~the ~~liabilities~~accounting ~~assumed~~guidance ~~based~~requires ~~upon~~management ~~their~~to ~~acquisition~~assess ~~date~~whether ~~fair~~the ~~values.~~lease ~~Management~~component ~~estimated~~is separate from the ~~fair~~nonlease ~~value~~components, ofdetermine the ~~contingent~~appropriate allocation of consideration bybased ~~applying~~on arelative ~~probability-weighted~~standalone ~~expected~~selling ~~return~~prices, ~~method~~and ~~for~~evaluate the ~~different~~resulting ~~scenarios~~revenue ~~that~~recognition ~~may~~and ~~occur~~lease ~~based~~classification ~~upon~~implications. For the ~~amount~~power ofgeneration ~~additional~~arrangements ~~equipment~~entered ~~delivered~~into byduring the ~~seller,~~year atended ~~the~~December ~~request~~31, of2025, ~~the~~management ~~Company,~~determined ~~and~~that ~~the~~an ~~amount~~operating oflease ~~wet~~existed ~~sand~~in ~~expected~~the tocontract beand ~~delivered~~the bynonlease ~~such~~components, ~~equipment~~primarily ~~within~~power ageneration ~~30-month~~and ~~period.~~related ~~Management~~support ~~estimated~~activities, represent the ~~fair~~predominant ~~value~~components of the ~~customer~~contract; ~~relationship~~accordingly ~~intangible~~the ~~asset~~Company ~~using~~has aaccounted ~~discounted~~for ~~cash~~the ~~flow~~lease ~~method~~and ~~whereby~~nonlease ~~forecasted~~components ~~cash~~as ~~flows~~a ~~expected~~single toperformance beobligation ~~derived~~and ~~from~~recognizes the ~~intangible~~revenue ~~asset~~ over ~~the~~time ~~economic~~as ~~life of~~ the ~~asset,~~Company ~~adjusted~~delivers ~~for~~the ~~expected attrition, are discounted to present value~~services.

We identified the valuation of the customer relationship intangible asset and the contingent consideration liability at the AquaProp acquisition date as a critical audit matter because of the significant assumptions management used in estimating the fair values, including forecasted cash flows and the selection of a discount rate for the customer relationship intangible asset and forecasted tonnage of wet sand expected to be delivered for the contingent consideration. Auditing management’s assumptions involved a high degree of auditor judgment and an increase in audit effort, including the use of valuation specialists, due to the impact these assumptions could have on the accounting estimates.56

~~Our~~We identified the Company’s evaluation of the accounting treatment of the power generation arrangements as a critical audit ~~procedures~~matter ~~related~~because of the complexity involved in management’s evaluation of the contracts, including management’s interpretation and application of the applicable accounting rules and the judgments required by management to analyze the ~~valuation~~nature of the ~~customer~~services ~~relationship~~provided, ~~intangible~~assess whether the embedded lease conveyed the right to control the use of an identified asset, and to estimate standalone selling prices for the ~~contingent~~nonlease ~~consideration~~components. ~~liability~~Auditing ~~included~~management’s accounting conclusions involved a high degree of auditor judgment and an increase in audit effort due to the ~~following,~~impact ~~among~~management’s ~~others:~~conclusions could have on the Company’s accounting for the power generation arrangements.

~~•We~~Our ~~obtained~~audit anprocedures ~~understanding of the relevant controls~~ related to ~~management~~the Company’s ~~business~~evaluation ~~combination~~of ~~fair~~the ~~value~~accounting ~~estimates~~treatment ~~and~~of ~~tested~~the ~~such~~power ~~controls~~generation ~~for~~arrangements ~~design~~included ~~and~~the ~~operating effectiveness~~following, ~~including~~among ~~controls over management’s review of significant assumptions used in the fair value estimates.~~others:

•We ~~read~~obtained ~~the~~an ~~purchase~~understanding ~~and~~of ~~sale~~the ~~agreement~~relevant controls related to ~~understand~~management’s ~~and~~evaluation ~~evaluate~~of the ~~terms~~power ofgeneration ~~the~~arrangements ~~acquisition~~and tested such controls for design and operating effectiveness.

•We ~~tested~~obtained management’s technical accounting memorandum and evaluated the reasonableness of management’s ~~forecasts~~conclusions ofon ~~cash~~the ~~flows~~accounting intreatment of the ~~valuation~~power ofgeneration arrangements by assessing whether the ~~customer~~Company’s ~~relationship~~conclusions ~~intangible~~regarding ~~asset~~the byidentification ~~comparing~~of ~~them~~a tolease, ~~historical~~the ~~results~~classification of the lease, and ~~evaluating~~revenue ~~publicly~~recognition ~~available~~principles ~~industry~~were ~~information~~consistent with relevant accounting guidance.

•We ~~tested~~sampled the ~~reasonableness of management~~Company’s ~~forecasts~~power ofgeneration ~~tonnage~~arrangements ofand ~~wet~~read ~~sand~~the tocustomer beagreements ~~delivered~~to byassess ~~comparing~~ the ~~estimated~~existence ~~capacity~~ of ~~each~~identified ~~piece~~assets ~~of equipment to in-process contracts~~ and ~~considering~~whether ~~the~~control ~~impact~~ of ~~the~~those ~~estimated~~assets ~~timing~~was ofconveyed ~~the delivery~~ to the ~~estimate of fair value~~customer.

•We ~~utilized~~tested ~~our~~management’s ~~valuation~~allocation ~~specialists~~of toconsideration ~~assist~~between lease and nonlease components in ~~the~~its ~~following~~power ~~procedures~~generation arrangements, ~~among~~which ~~others:~~management based on standalone selling prices, by comparing the inputs in management’s allocation to applicable contract terms and available market data and testing the mathematical accuracy of management's calculations.

◦Evaluating the appropriateness of the valuation models used by management to estimate the fair values of the customer relationship intangible asset and contingent consideration and testing their mathematical accuracy.

◦Evaluating the appropriateness of the methodology used by management to develop the attrition rate for the customer relationship.

◦Comparing the source information underlying the determination of the discount rates to publicly available market data and verifying the accuracy of the calculations.

Impairment of Long-lived Assets—Fair Value of Conventional Tier II Diesel-only Hydraulic Fracturing Pumping Units and Associated Conventional Assets

As discussed in Notes 2 and 5 to the consolidated financial statements, at September 30, 2024, the Company performed a recoverability assessment on the long-lived assets in its conventional Tier II diesel-only hydraulic fracturing pumping units and associated conventional assets asset group (the “Tier II Units”). In performing the recoverability assessment, the Company first compared the carrying value of the asset group to the estimated undiscounted cash flows to be generated over the remaining useful life of the asset group’s primary asset. Because the carrying value of the asset group exceeded the estimated undiscounted cash flows, the Company then estimated the fair value of the asset group, utilizing both a market approach and a cost approach, and recorded an impairment charge of $188.6 million.

We identified management’s estimated fair value of the Tier II Units as a critical audit matter because of the significant assumptions management used in estimating the fair value of the assets, including the selection of the valuation methods used to estimate fair value, the determination of the highest and best use of the assets, and consideration of the appropriateness of market data, among others. Auditing management’s assumptions involved a high degree of auditor judgment and an increase in audit effort, including the use of our valuation specialists, due to the impact these assumptions could have on the accounting estimate.

Our audit procedures related to the Company’s estimate of the fair value of the Tier II Units included the following, among others:

•We obtained an understanding of the relevant controls related to management’s estimate of fair value of the Tier II Units and tested such controls for design and operating effectiveness, including controls over management’s review of the significant assumptions used in estimating the fair value of the underlying assets.

•We tested the completeness and accuracy of the Tier II Units by agreeing the carrying values and other relevant information to the underlying support.

•We utilized our valuation specialists to assist in the following procedures, among others:

◦Evaluating the appropriateness of the valuation models used by management to estimate the fair value of the Tier II Units and testing their mathematical accuracy.

◦Evaluating management’s determination of the highest and best use of the Tier II Units.

◦Corroborating managements estimates of fair value by comparing such estimates to publicly available market data.

Goodwill Impairment Testing—Wireline Reporting Unit

As discussed in Notes 2 and 5 to the consolidated financial statements, management tests the Company’s goodwill for impairment, at the reporting unit level, at December 31 of each fiscal year, or more frequently if events or changes in circumstances indicate the goodwill might be impaired. To test goodwill for impairment, management compares the estimated fair value of the reporting unit to the carrying amount, including the recorded goodwill. An impairment is recorded when the carrying value of the reporting unit exceeds its estimated fair value. The Company's estimated reporting unit fair value is based on a combination of income and market approaches. The income approach involves the use of a discounted cash flow method with the cash flow projections discounted at an appropriate discount rate. The market approach involves the use of comparable public companies’ market multiples in estimating the fair value. During the year ended December 31, 2024, the Company recorded a goodwill impairment charge of $23.6 million in its Wireline reporting unit, which represented a full impairment of the goodwill in that reporting unit.

We identified the valuation of the Wireline reporting unit as a critical audit matter because of the significant assumptions management used in estimating the fair value of the reporting unit, including revenue growth rates and margin percentages used in the projected cash flows, the determination of the discount rate applicable to the reporting unit, and the identification of comparable guideline public companies and market multiples. Auditing management’s assumptions involved a high degree of auditor judgment and an increase in audit effort, including the use of valuation specialists, due to the impact these assumptions could have on the estimate of fair value.

Our audit procedures related to the estimated fair value of the Wireline reporting unit included the following, among others:

•We obtained an understanding of the relevant controls related to management’s impairment assessment and tested such controls for design and operating effectiveness, including controls over management’s review of the significant assumptions utilized in the fair value measurement.

•We tested the reasonableness of management’s forecasts of cash flows, including revenue and margins, by comparing them to historical results and evaluating publicly available industry information.

•We tested the underlying data used by management in the development of the forecasts of cash flows for accuracy and completeness by agreeing it to source data.

•We utilized our valuation specialists to assist in the following procedures, among others:

◦Evaluating the appropriateness of the Company's valuation methodology and testing the mathematical accuracy.

◦Testing the reasonableness of the discount rate using in the income approach by comparing the inputs used by management to publicly available market data.

◦Evaluating the comparability of the guideline public companies identified by management based upon publicly available market data.

◦Corroborating the market multiples selected by the Company in the market approach by comparing them publicly available market data.

/s/ RSM US LLP

RSM US LLP

We have served as the Company's auditor since 2023.

Houston, Texas

February 2019, ~~2025~~2026

5657

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Directors of ProPetro Holding Corp.

Opinion on the Internal Control ~~over~~Over Financial Reporting

We have audited ProPetro Holding Corp.'s (the Company) internal control over financial reporting as of December 31, ~~2024~~2025, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, ~~2024~~2025, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission in 2013.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements of the Company and our report dated February 2019, ~~2025~~2026, expressed an unqualified opinion.

As described in Management’s Report on Internal Control over Financial Reporting, management has excluded Aqua Prop, LLC from its assessment of internal control over financial reporting as of December 31, 2024, because it was acquired by the Company in a purchase business combination in the second quarter of 2024. We have also excluded Aqua Prop, LLC from our audit of internal control over financial reporting. Aqua Prop, LLC is a wholly owned subsidiary whose total assets and revenue represent approximately 4.9% and 3.1%, respectively, of the related consolidated financial statement amounts as of and for the year ended December 31, 2024.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control ~~over~~Over Financial Reporting

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ RSM US LLP

RSM US LLP

Houston, Texas

February 2019, ~~2025~~2026

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Directors of

ProPetro Holding Corp. and Subsidiaries

Opinion on the Financial Statements

We have audited, before the effects of the retrospective adjustments to the disclosures for a change in the composition of reportable segments and the adoption of ASU No. 2023-07, Segment Reporting, discussed in Note 11 to the consolidated financial statements, the consolidated statements of operations, shareholders' equity, and cash flows of ProPetro Holding Corp. and Subsidiaries (the “Company”), for the year ended December 31, 2022, and the related notes (collectively, referred to as, the “financial statements”) (the 2022 financial statements before the effects of the retrospective adjustments discussed in Note 11 to the financial statements are not presented herein). In our opinion, the 2022 financial statements, before the effects of the retrospective adjustments to the disclosures for a change in the composition of reportable segments and the adoption of ASU No. 2023-07, Segment Reporting, discussed in Note 11 to the financial statements, present fairly, in all material respects, the results of the Company’s operations and cash flows for the year ended December 31, 2022, in conformity with accounting principles generally accepted in the United States of America.

We were not engaged to audit, review, or apply any procedures to the retrospective adjustments to the disclosures for a change in the composition of reportable segments and the adoption of ASU No. 2023-07, Segment Reporting discussed in Note 11 to the financial statements, and accordingly, we do not express an opinion or any other form of assurance about whether such retrospective adjustments are appropriate and have been properly applied. Those retrospective adjustments were audited by other auditors.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audit included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audit also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audit provided a reasonable basis for our opinion.

/s/ DELOITTE & TOUCHE LLP

Houston, Texas

February 23, 2023

We began serving as the Company's auditor since 2013. In 2023, we became the predecessor auditor.

PROPETRO HOLDING CORP.

CONSOLIDATED BALANCE SHEETS

AS OF DECEMBER 31, ~~2024~~2025 AND ~~2023~~2024

(In thousands, except share data)

	2024		2023
	2025		2024
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	5091,~~443~~334	$	3350,~~354~~443
Accounts receivable - net of allowance for credit losses of $0 and $236, respectively	195,994		237,012
Accounts receivable - net of allowance for credit losses of $0 and $0, respectively	200,753		195,994
Inventories	1613,~~162~~323		1716,~~705~~162
Prepaid expenses	1719,~~719~~896		1417,~~640~~719
Short-term investment, net	7,849		7,745
Short-term investment	—		7,849
Other current assets	41,~~054~~398		~~353~~4,054
Total current assets	~~292~~326,~~221~~704		~~310~~292,~~809~~221
PROPERTY AND EQUIPMENT - net of accumulated depreciation	~~688~~793,~~225~~475		~~967~~688,~~116~~225
OPERATING LEASE RIGHT-OF-USE ASSETS	~~132~~99,~~294~~787		78132,~~583~~294
FINANCE LEASE RIGHT-OF-USE ASSETS	3010,~~713~~637		4730,~~449~~713
OTHER NONCURRENT ASSETS:
Goodwill	920		~~23,624~~920
Intangible assets - net of amortization	6455,~~905~~476		5064,~~615~~905
Other noncurrent assets	143,~~367~~891		214,~~116~~367
Total other noncurrent assets	8060,~~192~~287		7680,~~355~~192
TOTAL ASSETS	$	1,~~223~~290,~~645~~890	$	1,~~480~~223,~~312~~645
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	92115,~~963~~009	$	~~161~~92,~~441~~963
Accrued and other current liabilities	7065,~~923~~981		7570,~~616~~923
Operating lease liabilities	39,063		17,029
Interim debt - net of debt issuance costs	2,113		—
Finance lease liabilities	19,317		17,063
Current maturities of long-term debt - net of debt issuance costs	13,844		—
Total current liabilities	222,266		271,149
Operating lease liabilities	43,572		39,063
DEFERRED INCOME TAXES	59,770		93,105
Finance lease liabilities	12,442		19,317
LONG-TERM DEBT	45,000		45,000
Total current liabilities	252,961		222,266
NONCURRENT OPERATING LEASE LIABILITIES	58,849		38,600
DEFERRED INCOME TAXES	63,433		59,770
NONCURRENT FINANCE LEASE LIABILITIES	13,187		30,886
LONG-TERM DEBT - net of debt issuance costs and current maturities	105,613		45,000
OTHER LONG-TERM LIABILITIES	8,300		3,180
NONCURRENT OPERATING LEASE LIABILITIES	35,641		58,849
Total liabilities	407,372		481,920
NONCURRENT FINANCE LEASE LIABILITIES	—		13,187
OTHER LONG-TERM LIABILITIES	3,400		8,300
Total liabilities	461,048		407,372
COMMITMENTS AND CONTINGENCIES (Note 18)
SHAREHOLDERS’ EQUITY:
Preferred stock, $0.001 par value, 30,000,000 shares authorized, none issued, respectively	—		—
Common stock, $0.001 par value, 200,000,000 shares authorized, 102,994,958 and 109,483,281 shares issued and outstanding, respectively	103		109
Common stock, $0.001 par value, 200,000,000 shares authorized, 104,310,266 and 102,994,958 shares issued and outstanding, respectively	104		103
Additional paid-in capital	~~884~~897,~~995~~739		~~929~~884,~~249~~995
Retained earnings (accumulated deficit)	(68,825)		69,034
Accumulated deficit	(68,001)		(68,825)
Total shareholders’ equity	~~816~~829,~~273~~842		~~998~~816,~~392~~273
TOTAL LIABILITIES AND SHAREHOLDERS’ EQUITY	$	1,~~223~~290,~~645~~890	$	1,~~480~~223,~~312~~645

See notes to consolidated financial statements.

PROPETRO HOLDING CORP.

CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE YEARS ENDED DECEMBER 31, ~~2024~~2025, ~~2023~~2024 AND ~~2022~~2023

(In thousands, except per share data)

	2024		2023		2022
	2025		2024		2023
REVENUE - Service revenue	$	1,~~444~~269,~~286~~158	$	1,~~630~~444,~~399~~286	$	1,~~279~~630,~~701~~399
COSTS AND EXPENSES:
Cost of services (exclusive of depreciation and amortization)	1968,~~065,514~~175		1,~~131~~065,~~801~~514		~~882~~1,~~820~~131,801
General and administrative expenses (inclusive of stock‑based compensation)	~~114~~107,~~323~~558		114,~~354~~323		~~111~~114,~~760~~354
Depreciation and amortization	~~211~~174,~~733~~896		~~180~~224,~~886~~109		~~128~~219,~~108~~608
Property and equipment impairment expense	~~188,601~~—		—188,601		~~57,454~~—
Goodwill impairment expense	~~23,624~~—		—23,624		—
Loss on disposal of assets and businesses, net	7,451		73,015		102,150
Loss (gain) on disposal of assets and businesses, net	12,179		(4,925)		34,293
Total costs and expenses	1,~~611~~262,~~246~~808		1,~~500~~611,~~056~~246		1,~~282~~500,~~292~~056
OPERATING (LOSS) INCOME	(166,960)		130,343		(2,591)
OPERATING INCOME (LOSS)	6,350		(166,960)		130,343
OTHER (EXPENSE) INCOME:
OTHER INCOME (EXPENSE):
Interest expense	(78,~~815~~238)		(57,~~308~~815)		(15,~~605~~308)
Other income (expense), net	59,~~531~~709		(95,~~533)~~531		11(9,~~582~~533)
Total other income (expense)	(2,284)		(14,841)		9,977
Total other income (expense), net	1,471		(2,284)		(14,841)
INCOME (LOSS) BEFORE INCOME TAXES	~~(169~~7,~~244)~~821		~~115~~(169,~~502~~244)		7115,~~386~~502
INCOME TAX BENEFIT (EXPENSE)	31,385		(29,868)		(5,356)
INCOME TAX (EXPENSE) BENEFIT	(6,997)		31,385		(29,868)
NET (LOSS) INCOME	$	(137,859)	$	85,634	$	2,030
NET INCOME (LOSS)	$	824	$	(137,859)	$	85,634
NET (LOSS) INCOME PER COMMON SHARE:
NET INCOME (LOSS) PER COMMON SHARE:
Basic	$	(10.~~31)~~01	$	0(1.7631)	$	0.0276
Diluted	$	(10.~~31)~~01	$	0(1.7631)	$	0.0276
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING:
Basic	~~105~~103,~~469~~838		~~113~~105,~~004~~469		~~105~~113,~~868~~004
Diluted	105,~~469~~398		~~113~~105,~~416~~469		~~106~~113,~~939~~416

See notes to consolidated financial statements.

PROPETRO HOLDING CORP.

CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

FOR THE YEARS ENDED DECEMBER 31, ~~2024~~2025, ~~2023~~2024 AND ~~2022~~2023

(In thousands)

	Common Stock
	Shares	Amount		Additional Paid‑In Capital		Retained Earnings (Accumulated Deficit)		Total
BALANCE - January 1, 2022	103,437	$	104	$	844,828	$	(18,630)	$	826,302
BALANCE - January 1, 2023	114,515	$	114	$	970,519	$	(16,600)	$	954,033
Stock‑based compensation cost	—	—		21,881		—		21,881
Issuance of equity award—net	11,078	10		107,689		—		107,699
Tax withholdings paid for net settlement of equity awards	—	—		(3,879)		—		(3,879)
Net income	—	—		—		2,030		2,030
BALANCE - December 31, 2022	114,515	$	114	$	970,519	$	(16,600)	$	954,033
Stock‑based compensation cost	—	—		14,450		—		14,450
Issuance of equity awards—net	763	1		(1)		—		—
Issuance of equity award, net	763	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(3,543)		—		(3,543)
Share repurchases	(5,795)	(6)		(51,732)		—		(51,738)
Excise tax on share repurchases	—	—		(444)		—		(444)
Net income	—	—		—		85,634		85,634
BALANCE - December 31, 2023	109,483	$	109	$	929,249	$	69,034	$	998,392
Stock‑based compensation cost	—	—		17,288		—		17,288
Issuance of equity—net	707	1		(1)		—		—
Issuance of equity awards, net	707	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(1,909)		—		(1,909)
Share repurchases	(7,195)	(7)		(59,101)		—		(59,108)
Excise tax on share repurchases	—	—		(531)		—		(531)
Net loss	—	—		—		(137,859)		(137,859)
BALANCE - December 31, 2024	102,995	$	103	$	884,995	$	(68,825)	$	816,273
Stock‑based compensation cost	—	—		16,946		—		16,946
Issuance of equity, net	1,315	1		(1)		—		—
Tax withholdings paid for net settlement of equity awards	—	—		(4,201)		—		(4,201)
Net income	—	—		—		824		824
BALANCE - December 31, 2025	104,310	$	104	$	897,739	$	(68,001)	$	829,842

See notes to consolidated financial statements.

PROPETRO HOLDING CORP.

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, ~~2024~~2025, ~~2023~~2024 AND ~~2022~~2023

(In thousands)

	2024		2023		2022
	2025		2024		2023
CASH FLOWS FROM OPERATING ACTIVITIES:
Net (loss) income	$	(137,859)	$	85,634	$	2,030
Net income (loss)	$	824	$	(137,859)	$	85,634
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	~~211~~174,~~733~~896		~~180~~224,~~886~~109		~~128~~219,~~108~~608
Property and equipment impairment expense	~~188,601~~—		—188,601		~~57,454~~—
Goodwill impairment expense	~~23,624~~—		—23,624		—
Deferred income tax (benefit) expense	(33,336)		27,840		4,213
Deferred income tax expense (benefit)	3,663		(33,336)		27,840
Amortization of deferred debt issuance costs	438		359		785
Amortization of deferred financing origination and debt issuance costs	504		438		359
Stock‑based compensation	1716,~~288~~946		1417,~~450~~288		2114,~~881~~450
Provision for credit losses	—		34—		~~202~~34
Loss on disposal of assets and businesses, net	7,451		73,015		102,150
Loss (gain) on disposal of assets and businesses, net	12,179		(4,925)		34,293
Unrealized (gain) loss on short-term investment	(~~105~~2,355)		~~2,538~~(105)		12,~~570~~538
Business acquisition contingent consideration adjustments	(24,~~600~~900)		—(2,600)		—
Noncash income from settlement with equipment manufacturer	—		—		(2,668)
Changes in operating assets and liabilities:
Accounts receivable	51(4,~~498~~759)		~~(12~~51,~~408)~~498		(6612,~~900~~408)
Other current assets	~~(2,301)~~913		(~~831~~2,301)		~~354~~(831)
Inventories	12,~~543~~840		(61,~~017)~~543		~~124~~(6,017)
Prepaid expenses	1(2,~~327~~177)		(61,~~143)~~327		~~743~~(6,143)
Accounts payable	~~(64~~9,~~501)~~573		(1164,~~429~~501)		27(11,~~428~~429)
Accrued and other current liabilities	~~(10~~23,~~506)~~460		26(10,~~814~~506)		2226,~~955~~814
Net cash provided by operating activities	~~252~~231,~~295~~607		~~374~~252,~~742~~295		~~300~~374,~~429~~742
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures	(~~140~~186,~~297~~316)		(~~370~~140,~~869~~297)		(~~319~~370,~~683~~869)
Business acquisitions, net of cash acquired	~~(21,038)~~—		(2221,~~215~~038)		(3822,~~639~~215)
Proceeds from sale of assets	623,~~236~~505		86,~~957~~236		8,~~577~~957
Net cash used in investing activities	(155,099)		(384,127)		(349,745)
Proceeds from note receivable from sale of business	13,000		—		—
Net cash used in investing activities	(149,811)		(155,099)		(384,127)
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from borrowings	—		~~30,000~~—		30,000
Repayments of borrowings	—		~~(15,000)~~—		—(15,000)
Payments of finance lease obligation	(17,676)		(4,663)		—
Payments of finance lease obligations	(18,513)		(17,676)		(4,663)
Repayments of insurance financing	(970)		—		—
Repayments of equipment financing term loans	(3,571)		—		—
Payment of debt issuance costs	—		(1,179)		(824)
Repayments of insurance financing	(4,510)		(970)		—
Proceeds from exercise of equity awards	—		—		963
Payment of financing origination and debt issuance costs	(2,807)		—		(1,179)
Tax withholdings paid for net settlement of equity awards	(1,909)		(3,543)		(3,879)
Payment of business acquisition deferred cash consideration	(6,773)		—		—
Share repurchases	(59,108)		(51,738)		—
Tax withholdings paid for net settlement of equity awards	(4,200)		(1,909)		(3,543)
Payment of excise taxes on share repurchases	(444)		—		—
Share repurchases	—		(59,108)		(51,738)
Net cash used in financing activities	(80,107)		(46,123)		26,260
Payment of excise taxes on share repurchases	(531)		(444)		—
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH	17,089		(55,508)		(23,056)
Net cash used in financing activities	(40,905)		(80,107)		(46,123)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH — Beginning of year	33,354		88,862		111,918
NET INCREASE (DECREASE) IN CASH, CASH EQUIVALENTS AND RESTRICTED CASH	40,891		17,089		(55,508)
CASH, CASH EQUIVALENTS AND RESTRICTED CASH — End of year	$	50,443	$	33,354	$	88,862
CASH, CASH EQUIVALENTS AND RESTRICTED CASH — Beginning of year	50,443		33,354		88,862
CASH AND CASH EQUIVALENTS — End of year	$	91,334	$	50,443	$	33,354

See notes to consolidated financial statements.

PROPETRO HOLDING CORP. CONSOLIDATED STATEMENTS OF CASH FLOWS (Continued)FOR THE YEARS ENDED DECEMBER 31, 2024, 2023 AND 2022

(In thousands)

The following table provides a reconciliation of cash, cash equivalents and restricted cash to amounts reported within the consolidated balance sheets:

	2024		2023		2022
Summary of cash, cash equivalents and restricted cash
Cash and cash equivalents	$	50,443	$	33,354	$	78,862
Restricted cash	—		—		10,000
Total cash, cash equivalents and restricted cash — End of year	$	50,443	$	33,354	$	88,862

See notes to consolidated financial statements.

PROPETRO HOLDING CORP.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND HISTORY

ProPetro Holding Corp. (“Holding”), a Texas corporation ~~was~~ formed on April 14, 2007, ~~and it~~ is a holding company for its wholly owned subsidiaries ProPetro Services, Inc., a Texas corporation (“Services”), Silvertip Completion Services Operating, LLC, a Delaware limited liability company (“Silvertip”), Aqua Prop, LLC, a Texas limited liability company (“AquaProp”) and ProPetro Energy Solutions, LLC, a Texas limited liability company (“PROPWR”). Services, Silvertip and AquaProp together ~~offer~~provide hydraulic fracturing, wireline, cementing, wet sand solutions and other complementary services to oil and gas producers, located primarily in Texas and New Mexico. PROPWR ~~has~~provides ~~not~~turnkey ~~begun any revenue-generating activities yet and was formed to provide~~ power generation services to oil and gas producers and non-oil and gas applications such as general industrial projects and data centers, ~~located~~using ~~primarily~~mobile inpower ~~Texas~~generation ~~and~~equipment ~~New~~installed ~~Mexico~~at ~~and~~customers’ ~~will do business as PROPWR~~sites. Holding was converted and incorporated as a Delaware Corporation on March 8, 2017.

Unless otherwise indicated, references in these notes to consolidated financial statements to “ProPetro Holding Corp.,” “the Company,” “we,” “our,” “us,” or like terms refer to Holding, Services, Silvertip, AquaProp, and PROPWR.

OnIn ~~November~~December 1, 2024, we ~~sold~~formed ~~our~~a ~~cementing~~new ~~business~~subsidiary, ~~located~~ProPetro inEnergy ~~Vernal~~Solutions, ~~Utah, to Big 4 Services~~ LLC, adoing ~~Wyoming~~business ~~limited~~as ~~liability company (“Big 4”)~~PROPWR, ~~solely~~which ~~owned~~provides byturnkey apower ~~former~~generation ~~employee~~services asto ~~part~~oil ofand agas ~~strategic~~producers ~~repositioning.~~and ~~We received a promissory note~~ for ~~$13.0~~general ~~million~~industrial asprojects ~~consideration.~~and ~~The~~data ~~note~~centers ~~receivable~~using ismobile ~~secured~~power bygeneration ~~substantially~~equipment ~~all~~installed ~~assets~~at ~~of Big 4 and the former employee~~customers’s ~~ownership interests in and distributions from Big 4~~sites. ~~The~~This ~~note~~subsidiary ~~receivable~~began isrevenue-generating toactivities beduring ~~paid to~~ the ~~Company~~third inquarter ~~quarterly installments with interest~~ of ~~10%~~fiscal ~~per~~year ~~annum from March 31,~~ 2025 toand ~~December~~has ~~31,~~entered ~~2029.~~into Wecontractual ~~recorded~~arrangements awith ~~gain~~equipment onmanufacturers ~~disposal of $8.2 million related~~ to ~~the~~purchase ~~sale~~mobile ofnatural ~~the~~gas-fueled ~~business~~power ~~within~~generation ~~loss~~equipment, onincluding ~~disposal~~turbine ofgenerator ~~assets and business within our consolidated statement of operations for the year ended December 31~~sets, ~~2024.~~reciprocating ~~The former employee was part of our cementing operations until November 1~~engines, ~~2024~~auxiliary equipment and isbattery noenergy ~~longer~~storage ~~affiliated~~solution ~~with the Company~~equipment. ~~The Company does not expect to have any significant continuing involvement with Big 4 other than collection of the note receivable.~~

On ~~May~~November 311, 2024, we ~~consummated~~sold ~~the~~our ~~acquisition~~cementing ofbusiness ~~all~~located ofin ~~the~~Vernal, ~~outstanding~~Utah, e

Filing Compare · ProPetro Holding Corp.