NYSE: USAC

We have focused our compression services in unconventional resource plays throughout the U.S., including the Utica, Marcellus, Permian, Denver-Julesburg, Eagle Ford, Mississippi Lime, Granite Wash, Woodford, Barnett, and Haynesville, and following the J-W Power Acquisition, the Bakken. According to studies promulgated by the EIA, the production and transportation volumes in these unconventional plays, namely tight oil and gas shale plays, are expected to collectively increase over the long term. Furthermore, changes in production volumes and pressures of shale plays over time require a wider range of compression service levels than in conventional basins. We believe we are well-positioned to meet these changing operating conditions due to the operational design flexibility inherit within our compression-unit fleets.

Our business includes compression services serving infrastructure applications, including centralized natural gas gathering systems and processing facilities, which utilize large-horsepower compression units and also gas lift applications on crude oil wells targeted by horizontal drilling techniques. Gas lift is a process by which natural gas is injected into the production tubing of an existing producing well to reduce hydrostatic pressure and allow the oil to flow at a higher rate. This process, and other artificial-lift technologies are critical to the enhancement of oil production from horizontal wells operating in tight shale plays.

We operate a fleet of compression units with an average age of approximately 13 years as of December 31, 2025 and a useful life that could potentially extend decades when properly maintained. We acquire our compression units primarily from third-party fabricators who build the units to our specifications, utilizing specific components from original equipment manufacturers and assembling the units in a manner that provides us the ability to meet certain operating condition thresholds. Our standard new-build compression units generally are configured for multiple compression stages, which allows us to operate our units across a broad range of operating conditions. The design flexibility of our units, particularly in midstream applications, allows us to enter into longer-term contracts and reduces the redeployment risk of our horsepower in the field. Our modern and standardized fleet, decentralized field level operating structure and technical proficiency in predictive and preventive maintenance and overhaul operations have enabled us to achieve average service run times consistently at or above the levels required by our customers and maintain high overall utilization rates for our fleet.

As part of our services, we engineer, design, operate, service, and repair our compression units and maintain related support inventory and equipment. The compression units in our modern fleet are designed to be easily adaptable to fit our customers’ changing compression requirements. Focusing on the needs of our customers and providing them with reliable and flexible compression services in geographic areas of attractive production helps us to generate stable and predictable cash flows in the near term.

We provide compression services to our customers under fixed-fee contracts with initial contract terms that, as of December 31, 2025, typically range from six months to five years, depending on the application and location of the compression unit. We typically continue to provide compression services at a specific location beyond the initial contract term, either through contract renewal or on a month-to-month or longer basis. We primarily enter into fixed-fee contracts whereby our customers are required to pay our monthly fee even during periods of limited or disrupted throughput, which enhances the stability and predictability of our cash flows. We bill most of our customers in advance of the service date and also typically utilize annual inflation adjustments in our term contracts. We are not directly exposed to commodity price risk because we do not take title to the natural gas or crude oil involved in our services and because the natural gas used as fuel by our compression units is supplied by our customers without cost to us.

We provide compression services to major oil companies and independent producers, processors, gatherers and transporters of natural gas and crude oil. Regardless of the application for which our services are provided, our customers rely on the availability of the equipment used to provide compression services and our expertise to maximize the throughput of product, reduce fuel costs and minimize emissions. Our customers may have compression demands in conjunction with their field development projects in areas of the U.S. where we are not currently operating, and we continually consider further expansion

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of our geographic areas of operation in the U.S. based upon the level of customer demand. Our modern, flexible fleet of compression units, which have been designed to be rapidly deployed and redeployed throughout the country, provides us with opportunities to expand into other areas with both new and existing customers.

We also own and operate a fleet of equipment used to provide natural gas treating services, such as carbon dioxide and hydrogen sulfide removal and natural gas cooling and dehydration, to natural gas producers and midstream companies. Additionally, as a result of the J-W Power Acquisition, we also own and operate specialized manufacturing facilities for the manufacture of compression units.

Our assets and operations are organized into a single reportable segment and all are located and operated within the U.S. See our consolidated financial statements, and the notes thereto, in Part II, Item 8 “Financial Statements and Supplementary Data” for financial information on our operations and assets; such information is incorporated herein by reference.

Recent Developments

On January 12, 2026, the Partnership and USA Compression Partners, LLC, a wholly owned subsidiary of the Partnership, completed the J-W Power Acquisition, pursuant to which USA Compression Partners, LLC purchased all of the issued and outstanding capital stock of J-W Energy from Westerman, Ltd. for aggregate consideration of approximately $860.0 million, subject to customary purchase price adjustments, consisting of (i) 18,175,323 common units representing limited partner interests in the Partnership and (ii) approximately $430.0 million in cash. Upon consummation of the J-W Power Acquisition, J-W Power and J-W Energy became wholly owned indirect subsidiaries of the Partnership.

The J-W Power Acquisition added approximately 0.8 million active horsepower and 1.0 million total horsepower to our fleet across key regions including the Northeast, Mid-Con, Rockies, Gulf Coast, Bakken and Permian Basin. J-W Power also owns and operates specialized manufacturing facilities that support its internal compression requirements and those of third-party customers.

Our Relationship with Energy Transfer LP

We share certain services with the owner of our General Partner, Energy Transfer. Under this shared service model, we share personnel and resources in certain departments, including information technology, accounting, and human resources, which increases efficiencies and support across our organization.

As of February 12, 2026, Energy Transfer owned 100% of the membership interest in our General Partner and 46,056,228 of our common units, which constituted a 32% limited partner interest in us. Given the significant ownership, we believe Energy Transfer will be motivated to promote and support the successful execution of the shared services model, as well as our overall business strategy.

For additional information on our related party transactions with entities affiliated with Energy Transfer, see Note 14 to our consolidated financial statements in Part II, Item 8 “Financial Statements and Supplementary Data”.

Our Operations

Compression Services

We provide compression services for a fixed monthly service fee. As part of our services, we engineer, design, operate, service, and repair our fleet of compression units and maintain related support inventory and equipment. In certain instances, we also engineer, design, install, operate, service, and repair certain ancillary equipment used in conjunction with our compression services. We consistently have provided average service run times at or above the levels required by our customers. In general, our team of field technicians services only our compression fleet and ancillary equipment. In certain circumstances we service third-party owned equipment. As a result of the J-W Power Acquisition, we also own two compression fabrication facilities.

Our Compression Fleet

The fleet of compression units that we own and use to provide compression services consists of specially engineered compression units that utilize standardized components, principally engines manufactured by Caterpillar Inc. and compressor frames and cylinders manufactured by Ariel Corporation. Our units can be rapidly and cost effectively modified for specific customer applications. As of December 31, 2025, the average age of our compression units was approximately 13 years. Our modern, standardized compression unit fleet as of December 31, 2025 is powered primarily by the Caterpillar 3400, 3500, and 3600 engine classes, which range from 400 to 5,000 horsepower per unit. These larger-horsepower units, which we define as 400 horsepower per unit or greater, represented 87.6% of our total fleet horsepower (including compression units on order) as

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of December 31, 2025. The remainder of our fleet as of December 31, 2025 consists of smaller-horsepower units ranging from 40 horsepower to 399 horsepower that are used primarily in gas lift applications. The unit fleet we acquired as a result of the J-W Power Acquisition consists of primarily of Caterpillar 3300, 3400 and 3500 engine classes. We believe the average age and overall composition of our compressor fleet result in fewer mechanical failures, lower fuel usage, and reduced environmental emissions.

The following table provides a summary of our compression units by horsepower as of December 31, 2025:

Unit HorsepowerFleet

Horsepower (1)Number of

UnitsHorsepower

on OrderNumber of Units on OrderTotal

Horsepower (1)Number of

UnitsPercent of

Total

HorsepowerPercent of

Units

Small horsepower

<400488,813 2,878 — — 488,813 2,878 12.4 %53.4 %

Large horsepower

≥400 and <1,000422,920 722 — — 422,920 722 10.6 %13.4 %

≥1,0002,982,599 1,764 63,250 28 3,045,849 1,792 77.0 %33.2 %

Total large horsepower3,405,519 2,486 63,250 28 3,468,769 2,514 87.6 %46.6 %

Total horsepower3,894,332 5,364 63,250 28 3,957,582 5,392 100.0 %100.0 %

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(1)As a result of the J-W Power Acquisition, in January 2026 we added approximately 0.8 million active horsepower and 1.0 million total horsepower.

Many of our compression units contain devices that enable us to monitor the units remotely through cellular and satellite networks to supplement our technicians’ on-site monitoring visits. We intend to continue to selectively add remote monitoring systems to our new and existing fleet during 2026 where beneficial from an operational and financial standpoint. All of our compression units are designed to automatically shut down if operating conditions deviate from a pre-determined range.

We adhere to routine, preventive, and scheduled maintenance cycles. Each of our compression units is subjected to rigorous sizing and diagnostic analyses, including lubricating oil analysis and engine exhaust emission analysis. We have proprietary field-service automation capabilities that allow our service technicians to electronically record and track operating, technical, environmental, and commercial information at the discrete unit level. These capabilities allow our field technicians to identify potential problems and often act on them before such problems result in down-time.

Generally, we expect each of our compression units to undergo a major overhaul between service deployment cycles. The timing of these major overhauls depends on multiple factors, including run time and operating conditions. A major overhaul involves the periodic rebuilding of the unit to materially extend its economic useful life or to enhance the unit’s ability to fulfill broader or more diversified compression applications. Because our compression fleet is comprised of units of varying horsepower that have been placed into service with staggered initial on-line dates, we are able to schedule overhauls in a way that avoids excessive annual maintenance capital expenditures and minimizes the revenue impacts of down-time.

We believe that our customers, by outsourcing their compression requirements, can achieve higher compression run-times, which translates into increased volumes of either natural gas or crude oil production and, therefore, increased revenues. Utilizing our compression services also allows our customers to reduce their operating, maintenance, and equipment costs by allowing us to efficiently manage their changing compression needs. In many of our service contracts, we guarantee our customers availability (as described below) ranging from 95% to 98%, depending on field-level requirements.

Marketing and Sales

Our marketing and client service functions are performed on a coordinated basis by our sales team and field technicians. Salespeople, applications engineers, and field technicians qualify, analyze, and scope new compression applications as well as regularly visit our customers to ensure customer satisfaction, determine a customer’s needs related to existing services being provided, and determine the customer’s future compression service requirements. This ongoing communication allows us to quickly identify and respond to our customers’ compression requirements.

Customers

As of December 31, 2025, our customers consisted of approximately 260 companies in the energy industry, including major integrated oil companies, public and private independent exploration and production companies, and midstream companies. Our ten largest customers accounted for approximately 46%, 41%, and 39% of our total revenues for the years ended December 31, 2025, 2024, and 2023, respectively.

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Suppliers and Service Providers

The principal manufacturers of components for our natural gas compression equipment include Caterpillar Inc., Cummins Inc., INNIO Waukesha, and TECO-Westinghouse for engines; Air-X-Changers, Alfa Laval (US), AXH air-coolers, EADS Cooling Solutions, LLC, and R&R Engineering Co. for coolers; and Ariel Corporation, Cooper Machinery Services Gemini products, and Arrow Engine Company for compressor frames and cylinders. We also rely on several vendors, including Standard Equipment Company, a subsidiary of Energy Transfer, to package and assemble our compression units. Additionally, J-W Power owns specialized manufacturing facilities that support its internal compression requirements and those of third-party customers. Although we primarily rely on these suppliers, we believe alternative sources for natural gas compression equipment generally are available if needed. However, relying on alternative sources may increase our costs and change the standardized nature of our fleet. We have not experienced any material supply problems to date. Lead-times for new Caterpillar engines and new Ariel compressor frames have in the recent past varied between six months to over one year due to changes in demand and supply allocations, and as of December 31, 2025, lead-times for such engines and frames have extended beyond one year, and in some cases with certain engine classes, are in excess of two years. Please read Part I, Item 1A “Risk Factors – Risks Related to Our Business – We depend on a limited number of suppliers and are vulnerable to product shortages and price increases, which could have a negative impact on our results of operations”.

Competition

The compression services business is highly competitive. Some of our competitors have greater financial and other resources than we do. On a regional basis, we experience competition from numerous smaller companies that may be able to more quickly adapt to changes within our industry and changes in economic conditions as a whole, more readily take advantage of available opportunities, and adopt more aggressive pricing policies. Additionally, the historical availability of attractive financing terms from financial institutions and equipment manufacturers has made the purchase of individual compression units more affordable to our customers. We believe that we compete effectively on the basis of price, equipment availability, customer service, flexibility in meeting customer needs, quality and reliability of our compressors, and related services. Please read Part I, Item 1A “Risk Factors – Risks Related to Our Business – We face significant competition that may cause us to lose market share and reduce our cash available for distribution”.

Seasonality

Our results of operations have not historically been materially affected by seasonality, and we do not currently have reason to believe that seasonal fluctuations will have a material impact in the foreseeable future.

Insurance

We believe that our insurance coverage is customary for the industry and adequate for our business. As is customary in the energy services industry, we review our safety equipment and procedures, and carry insurance against most, but not all, risks of our business. Losses and liabilities not covered by insurance would increase our costs. The compression business can be hazardous, involving unforeseen circumstances such as uncontrollable flows of gas or well fluids, fires and explosions, or environmental damage. To address the hazards inherent in our business, we maintain insurance coverage that, subject to significant deductibles, includes physical damage coverage, third-party general liability insurance, employer’s liability, environmental and pollution, and other coverage, although coverage for environmental- and pollution-related losses is subject to significant limitations. Under the terms of our standard compression services contract, we are responsible for maintaining insurance coverage on our compression equipment. Please read Part I, Item 1A “Risk Factors – General Risk Factors – We do not insure against all potential losses and could be seriously harmed by unexpected liabilities”.

Governmental Regulations

We are subject to stringent and complex federal, state, and local laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of human health, safety, and the environment. These regulations include compliance obligations for air emissions, water quality, wastewater discharges, and solid and hazardous waste disposal, as well as regulations designed for the protection of human health and safety, and threatened or endangered species. Compliance with these environmental laws and regulations may expose us to significant costs and liabilities and cause us to incur significant capital expenditures in our operations. We often are obligated to provide information to customers in obtaining permits or approvals in our operations from various federal, state, and local authorities. Permits and approvals can be denied or delayed, which may cause us to lose potential and current customers, interrupt our operations, and limit our growth and revenue. Moreover, failure to comply with these laws and regulations may result in the assessment of administrative, civil, and criminal penalties, imposition of remedial obligations, and the issuance of injunctions delaying or prohibiting operations. Private parties also may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. While we believe that our operations are in

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substantial compliance with applicable environmental laws and regulations and that continued compliance with current requirements would not have a material adverse effect on us, we cannot predict whether our cost of compliance will materially increase in the future. Any changes in, or more stringent enforcement of, existing environmental laws and regulations, or passage of additional environmental laws and regulations that result in more stringent and costly pollution control equipment, waste handling, storage, transport, disposal, or remediation requirements could have a material adverse effect on our operations and financial position.

We do not believe that compliance with current federal, state, or local laws and regulations will have a material adverse effect on our business, financial position, results of operations, or cash flows. We cannot assure you, however, that future events such as changes in existing laws or regulations or enforcement policies, the promulgation of new laws or regulations, or the development or discovery of new facts or conditions or unforeseen incidents will not cause us to incur significant costs. The following is a discussion of material environmental and safety laws that relate to our operations. We believe that we are in substantial compliance with all of these environmental laws and regulations. Please read Part I, Item 1A “Risk Factors – Risks Related to Governmental Legislation and Regulation – We and our customers are subject to substantial environmental regulation, and changes in these regulations could increase our and their costs or liabilities and result in decreased demand for our services”.

Air emissions. The Clean Air Act (“CAA”) and comparable state laws regulate emissions of air pollutants from various industrial sources, including natural gas compressors, and impose certain monitoring and reporting requirements. Such emissions are regulated by air emissions permits, which are applied for and obtained through various state or federal regulatory agencies. Our standard natural gas compression contract provides that the customer is responsible for obtaining air emissions permits and assuming the environmental risks related to site operations. In some instances, our customers may be required to aggregate emissions from a number of different sources on the theory that the different sources should be considered a single source. Any such determinations could have the effect of making projects more costly than our customers expected and could require the installation of more costly emissions controls, which may lead some of our customers not to pursue certain projects.

Increased obligations of operators to reduce air emissions of nitrogen oxides and other pollutants from internal combustion engines in transmission service have been imposed by governmental authorities. For example, in 2010, the U.S. Environmental Protection Agency (“EPA”) published new regulations under the CAA to control emissions of hazardous air pollutants from existing stationary reciprocal internal combustion engines, also known as Quad Z regulations. The rule requires us to undertake certain expenditures and activities, including purchasing and installing emissions control equipment on certain compressor engines and generators.

In recent years, the EPA has lowered the National Ambient Air Quality Standards (“NAAQS”) for several air pollutants. For example, in 2015, the EPA finalized a rule strengthening the primary and secondary standards for ground-level ozone, both of which are eight-hour concentration standards of 70 parts per billion (the “2015 NAAQS”). In December 2020, the EPA announced its decision to retain, without changes, the 2015 NAAQS. After the EPA revises a NAAQS standard, the states are expected to establish revised attainment/non-attainment regions. State implementation of the 2015 NAAQS could result in stricter permitting requirements, delay, or prohibit our customers’ ability to obtain such permits, and result in increased expenditures for pollution-control equipment, which could impact our customers’ operations, increase the cost of additions to property and equipment, and negatively impact our business.

In 2012, the EPA finalized rules that establish new air emissions controls for oil and natural gas production and natural gas processing operations. Specifically, the EPA’s rule package included New Source Performance Standards (“NSPS”) to address emissions of sulfur dioxide and volatile organic compounds (“VOCs”) and a separate set of emissions standards to address hazardous air pollutants frequently associated with crude oil and natural gas production and processing activities. The rules established specific new requirements regarding emissions from compressors and controllers at natural gas processing plants, dehydrators, storage tanks, and other production equipment, as well as the first federal air standards for natural gas wells that are hydraulically fractured. In June 2016, the EPA expanded these regulations when it published additional NSPS, known as Subpart OOOOa, that require certain new, modified, or reconstructed facilities in the oil and gas sector to reduce methane gas and VOC emissions. These Subpart OOOOa standards expanded the 2012 NSPS by mandating certain equipment-specific emissions control practices, requiring additional controls for pneumatic controllers and pumps as well as compressors, and imposing leak detection and repair requirements for natural gas compressor and booster stations. In addition, in December 2023, the EPA issued rules to further reduce methane and VOC emissions from new and existing sources in the oil and gas sector.

Any additional regulation of air emissions from the oil and gas sector could result in increased expenditures for pollution control equipment, which could impact our customers’ operations and negatively impact our business.

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We also are subject to air regulation at the state level. For example, the Texas Commission on Environmental Quality (“TCEQ”) has finalized revisions to certain air permit programs that significantly increase the air permitting requirements for new and certain existing oil and gas production and gathering sites for 15 counties in the Barnett Shale production area. The final rule establishes new emissions standards for engines, which could impact the operation of specific categories of engines by requiring the use of alternative engines, compressor packages, or the installation of aftermarket emissions control equipment. The rule became effective for the Barnett Shale production area in April 2011, with the lower emissions standards becoming applicable between 2015 and 2030 depending on the type of engine and the permitting requirements. The cost to comply with the revised air permit programs is not expected to be material at this time. However, the TCEQ has stated it will consider expanding application of the new air permit program statewide. At this point, we cannot predict the cost to comply with such requirements if the geographic scope is expanded.

There can be no assurance that future requirements compelling the installation of more sophisticated emissions control equipment would not have a material adverse impact on our business, financial condition, results of operations, and cash available for distribution.

Climate change. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are examples of greenhouse gases (“GHGs”). The U.S. Congress, from time to time, has considered legislation to reduce GHG emissions. The Inflation Reduction Act of 2022 (the “IRA 2022”) imposed a methane emissions charge on certain oil and gas facilities, including onshore petroleum and natural gas production facilities, that emit 25,000 metric tons or more of carbon dioxide equivalent gas per year and exceed certain emissions thresholds. The One Big Beautiful Bill Act, signed by President Trump on July 4, 2025, delays the imposition of the methane emissions charge until calendar year 2034. We do not believe that this methane fee will have a material adverse effect on our business, financial position, results of operations, or cash flows. Other energy legislation and initiatives could include a carbon tax or cap-and-trade program. At the state level, many states, including the states in which we or our customers conduct operations, have adopted legal requirements that have imposed new or more stringent permitting, disclosure, or well construction requirements on oil and gas activities. In addition, almost half of the states have begun to address GHG emissions, primarily through the planned development of emissions inventories or regional GHG cap-and-trade programs. Depending on the particular program, we could be required to control GHG emissions or to purchase and surrender allowances for GHG emissions resulting from our operations.

Independent of the U.S. Congress, the EPA undertook to adopt regulations controlling GHG emissions under its existing CAA authority. For example, in 2009, the EPA officially published its findings that emissions of carbon dioxide, methane, and other GHGs endanger human health and the environment (the “Endangerment Finding”), allowing the agency to proceed with the adoption of regulations that restrict emissions of GHG under existing provisions of the CAA. In 2009 and 2010, the EPA adopted rules regarding regulation of GHG emissions from motor vehicles and required the reporting of GHG emissions in the U.S. from specified large GHG emissions sources, including petroleum and natural gas facilities such as natural gas transmission compression facilities that emit 25,000 metric tons or more of carbon dioxide equivalent per year. On August 1, 2025, the EPA proposed rescinding the Endangerment Finding. It remains uncertain how EPA’s rescindment of the Endangerment Finding, once final, will impact future regulation of GHG emissions.

In addition, from time to time, there have been various proposals to regulate hydraulic fracturing at the federal level. Hydraulic fracturing involves the injection of water, sand, and chemicals under pressure into the rock formation to stimulate oil and gas production. Any limitations or bans on hydraulic fracturing at the federal level could increase the costs of operations for our customers who operate on federal land, and negatively impact our business.

Some states also have passed legislation or regulations regarding hydraulic fracturing. For example, in 2019, Colorado passed Senate Bill 19-181, which delegates authority to local governments to regulate oil and gas activities and requires the Colorado Oil and Gas Conservation Commission to minimize emissions of methane and other air contaminants. Some local communities have adopted additional restrictions for oil and gas activities, such as requiring greater setbacks, and some groups are petitioning local governments to ban hydraulic fracturing. If additional regulatory measures are adopted that ban or restrict production of natural gas through hydraulic fracturing, our customers could experience delays, limitations, or prohibitions on their activities. Such delays, limitations, or prohibitions could result in decreased demand for our services.

Litigation risks also are increasing, as several cities, local governments, and other plaintiffs have sued companies engaged in the exploration and production of fossil fuels in state and federal courts, alleging various legal theories to recover for the impacts of alleged global warming effects, such as rising sea levels. Many of these suits allege that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors by failing to adequately disclose those impacts. Although a number of these lawsuits have been dismissed, others remain pending and the outcome of these cases remains difficult to predict.

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Although it is not currently possible to predict with specificity how any proposed or future GHG legislation, regulation, agreements or initiatives will impact our business, any legislation or regulation of GHG emissions that may be imposed in areas in which we conduct business or on the assets we operate, including a carbon tax or cap-and-trade program, could result in increased compliance or operating costs, additional operating restrictions, or reduced demand for our services, and could have a material adverse effect on our business, financial condition, and results of operations. Notwithstanding potential risks related to climate change, the EIA estimates that crude oil and natural gas will continue to represent a major share of energy use through 2050. However, recent activism directed at shifting funding away from companies with energy-related assets could result in limitations or restrictions on certain sources of funding for the energy sector, which could have an adverse effect on our ability to obtain external financing.

Finally, some scientists have concluded that increasing concentrations of GHG in Earth’s atmosphere may produce climate changes that have significant weather-related effects, such as increased frequency and severity of storms, droughts, floods, and other climatic events. If any of those effects were to occur, they could have an adverse effect on our or our customers’ assets and operations, or result in increased cost or difficulty obtaining insurance. Another possible consequence of climate change is increased volatility in seasonal temperatures. The market for natural gas liquids (“NGLs”) and natural gas generally is impacted by periods of colder weather and warmer weather, so any changes in climate could affect the market for these fuels, and thus demand for our services. Despite the use of the term “global warming” as a shorthand for climate change, some studies indicate that climate change could cause some areas to experience temperatures substantially colder than their historical averages. As a result, it is difficult to predict how the market for our services could be affected by increased temperature volatility.

We recognize the need to decrease emissions and integrate alternative energy sources into our operations, and we actively pursue economically beneficial opportunities to reduce our environmental footprint. To that end, we have dual-drive technology as a product offering in our natural gas compression services. Dual-drive technology offers the ability to switch compression drivers between an electric motor and a natural gas engine, to reduce our emissions of nitrogen oxide, carbon monoxide, carbon dioxide, and VOCs.

Water discharge. The Clean Water Act (“CWA”) and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the U.S. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. The CWA and regulations implemented thereunder also prohibit the discharge of dredge and fill material into regulated waters, including jurisdictional wetlands, unless authorized by an appropriately issued permit. The CWA also requires the development and implementation of spill prevention, control, and countermeasures, including the construction and maintenance of containment berms and similar structures, if required, to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture, or leak at such facilities. In addition, the CWA and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities. Federal and state regulatory agencies can impose administrative, civil, and criminal penalties as well as other enforcement mechanisms for non-compliance with discharge permits or other requirements of the CWA and analogous state laws and regulations.

Our compression operations do not generate process wastewaters that are discharged to waters of the U.S. In any event, our customers assume responsibility under the majority of our standard natural gas compression contracts for obtaining any permits that may be required under the CWA, whether for discharges or developing property by filling wetlands. The EPA and the U.S. Army Corps of Engineers have changed the standard for what constitutes jurisdictional waters and wetlands subject to the protections and requirements of the CWA from time to time. Changes to the jurisdictional reach of the CWA could cause our customers to face increased costs and delays due to additional permitting and regulatory requirements, and possible challenges to permitting decisions.

Safe Drinking Water Act. A significant portion of our customers’ natural gas production is developed from unconventional sources that require hydraulic fracturing as part of the completion process. Legislation to amend the Safe Drinking Water Act (“SDWA”) to repeal the exemption for hydraulic fracturing 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 been proposed from time to time. Several states also have proposed or adopted legislative or regulatory restrictions on hydraulic fracturing, including prohibitions on the practice. We cannot predict the future of such legislation and what additional, if any, provisions would be included. If additional levels of regulation, restrictions, and permits were required through the adoption of new laws and regulations at the federal or state level, or if the agencies that issue the permits develop new interpretations of those requirements, it could lead to delays, increased operating costs, and process prohibitions that could reduce demand for our compression services, which could materially adversely affect our revenue and results of operations.

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Site remediation. The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”) and comparable state laws may impose strict, joint, and several liability without regard to fault or the legality of the original conduct on certain classes of persons that contributed to the release of a hazardous substance into the environment. These persons include the current and former owners and operators of the site where the hazardous substance release occurred and any company that transported, disposed of, or arranged for the transport or disposal of the hazardous substance released at the site. Under CERCLA, such persons may be liable for the costs of remediating the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. In addition, where contamination may be present, neighboring landowners and other third parties sometimes file claims for personal injury, property damage, and recovery of response costs. While we generate materials in the course of our operations that may be regulated as hazardous substances, we have not received notification that we may be potentially responsible for cleanup costs under CERCLA at any site.

While we do not currently own or lease any material facilities or properties for storage or maintenance of our idle compression units, we may use third-party properties for such storage and possible maintenance and repair activities. In addition, our revenue-generating compression units typically are installed on properties owned or leased by third-party customers and operated by us pursuant to terms set forth in the natural gas compression services contracts executed by those customers. Under most of our natural gas compression services contracts, our customers must contractually indemnify us for certain damages we may suffer as a result of the release into the environment of hazardous and toxic substances. We are not currently responsible for any remedial activities at any properties we use; however, there always is the possibility that our future use of those properties may result in spills or releases of petroleum hydrocarbons, wastes, or other regulated substances into the environment that may cause us to become subject to remediation costs and liabilities under CERCLA, the Resource Conservation and Recovery Act or other environmental laws. We cannot provide any assurance that the costs and liabilities associated with the future imposition of such remedial obligations upon us would not have a material adverse effect on our operations or financial position.

Safety and health. The Occupational Safety and Health Act (“OSHA”) and comparable state laws strictly govern the protection of the health and safety of employees. The OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of CERCLA, and similar state statutes require that we organize and, as necessary, disclose information about hazardous materials used or produced in our operations to various federal, state, and local agencies, as well as to employees.

Human Capital Management

USA Compression Management Services, LLC (“USAC Management”), a wholly owned subsidiary of the General Partner, performs certain management, administrative and operating services for us, and provides us with personnel to manage and operate our business. All of our employees, including our executive officers, are employees of USAC Management. As of December 31, 2025, USAC Management had 885 full-time employees. An additional 594 employees were added as a result of the J-W Power Acquisition. In addition, under our shared services model with Energy Transfer we utilize the services of Energy Transfer employees in certain departments such as information technology, accounting, and human resources. None of our employees are subject to collective bargaining agreements. We consider our employee relations to be good.

Our employees are our greatest asset, and we seek to attract and retain top talent by fostering a culture that is guided by our four pillars of people, culture, equipment, and service. These four pillars rest on a foundation of safety and guide our values in a manner that respects all people with a commitment to safety and the environments where we operate.

Ethics and Values. We are committed to operating our business in a manner that honors and respects all people and the communities in which we do business. We recognize that people are our most critical resource, and we are committed to hiring and investing in our employee base. We value employees for what they bring to our organization by embracing those from diverse backgrounds, cultures, and experiences. We believe that one of the keys to our successes over time has been the cultivation of an atmosphere of inclusion and respect. These are the principles upon which we build and strengthen relationships among our people, our unitholders, our customers, and those within the communities we support.

We believe strict adherence to our Code of Business Conduct and Ethics is not only right, but is in our best interest and the best interest of our unitholders, our customers, and the industry in general. In all instances, our policies require that the business of the Partnership be conducted in a lawful and ethical manner. Every employee acting on behalf of the Partnership must adhere to our policies. Please refer to Part III, Item 10 “Directors, Executive Officers, and Corporate Governance” for additional information on our Code of Business Conduct and Ethics.

Commitment to Safety. We have a strong commitment to safety. We provide continuous training opportunities for employees, including training that is required by applicable laws, regulations, standards, and permit conditions. Our safety standards and expectations are clearly communicated to all employees with the expectation that each individual has the

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obligation to make safety their highest priority. Our safety culture promotes an open environment for discovering, resolving, and sharing safety challenges. We strive to eliminate unwanted safety events and support our safety culture through a comprehensive program that includes a dedicated field operations-based safety team, monthly employee safety meetings, and safety audits, among other things. A portion of our senior management bonuses and field leadership bonuses are dependent on our safety performance. Our goal is operational excellence, which includes maintaining an injury- and incident-free workplace. To achieve this, we strive to hire and maintain a highly qualified and dedicated workforce, and create a safety culture with safety accountability as part of our daily operations. We promote employee empowerment, leadership, communication, and personal responsibility to comply with standard operating procedures and regulatory requirements, effective risk reduction processes, and personal wellness.

Available Information

Our website address is usacompression.com. We make available, free of charge at the “Investor Relations” section of our website, our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act, as soon as reasonably practicable after such reports are electronically filed with, or furnished to, the SEC. The information contained on our website does not constitute part of this report.

The SEC maintains a website that contains these reports at sec.gov.