EDGAR 10-K Filing

Company CIK: 1389050
Filing Year: 2024
Filename: 1389050_10-K_2024_0001389050-24-000007.json

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ITEM 1. BUSINESS
Item 1. Business
We were incorporated in February 2007 as a wholly-owned subsidiary of Universal Compression Holdings, Inc. In August 2007, Universal Compression Holdings, Inc. and Hanover Compressor Company merged into our wholly-owned subsidiaries and we became Exterran Holdings, Inc., the parent entity of Universal Compression Holdings, Inc. and Hanover Compressor Company. In November 2015, we completed the spin-off of our international contract operations, international aftermarket services and global fabrication business into a standalone public company operating as Exterran Corporation, and we were renamed “Archrock, Inc.”
We are an energy infrastructure company with a primary focus on midstream natural gas compression and a commitment to helping our customers produce, compress and transport natural gas in a safe and environmentally responsible way. We are the leading provider of natural gas compression services to customers in the energy industry throughout the U.S., in terms of total compression fleet horsepower, and a leading supplier of aftermarket services to customers that own compression equipment in the U.S. Our business supports a must-run service that is essential to the production, processing, transportation and storage of natural gas. Our mission to help our customers deliver natural gas, an affordable and cleaner energy source, to a variety of critical industries, to generate electricity and to directly heat and power our homes, is more critical than ever.
We operate in two business segments:
• Contract Operations - Our contract operations business is comprised of our owned fleet of natural gas compression equipment that we use to provide operations services to our customers.
• Aftermarket Services - Our aftermarket services business provides a full range of services to support the compression needs of our customers that own compression equipment, including operations, maintenance, overhaul and reconfiguration services and sales of parts and components.
Natural Gas Compression Industry Overview
Natural gas compression is a mechanical process whereby the pressure of a given volume of natural gas is increased to a desired higher pressure for transportation from one point to another. It is essential to the production and transportation of natural gas. Compression is also critical to minimizing flaring and reducing the waste of natural gas and natural gas liquids that results from insufficient gathering and processing capacity.
Compression is typically required throughout the natural gas production and transportation cycle, including at the wellhead, throughout gathering and distribution systems, into and out of processing and storage facilities and along intrastate and interstate pipelines. Our service offerings focus primarily on midstream applications, with 75% of our operating fleet being used in the gathering and processing cycle stages. The remaining 25% of our operating fleet is used in gas lift applications.
Wellhead and Gathering Systems. Natural gas compression is used to transport natural gas from the wellhead through the gathering system. At some point during the life of natural gas wells, reservoir pressures typically fall below the line pressure of the natural gas gathering or pipeline system used to transport the natural gas to market. At that point, natural gas no longer naturally flows into the pipeline. Compression equipment is applied in both field and gathering systems to boost the pressure levels of the natural gas flowing from the well, allowing it to be transported to market. Changes in pressure levels in natural gas fields require periodic changes to the size and/or type of on-site compression equipment. Compression equipment is also used to increase the efficiency of a low-capacity natural gas field by providing a central compression point from which the natural gas can be produced and injected into a pipeline for transmission to facilities for further processing.
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Processing Applications. Compressors may be used in combination with natural gas production and processing equipment to process natural gas into other marketable energy sources. In addition, compression services are used for compression applications in refineries and petrochemical plants. Processing applications typically utilize multiple large horsepower compressors.
Gas Lift Applications. Compression is used to reinject natural gas into producing oil wells to help lift liquids to the surface, which is known as natural gas lift. These applications utilize low- to mid-range horsepower compression equipment located at or near the wellhead or large horsepower compression equipment of over 1,000 horsepower for a centralized gas lift system servicing multiple wells.
Many oil and natural gas producers, transporters and processors outsource their compression services due to the benefits and flexibility of contract compression. Changing well and pipeline pressures and conditions over the life of a well often require producers to reconfigure or replace their compression packages to optimize the well production or gathering system efficiency.
We believe outsourcing compression operations to compression service providers such as us offers customers:
• the ability to efficiently meet their changing compression needs over time while limiting the underutilization of their owned compression equipment;
• access to the compression service provider’s specialized personnel and technical skills, including engineers and field service and maintenance employees, which we believe generally leads to improved production rates and/or increased throughput;
• the ability to increase their profitability by transporting or producing a higher volume of natural gas and crude oil through decreased compression downtime and reduced operating, maintenance and equipment costs by allowing the compression service provider to efficiently manage their compression needs; and
• the flexibility to deploy their capital on projects more directly related to their primary business by reducing their compression equipment and maintenance capital requirements.
We believe the U.S. natural gas compression services industry continues to have growth potential over time due to, among other things, increased natural gas production in the U.S. from unconventional sources, the aging of producing natural gas fields that will require more compression to continue producing the same volume of natural gas due to lower pressures and the rise in gas-to-oil ratios for maturing wells and expected increased demand for natural gas in the U.S. for power generation, industrial uses and exports, including liquefied natural gas exports and exports of natural gas via pipeline to Mexico.
Contract Operations Overview
Compression Services
We provide comprehensive contract operations services including the personnel, equipment, tools, materials and supplies to meet our customers’ natural gas compression needs. Based on the operating specifications at the customer location and each customer’s unique needs, these services include designing, sourcing, owning, installing, operating, servicing, repairing and maintaining the equipment. We work closely with our customers’ field service personnel so that compression services can be adjusted to efficiently match changing characteristics of the reservoir and the natural gas produced and may repackage or reconfigure our existing fleet to adapt to our customers’ compression needs.
During the years ended December 31, 2023, 2022 and 2021, we generated 82%, 80% and 83%, respectively, of our total revenue from contract operations.
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Compression Fleet
The compressors that we own and use to provide contract operations services are predominantly large horsepower, which we define as greater than 1,000 horsepower per unit, and consist primarily of reciprocating compressors driven by natural gas-powered engines. Additionally, we provide a small but growing number of electric motor-driven compressors. Our fleet is largely standardized around major components and key suppliers, which minimizes our fleet operating costs and maintenance capital requirements, reduces inventory costs, facilitates low-cost compressor resizing and improves technical proficiency in our maintenance and overhaul operations, which in turn allows us to achieve higher uptime while maintaining lower operating costs.
All of our compressors are designed to automatically shut down if operating conditions deviate from a pre-determined range and substantially all are also equipped with telematic devices that enable us to remotely monitor the units. We maintain field service locations from which we service and overhaul our fleet. Our equipment undergoes routine and preventive maintenance in accordance with our established maintenance schedules, standards and procedures, which we update as technology changes and as our operations group develops new techniques and procedures to better service our equipment. In our experience, these maintenance practices maximize equipment life and unit availability, minimize emissions and avoidable downtime while reducing the overall maintenance expenditures over the equipment life. As of December 31, 2023, the average age of our operating fleet was 11 years.
The following table summarizes the size of our natural gas compression fleet as of December 31, 2023:
Aggregate
Number
Horsepower
% of
of Units
(in thousands)
Horsepower
0 - 1,000 horsepower per unit
1,356
%
1,001 - 1,500 horsepower per unit
1,304
1,765
%
Over 1,500 horsepower per unit
1,439
%
Total
3,348
3,759
%
General Terms of our Contract Operations Service Agreements
We typically enter into a master service agreement with each customer that sets forth the general terms and conditions of our services, and then enter into a separate supplemental service agreement for each distinct site at which we provide contract operations services. The following describes select material terms common to our standard contract operations service agreements.
Term and Termination. Our customers typically contract for our contract operations services on a site-by-site basis that is generally reduced if we fail to operate in accordance with the contract requirements. Following the initial minimum term, which generally ranges from 12 to 48 months, contract operations services generally continue on a month-to-month basis until terminated by either party with 30 days’ advance notice.
Fees and Expenses. Our customers pay a fixed monthly fee for our contract operations services, which generally is based on the amount of horsepower associated with a specific application. In certain circumstances, such as limited or disrupted natural gas flows, our customers may be provided a reduced monthly fee. We are typically responsible for the costs and expenses associated with our compression equipment except for fuel gas or electricity, which is provided by our customers.
Service Standards and Specifications. We provide contract operations services according to the particular specifications of each job, as set forth in the applicable contract. These are typically turn-key service contracts under which we supply all services and support and use our compression equipment to provide the contract operations services necessary for a particular application. In certain circumstances, if the availability of our services does not meet certain percentages specified in our contracts, our customers are generally entitled, upon request, to specified credits against our service fees.
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Title and Risk of Loss. We own and retain title to or have an exclusive possessory interest in all compression equipment used to provide contract operations services and we generally bear risk of loss for such equipment to the extent the loss is not caused by gas conditions, our customers’ acts or omissions or the failure or collapse of the customer’s over-water job site upon which we provide the contract operations services.
Insurance. Typically, both we and our customers are required to carry general liability, workers’ compensation, employer’s liability, automobile and excess liability insurance. Our insurance coverage includes property damage, general liability and commercial automobile liability and other coverage we believe is appropriate. Additionally, we are substantially self-insured for workers’ compensation and employee group health claims in view of the relatively high per-incident deductibles we absorb under our insurance arrangements for these risks. We are also self-insured for property damage to our offshore assets.
Aftermarket Services Overview
Our aftermarket services business sells parts and components and provides operations, major and routine maintenance, overhaul and reconfiguration services to customers who own compression equipment. We believe that we are particularly well-qualified to provide these services because our highly experienced operating personnel have access to the full range of our compression services and facilities. In addition, our aftermarket services business provides opportunities to cross-sell our contract operations services. During the years ended December 31, 2023, 2022 and 2021, we generated 18%, 20% and 17%, respectively, of our total revenue from aftermarket services.
Competitive Strengths
We believe we have the following key competitive strengths:
Superior safety performance. We believe our collective safety performance is pivotal to the success of our business and is of primary importance to our customers. We have a strong safety culture and a proven ability to safely manage our business in a variety of commodity and economic environments. Our safety-centric culture has consistently produced industry-leading safety performance for many years, including a 2023 total recordable incident rate of 0.05.
Large horsepower. As of December 31. 2023, we have the largest fleet of large horsepower equipment among all outsourced compression service providers in the U.S. In addition, 85% of our fleet, as measured by operating horsepower, was comprised of units that exceed 1,000 horsepower per unit. We believe the trends driving demand for large horsepower units will continue. These trends include (i) high levels of associated gas production from shale wells, which are generally produced at a lower initial pressure than dry gas wells, (ii) pad drilling, which brings multiple wells to a single well site with larger volumes of gas, (iii) increasing well lateral lengths, which increase natural gas flow through gas gathering systems, and (iv) high probability drilling programs that allow for efficient infrastructure planning.
Excellent customer service. We operate in a relationship-driven, service-intensive industry and therefore need to provide superior customer service. We believe that our regionally-based network, local presence, experience and in-depth knowledge of our customers’ operating needs and growth plans enable us to respond to our customers’ needs and meet their evolving demands on a timely basis. In addition, we focus on achieving a high level of reliability for the services we provide in order to maximize uptime and our customers’ production levels. Our sales efforts concentrate on demonstrating our commitment to enhancing our customers’ cash flows through superior customer service and after-market support.
Large and stable customer base. We have strong relationships with a deep base of midstream companies and natural gas and crude oil producers. Our contract operations revenue base is sourced from approximately 290 customers operating throughout all major U.S. natural gas and crude oil producing regions.
Fee-based cash flows. We charge a fixed monthly fee for our contract operations services and a reduced monthly fee during periods of limited or disrupted natural gas flows. Our compression packages, on average, operate at a customer location for approximately four years. We believe this fee structure and the longevity of our operations reduces volatility and enhances the stability and predictability of our cash flows.
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Diversified geographic footprint. We operate in substantially all major natural gas and crude oil producing regions in the U.S. We have a meaningful presence in associated gas plays, including the Permian and Eagle Ford shales which, combined, account for approximately two-thirds of our operating horsepower. Increased size and geographic density offer compression services providers operating and cost advantages. As the number of compression locations and size of the compression fleet increases, the number of required sales, administrative and maintenance personnel increases at a lesser rate, resulting in operational efficiencies and potential cost advantages. Additionally, broad geographic scope allows compression service providers to more efficiently provide services to all customers, particularly those with compression applications in remote locations. Our large fleet and numerous operating locations throughout the U.S., combined with our ability to efficiently move equipment among producing regions, mean that we are not dependent on production activity in any particular region. We believe our size, geographic scope and broad customer base give us more flexibility in meeting our customers’ needs than many of our competitors and provide us with improved operating expertise and business development opportunities.
Long operating history. We have a long, sustained history of operating in the compression industry and a robust database of fleet financial and operating metrics that provides an advantage compared to our younger competitors. We have extensive experience working with our customers to meet their evolving needs.
Financial resilience and flexibility. We have historically shown and are committed to maintaining capital discipline and financial strength, which is critical in a cyclical industry and business such as ours. Maintaining ample liquidity and a prudent balance sheet supports our ability to continue to deliver on our long-term strategies and positions us to take advantage of future growth opportunities as they arise.
Technology Deployment. We are focused on harnessing technology across all aspects of our business to drive operational efficiencies and enhance our value proposition to our customers. This includes the automation of workflows, integration of digital and mobile tools for our field service technicians, expanded remote monitoring capabilities of our compressor fleets and emissions solutions. We believe these efforts, among other things, will help us achieve increased asset uptime, improve the efficiency of our field service technicians, improve our supply chain and inventory management and reduce our emissions and carbon footprint, thereby improving our profitability as discussed further below in “Business Strategies.”
Business Strategies
We intend to continue to capitalize on our competitive strengths to meet our customers’ needs through the following key strategies:
Capitalize on the long-term fundamentals for the U.S. natural gas compression industry. We believe our ability to efficiently meet our customers’ evolving compression needs, our long-standing customer relationships and our large compression fleet will enable us to capitalize on what we believe are favorable long-term fundamentals for the U.S. natural gas compression industry. These fundamentals include significant natural gas resources in the U.S., increased unconventional oil and natural gas production, decreasing natural reservoir pressures, rising gas-to-oil ratios for maturing wells and expected increased natural gas demand in the U.S. from the growth of liquefied natural gas exports, exports of natural gas via pipeline to Mexico, power generation and industrial uses.
Improve profitability. We are focused on increasing productivity and optimizing our processes. Between 2019 and 2021, we invested in a process and technology transformation project that replaced our existing ERP, supply chain and inventory management systems and expanded the remote monitoring capabilities of our compression fleet. During 2023, our focus shifted to fully harnessing these technologies across our business. We expect the technological transformations to lower our internal costs and improve our profitability over time. Implementing telematics and advanced data analysis across our fleet has enabled us to respond more quickly and optimally to downtime events, minimize prolonged troubleshooting, prevent unnecessary unit touches and stops, which are the primary cause of wear and tear of the equipment, and, ultimately, predict failures before they occur. We expect this will increase the number of units a field service technician can oversee and reduce vehicle miles traveled and fuel consumption, thereby also reducing emissions.
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In addition, large horsepower equipment is our primary focus in order to capitalize on the trends that have been driving, and that we believe will continue to drive, demand for large horsepower units. As part of this strategy, we sold approximately 199,000 and 341,000 horsepower during the years ended December 31, 2023 and 2022, respectively, which drove an increase in our large operating horsepower from 81% of our fleet as of December 31, 2021, to 85% as of December 31, 2023.
Optimize our business to generate attractive returns. We plan to continue to invest in strategically growing our business both organically and through third-party acquisitions. We see opportunities to grow our contract operations business over the long term by putting idle units back to work and profitably adding new horsepower in key growth areas. In addition, because a large amount of compression equipment is owned by natural gas and crude oil producers, processors, gatherers, transporters and storage providers, we believe there will be additional opportunities for our aftermarket services business to provide services and parts to support the operation of this equipment.
Oil and Natural Gas Industry Cyclicality and Volatility
Demand for our products and services is correlated to natural gas and crude oil production. Fluctuations in energy prices can affect the levels of expenditures by our customers, production volumes and ultimately, demand for our products and services, however, we believe our contract operations business is typically less impacted by commodity prices for the following reasons:
• fee-based contracts minimize our direct commodity price exposure;
• the natural gas we use as fuel for our compression packages is supplied by our customers, further reducing our direct exposure to commodity price risk;
• compression services are a necessary part of midstream energy infrastructure that facilitate the transportation of natural gas through gathering systems;
• our contract operations business is tied primarily to oil and natural gas production, transportation and consumption, which are generally less cyclical in nature than exploration and new well drilling and completion activities;
• the need for compression services and equipment has grown over time due to the increased production of natural gas, the natural pressure decline of natural gas-producing basins and the increased percentage of natural gas production from unconventional sources; and
• our compression packages operate at a customer location for an average of approximately four years, during which time our customers are generally required to pay a fixed monthly fee for our contract operations services or a reduced monthly fee during periods of limited or disrupted natural gas flows.
Seasonal Fluctuations
Our results of operations have not historically reflected any material seasonal tendencies and we do not believe that seasonal fluctuations will have a material impact on us in the foreseeable future.
Sales and Marketing
Our marketing and client service functions are coordinated and performed by our sales and field service personnel. Salespeople, application engineers and field service personnel qualify, analyze and scope new compression applications as well as regularly visit our customers to ensure customer satisfaction, determine customer needs as to services currently being provided and ascertain potential future compression services requirements. This ongoing communication allows us to respond swiftly to customer requests.
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Customers
Our customer base consists primarily of companies engaged in all aspects of the oil and natural gas industry, including large integrated and independent oil and natural gas processors, gatherers and transporters. We have entered into preferred vendor arrangements with some of our customers that give us preferential consideration for their compression needs. In exchange, we provide these customers with enhanced product availability, product support and favorable pricing. During the years ended December 31, 2023, 2022 and 2021, our five most significant customers collectively accounted for 33%, 32% and 31%, respectively, of our contract operations and aftermarket services revenue. No single customer accounted for 10% or more of our revenue during the years ended December 31, 2023, 2022 and 2021.
Suppliers
We have pricing agreements in place with all of our primary suppliers of compression equipment, parts and services, and work closely with these key suppliers on value engineering, to lower total lifecycle cost and improve equipment reliability. Though we rely on these suppliers to a significant degree, we believe alternative sources for compression equipment, parts and services are generally available.
Competition
The natural gas compression services business is highly competitive with low barriers to entry. Overall, we experience considerable competition from companies that may be able to more quickly adapt to changing technology within our industry and changes in economic conditions as a whole, more readily take advantage of acquisitions and other opportunities and adopt more aggressive pricing policies. We believe we are competitive with respect to price, equipment availability, customer service, flexibility in meeting customer needs, technical expertise and quality and reliability of our compression packages and related services. See “Competitive Strengths” above for further discussion.
Governmental Regulation
Environmental Regulation
Our operations are subject to stringent and complex U.S. federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of the environment and to occupational safety and health. 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. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of investigatory and remedial obligations and the issuance of injunctions delaying or prohibiting operations. We believe that our operations are in substantial compliance with applicable environmental, health and safety laws and regulations and that continued compliance with currently applicable requirements would not have a material adverse effect on us. However, the trend in environmental regulation has been to place more restrictions on activities that may affect the environment, and thus, any changes in these laws and regulations that result in more stringent and costly waste handling, storage, transport, disposal, emission or remediation requirements could have a material adverse effect on our results of operations and financial position.
The primary U.S. federal environmental laws to which our operations are subject include the CAA and regulations thereunder, which regulate air emissions; the CWA and regulations thereunder, which regulate the discharge of pollutants in industrial wastewater and storm water runoff; the RCRA and regulations thereunder, which regulate the management and disposal of hazardous and non-hazardous solid wastes; and the CERCLA and regulations thereunder, known more commonly as “Superfund,” which impose liability for the remediation of releases of hazardous substances in the environment. We are also subject to regulation under the OSHA and regulations thereunder, which regulate the protection of the safety and health of workers. Analogous state and local laws and regulations may also apply.
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Air Emissions
The CAA and analogous state laws and their implementing regulations regulate emissions of air pollutants from various sources, including natural gas compressors, and also impose various monitoring and reporting requirements. Such laws and regulations may require a facility to obtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, obtain and strictly comply with air permits containing various emissions and operational limitations, or utilize specific emission control technologies to limit emissions. Our standard contract operations agreement typically provides that the customer will assume permitting responsibilities and certain environmental risks related to site operations.
New Source Performance Standards. In June 2016, the EPA issued final regulations amending the NSPS for the oil and natural gas source category and applying to sources of emissions of methane and VOC from certain processes, activities and equipment that is constructed, modified or reconstructed after September 18, 2015. Specifically, the regulation contains both methane and VOC standards for several emission sources not previously covered by the NSPS, such as fugitive emissions from compressor stations and pneumatic pumps and methane standards for certain emission sources that are already regulated for VOC, such as equipment leaks at natural gas processing plants. The amendments also establish methane standards for a subset of equipment that the current NSPS regulates, including reciprocating compressors and pneumatic controllers, and extend the current VOC standards to the remaining unregulated equipment.
In December 2023, the EPA adopted even more stringent rules with respect to methane and VOC for new and existing sources, via NSPS OOOOb and NSPS OOOOc. While the rules have been approved by the EPA Administrator and published on the EPA website, they have not yet been published in the Federal Register. Once published, the rules become effective 60 days thereafter.
A separate BoLM rule to address methane emissions on public lands was proposed in November 2022. Among the newly adopted and proposed methane requirements that may impact our operations are broader applicability to compression equipment relative to the existing rules, increased work practices and inspection requirements and mandates for certain new zero-emissions equipment.
Meanwhile, several states - including, most notably, New Mexico and Colorado - have been developing their own more stringent methane rules that will or are anticipated to impose additional requirements on the industry. We, together with a consortium of other Gas Compressor Association member companies, were actively involved in the rulemaking effort in New Mexico, including working directly with the New Mexico Environmental Department and participating in the New Mexico Environmental Improvement Board’s hearing in late 2021.
We do not believe that the current rules will have a material adverse impact on our business, financial condition, results of operations or cash flows, but we cannot yet definitively predict the impact of any revision of the current rules or issuance of new rules, which impact could be material.
National Ambient Air Quality Standards. On October 1, 2015, the EPA issued a new NAAQS ozone standard of 70 ppb, which is a tightening from the 75 ppb standard set in 2008. This new standard became effective on December 28, 2015, and the EPA completed designating attainment/non-attainment regions under the revised ozone standard in 2018. In November 2016, the EPA proposed an implementation rule for the 2015 NAAQS ozone standard, but the agency has yet to issue a final implementation rule. State implementation of the revised 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, the costs of which could be significant. By law, the EPA must review each NAAQS every five years. In December 2018 and again in December 2020, the EPA announced that it was retaining without revision the 2015 NAAQS ozone standard. In June 2021, the EPA commenced a process for reconsidering the December 2020 decision, but more recent EPA announcements suggest that no changes are expected until 2025. We do not believe continued implementation of the NAAQS ozone standard will have a material adverse impact on our business, financial condition, results of operations or cash flows, but we cannot yet predict the impact, if any, of any new Federal Implementation Plan involving new NAAQS standards.
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General. New environmental regulations and proposals similar to these, when finalized, and any other new regulations requiring the installation of more sophisticated pollution control equipment or the adoption of other environmental protection measures, could have a material adverse impact on our business, financial condition, results of operations and cash flows. Notably, opposition to energy development and infrastructure projects has led to regulatory and judicial challenges to new facilities, including compression facilities, in states such as Massachusetts and Virginia. While we have not directly faced any such challenges to the facilities at which we provide contract operations and know of no pending or threatened efforts targeting those facilities, expanded opposition to energy infrastructure, including facilities at which we provide contract operations or in the future might otherwise have an opportunity to provide contract operations, could potentially give rise to material impacts in the future.
Climate Change
Climate change legislation and regulatory initiatives may arise from a variety of sources, including international, national, regional and state levels of government and associated administrative bodies, seeking to restrict or regulate emissions of GHG, such as carbon dioxide and methane.
Congress has previously considered legislation to restrict or regulate emissions of GHG. Energy legislation and other initiatives continue to be proposed that may be relevant to GHG emissions issues. Almost half of the states, either individually or through multi-state regional initiatives, have begun to address GHG emissions, primarily through the planned development of emission inventories or regional GHG cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of GHG emissions, such as electric power plants, it is possible that smaller sources such as our natural gas-powered compressors could become subject to GHG-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for GHG emissions resulting from our operations. The $1 trillion legislative infrastructure package passed by Congress in November 2021 includes a number of climate-focused spending initiatives targeted at climate resilience, enhanced response and preparation for extreme weather events, and clean energy and transportation investments. Significant additional legislative action by Congress also occurred in August 2022 with the Inflation Reduction Act, which provides $391 billion in funding for research and development and incentives for low-carbon energy production methods, carbon capture, and other programs directed at encouraging de-carbonization and addressing climate change.
Independent of Congress, the EPA has promulgated regulations controlling GHG emissions under its existing CAA authority. The EPA has adopted rules requiring many facilities, including petroleum and natural gas systems, to inventory and report their GHG emissions. In 2023, we did not operate any facilities that were subject to these reporting obligations. In addition, the EPA rules provide air permitting requirements for certain large sources of GHG emissions. The requirement for large sources of GHG emissions to obtain and comply with permits will affect some of our and our customers’ largest new or modified facilities going forward, but is not expected to cause us to incur material costs. As noted above, the EPA has undertaken efforts to regulate emissions of methane, considered a GHG, in the oil and gas sector, with the development of additional, more stringent rules under way.
In an executive order issued on January 20, 2021, the POTUS asked the heads of all executive departments and agencies to review and take action to address any federal regulations, orders, guidance documents, policies and any similar agency actions promulgated during the prior administration that may be inconsistent with or present obstacles to the administration’s stated goals of protecting public health and the environment, and conserving national monuments and refuges. The executive order also established an Interagency Working Group on the Social Cost of Greenhouse Gases, which is called on to, among other things, capture the full costs of GHG emissions, including the “social cost of carbon,” “social cost of nitrous oxide” and “social cost of methane,” which are “the monetized damages associated with incremental increases in greenhouse gas emissions,” including “changes in net agricultural productivity, human health, property damage from increased flood risk, and the value of ecosystem services.” The current administration adopted an interim social cost of carbon of $51 per ton in February 2021, but in recent rulemakings the EPA has referenced a figure as high as $2,400 per ton effective in 2030. This figure is intended to be used to guide federal decisions on the costs and benefits of various policies and approvals; such efforts have been the subject of a series of judicial challenges, which have been largely unsuccessful to date. At this time, we cannot determine whether the administration’s efforts on social cost or other interagency climate efforts will lead to any particular actions that give rise to a material adverse effect on our business, financial condition, results of operations and cash flows.
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At the international level, the U.S. joined the international community at the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change in Paris, France, which resulted in an agreement intended to nationally determine their contributions and set GHG emission reduction goals every five years beginning in 2020. While the Agreement did not impose direct requirements on emitters, national plans to meet its pledge could have resulted in new regulatory requirements. In November 2019, however, plans were formally announced for the U.S. to withdraw from the Paris Agreement with an effective exit date in November 2020. In April 2021, the current administration announced reentry of the U.S. into the Paris Agreement along with a new “nationally determined contribution” for U.S. GHG emissions that would achieve emissions reductions of at least 50% relative to 2005 levels by 2030. Those national commitments by themselves create no binding requirements on individual companies or facilities, but they do provide indications of the current administration’s policy direction and the types of legislative and regulatory requirements, such as the EPA’s proposed methane rules, that may be needed to achieve those commitments. Relatedly, the U.S. and European Union jointly announced the launch of the “Global Methane Pledge,” which aims to cut global methane pollution at least 30% by 2030 relative to 2020 levels, including “all feasible reductions” in the energy sector. More recently, the international community’s December 2023 meeting known as COP28 reaffirmed commitments to the Paris Agreement and concluded an agreement that the world should move away from fossil fuel energy in a just, orderly, and equitable manner and achieve net zero GHG emissions by 2050, while recognizing a transitional role for fossil fuels. With the exception of the proposed methane rules discussed above, we cannot predict whether re-entry into the Paris Agreement or other international pledges will result in any particular new regulatory requirements or whether such requirements will cause us to incur material costs.
Although it is not currently possible to predict how these executive orders, national commitments or any proposed or future GHG or climate change legislation or regulation promulgated by Congress, the states or multi-state regions will impact our business, any regulation of GHG emissions that may be imposed in areas in which we conduct business could result in increased compliance costs or additional operating restrictions or reduced demand for our services, and could have a material adverse effect on our business, financial condition, results of operations and cash flows.
Water Discharges
The CWA and analogous state laws and their implementing regulations impose restrictions and strict controls with respect to the discharge of pollutants into state waters or 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. In addition, the CWA regulates storm water discharges associated with industrial activities depending on a facility’s primary standard industrial classification. Four of our facilities have applied for and obtained industrial wastewater discharge permits and/or have sought coverage under local wastewater ordinances. U.S. federal laws also require development and implementation of spill prevention, controls and countermeasure plans where petroleum storage quantities exceed certain thresholds, including appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak at such facilities. The definition of “waters of the United States” and, relatedly, the scope of CWA jurisdiction, have been the subject of notable rulemaking efforts and judicial challenges over several decades. In May 2023, the U.S. Supreme Court announced a decision that sharply narrowed that definition to relatively permanent bodies of water connected to traditional navigable waters and wetlands with a continuous surface connection to other jurisdictional waters, thereby invalidating protections for many other historically regulated wetlands and waters. The EPA and the Army Corps of Engineers issued a final rule effective September 8, 2023 to implement the terms of that decision.
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Waste Management and Disposal
RCRA and analogous state laws and their implementing regulations govern the generation, transportation, treatment, storage and disposal of hazardous and non-hazardous solid wastes. During the course of our operations, we generate wastes (including, but not limited to, used oil, antifreeze, used oil filters, sludges, paints, solvents and abrasive blasting materials) in quantities regulated under RCRA. The EPA and various state agencies have limited the approved methods of disposal for these types of wastes. CERCLA and analogous state laws and their implementing regulations impose strict, and under certain conditions, joint and several liability without regard to fault or the 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 current and past owners and operators of the facility or disposal site where the release occurred and any company that transported, disposed of, or arranged for the transport or disposal of the hazardous substances released at the site. Under CERCLA, such persons may be subject to joint and several liability for the costs of cleaning up 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, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury, property damage and recovery of response costs allegedly caused by hazardous substances or other pollutants released into the environment.
We currently own or lease, and in the past have owned or leased, a number of properties that have been used in support of our operations for a number of years. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons, hazardous substances, or other regulated wastes may have been disposed of or released on or under the properties owned or leased by us or on or under other locations where such materials have been taken for disposal by companies subcontracted by us. In addition, many of these properties have been previously owned or operated by third parties whose treatment and disposal or release of hydrocarbons, hazardous substances or other regulated wastes was not under our control. These properties and the materials released or disposed thereon may be subject to CERCLA, RCRA and analogous state laws. Under such laws, we could be required to remove or remediate historical property contamination, or to perform certain operations to prevent future contamination. At certain of such sites, we are currently working with the prior owners who have undertaken to monitor and clean up contamination that occurred prior to our acquisition of these sites. We are not currently under any order requiring that we undertake or pay for any cleanup activities. However, we cannot provide any assurance that we will not receive any such order in the future.
Occupational Safety and Health
We are subject to the requirements of the OSHA and comparable state statutes. These laws and the implementing regulations strictly govern the protection of the safety and health of employees. The OSHA’s hazard communication standard, the EPA’s community right-to-know regulations under Title III of CERCLA and similar state statutes require that we organize and/or disclose information about hazardous materials used or produced in our operations.
Human Capital
As of December 31, 2023, we employed approximately 1,100 employees in 14 states and conducted business in 42 states. None of our employees are subject to a collective bargaining agreement.
We consider our employees to be our greatest asset and believe that our success depends on our ability to attract, develop and retain our employees. Diversity and inclusion are foundational to our leadership approach and our focus is on how our actions and the actions of our employees foster diversity and inclusion in our everyday activities at Archrock. We support diversity in hiring, as is reflected in the diversity of our Board of Directors, of which three of our independent directors are female or identify as a member of an underrepresented racial/ethnic group. Similarly, one-third of our executive leadership team is female and 28% of our total workforce is ethnically diverse.
We support pay equity and believe we offer competitive and comprehensive compensation benefits packages that include bonuses, an employee stock purchase plan, a 401(k) plan with employer contribution, healthcare and insurance benefits, health savings and flexible spending accounts with employer contribution, paid time off (including 16 hours per year as paid time to volunteer), family leave, an employee assistance program and tuition assistance, among many others.
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We believe in the ultimate goal of serving as the best corporate citizen possible and are dedicated to inspiring and empowering our employees to operate continuously according to our core values of safety, service, integrity, respect and pride. To that end, the Governance and Sustainability Committee of our Board of Directors provides oversight of our policies, practices and programs regarding the promotion of diversity and inclusion within our company and the health and safety of our employees and communities.
Learning and Talent Development
We invest significant resources to develop the talent needed to provide our industry-leading natural gas compression services. We work closely with suppliers to develop training programs for our field service technicians. Our field service technicians are supported by a dedicated training team and collectively completed over 37,000 hours of operational and technical training during 2023. Generally, new hire field employees enter a program whereby they are assigned an experienced mentor, for an average of six months, under whose direct supervision they apply their classroom learning in the real world setting.
In addition, we offer a number of non-technical, targeted skills-based and career-enhancing training programs, including technical orientation for non-technical employees, supervisor coaching, performance management and conflict resolution. Our talent development programs provide employees with the resources they need to help achieve their career goals, build management skills and lead their organizations.
Safety, Health and Wellness
The success of our business is fundamentally connected to the well-being of our people and so we are committed to the safety, health and wellness of our employees.
Safety is a core value of our company, and safety performance is a key measure of success that has been included in our short-term incentive program for over 17 years. We actively promote the highest standards of safety behavior and environmental awareness and strive to meet or exceed all applicable local and national regulations. “Stop the Job” is an adopted edict that establishes the obligation of and provides the authority to all employees to stop any task or operation where they perceive that a risk to people, the environment or assets is not properly controlled. We believe that all incidents are preventable and that through proper training, planning and hazard recognition, we can achieve a workplace with zero incidents. To this end, we created the TARGET ZERO program that includes over 90 safety and environmental procedures, and their necessary tools, equipment and training, which are designed to foster a mindset that integrates safety into every work process. Through this program, we achieved excellent safety performance, with a total recordable incident rate of 0.05 in 2023. While no incidents are acceptable, the incidents we experienced were extremely minor in nature and resulted in no lost time. It will be our continuous goal that we achieve a rate of zero in all future periods.
We also provide our employees and their families with access to a variety of flexible and convenient health and wellness programs that support the maintenance or improvement of our employees’ physical and mental health and encourage engagement in healthy behaviors, including our employee-led RockFIT program that develops and sponsors corporate health and fitness challenges throughout the year.
Building Employee and Community Connections
We consider ourselves a member of every community in which we operate and believe that building connections between our employees, their families and our communities creates a more meaningful and enjoyable workplace. Our employees give generously and are passionate towards many causes, for which they receive 16 hours per year of paid time off to volunteer. Our employee-led Archrock Cares program brings together employees across functions and backgrounds to break down traditional corporate barriers and form strong bonds through the pursuit of shared interests and volunteering and giving opportunities across the country.
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Available Information
Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports are available free of charge on our website, www.archrock.com, as soon as reasonably practicable after they are filed electronically with the SEC. Information on our website is not incorporated by reference in this 2023 Form 10-K or any of our other securities filings. Paper copies of our filings are also available, without charge, from Archrock, Inc., 9807 Katy Freeway, Suite 100, Houston, Texas 77024, Attention: Investor Relations. The SEC also maintains a website that contains reports, proxy and information statements and other information regarding issuers who file electronically with the SEC. The SEC’s website address is www.sec.gov.
Additionally, we make available free of charge on our website:
• our Code of Business Conduct;
• our Corporate Governance Principles; and
• the charters of our audit, compensation and nominating and corporate governance committees.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors
As described in “Forward-Looking Statements,” this 2023 Form 10-K contains forward-looking statements regarding us, our business and our industry. The risk factors described below, among others, could cause our actual results to differ materially from the expectations reflected in the forward-looking statements. If any of the following risks actually occur, our business, financial condition, results of operations and cash flows could be negatively impacted.
Industry and General Economic Risks
Pandemics and other public health crises may negatively affect demand for our services, and may have a material adverse impact on our financial condition, results of operations and cash flows.
Pandemics or other public health crises could significantly impact public health, economic growth, supply chains and markets. The extent to which our operating and financial results may be affected by future pandemics or other public health crises will depend on various factors and consequences beyond our control, such as the duration and scope of such pandemic or public health crisis, additional actions by businesses and governments in response to the pandemic and the speed and effectiveness of responses to combat any such pandemic or public health crisis. Any future pandemic or public health crisis may materially adversely affect our operating and financial results in a manner that is not currently known to us or that we do not currently consider to present significant risks to our operations.
An increase in inflation could have adverse effects on our results of operation.
While inflation rates have fallen over the second half of 2023, uncertainty remains on future inflation trends and whether the Federal Reserve will raise or lower interest rates, which has created further uncertainty for the economy and for our customers. If inflationary pressures return in 2024, this will increase our labor costs and the costs of parts, lube oil and other materials used in our operations. An increase in inflation rates could negatively affect our profitability and cash flows, due to higher wages, higher operating costs, higher financing costs, and/or higher supplier prices. We may be unable to pass along such higher costs to our customers. In addition, inflation may adversely affect customers’ financing costs, cash flows, and profitability, which could adversely impact their operations and our ability to collect receivables.
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Ongoing International Conflicts and Tensions
The conflict in Ukraine, the Israel-Hamas war and related price volatility and geopolitical instability could negatively impact our business.
In late February 2022, Russia launched significant military action against Ukraine, and in October 2023, Israel launched a military response against Hamas in Gaza. These ongoing conflicts have caused, and could intensify, volatility in oil and natural gas prices, and the extent and duration of these military actions, sanctions and resulting market disruptions could be significant and could potentially have a substantial negative impact on the global economy and/or our business for an unknown period of time. Any such volatility and disruptions may also magnify the impact of other risks described in this “Risk Factors” section.
Business and Operational Risks
Our operations entail inherent risks that may result in substantial liability. We do not insure against all potential losses and could be seriously harmed by unexpected liabilities.
Our operations entail inherent risks, including equipment defects, malfunctions and failures and natural disasters, which could result in uncontrollable flows of natural gas or well fluids, fires and explosions. These risks may expose us, as an equipment operator, to liability for personal injury, wrongful death, property damage, pollution and other environmental damage. The insurance we carry against many of these risks may not be adequate to cover our claims or losses. Our insurance coverage includes property damage, general liability and commercial automobile liability and other coverage we believe is appropriate. Additionally, we are substantially self-insured for workers’ compensation and employee group health claims in view of the relatively high per-incident deductibles we absorb under our insurance arrangements for these risks. We are also self-insured for property damage to our offshore assets. Further, insurance covering the risks we expect to face or in the amounts we desire may not be available in the future or, if available, the premiums may not be commercially justifiable. If we were to incur substantial liability and such damages were not covered by insurance or were in excess of policy limits, or if we were to incur liability at a time when we are not able to obtain liability insurance, our business, results of operations and financial condition could be negatively impacted.
We face significant competitive pressures that may cause us to lose market share and harm our financial performance.
Our business is highly competitive and there are low barriers to entry. Our competitors may be able to more quickly adapt to technological changes within our industry and changes in economic and market conditions as a whole, more readily take advantage of acquisitions and other opportunities and adopt more aggressive pricing policies. Our ability to renew or replace existing contract operations service agreements with our customers at rates sufficient to maintain current revenue and cash flows could be adversely affected by the activities of our competitors. If our competitors substantially increase the resources they devote to the development and marketing of competitive products, equipment or services or substantially decrease the price at which they offer their products, equipment or services, we may not be able to compete effectively.
In addition, we could face significant competition from new entrants into the compression services business. Some of our existing competitors or new entrants may expand or fabricate new compressors that would create additional competition for the services we provide to our customers. In addition, our customers may purchase and operate their own compression fleets in lieu of using our natural gas compression services. We also may not be able to take advantage of certain opportunities or make certain investments because of our debt levels and our other obligations. Any of these competitive pressures could have a material adverse effect on our business, results of operations and financial condition.
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If we do not make acquisitions on economically acceptable terms, our future growth could be limited.
Our ability to grow depends, in part, on our ability to make accretive acquisitions. If we are unable to make accretive acquisitions either because we are (i) unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them, (ii) unable to obtain financing for these acquisitions on economically acceptable terms or (iii) outbid by competitors, then our future growth and ability to maintain dividends could be limited. Furthermore, even if we make acquisitions that we believe will be accretive, these acquisitions may nevertheless result in a decrease in the cash generated from operations.
Any acquisition involves potential risks, including, among other things:
• an inability to successfully integrate the businesses we acquire;
• the assumption of unknown liabilities;
• limitations on rights to indemnity from the seller;
• mistaken assumptions about the cash generated or anticipated to be generated by the business acquired or the overall costs of equity or debt;
• the diversion of management’s attention from other business concerns;
• unforeseen operating difficulties; and
• customer or key employee losses at the acquired businesses.
If we consummate any future acquisitions, our capitalization and results of operations may change significantly and we will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of our future funds and other resources. In addition, competition from other buyers could reduce our acquisition opportunities or cause us to pay a higher price than we might otherwise pay.
While we paid quarterly dividends to holders of our common stock during the year ended December 31, 2023, there can be no assurance that we will pay dividends in the future.
We paid quarterly cash dividends, $0.61 annually, per share of common stock during the year ended December 31, 2023. We cannot provide assurance that we will, at any time in the future, again generate sufficient surplus cash that would be available for distribution to the holders of our common stock as a dividend or that our Board of Directors would determine to use any of our net profits to pay a dividend.
Future dividends may be affected by, among other factors:
• the availability of surplus or net profits, which in turn depend on the performance of our business and operating subsidiaries;
• our debt service requirements and other liabilities;
• our ability to refinance our debt in the future or borrow funds and access capital markets;
• restrictions contained in our Debt Agreements;
• our future capital requirements, including to fund our operating expenses and other working capital needs;
• the rates we charge for our services;
• the level of demand for our services;
• the creditworthiness of our customers;
• our level of operating expenses; and
• changes in U.S. federal, state and local income tax laws or corporate laws.
We cannot provide assurance that we will declare or pay dividends in any particular amount or at all in the future. A decision not to pay dividends or a reduction in our dividend payments in the future could have a negative effect on our stock price.
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Financial Risks
We have a substantial amount of debt that could limit our ability to fund future growth and operations and increase our exposure to risk during adverse economic conditions.
As of December 31, 2023, we had $1.6 billion in outstanding debt obligations, net of unamortized debt premiums and unamortized deferred financing costs, outstanding under our Credit Facility and Senior Notes. Many factors, including factors beyond our control, may affect our ability to make payments on our outstanding indebtedness. These factors include those discussed elsewhere in these Risk Factors.
Our substantial debt level and associated commitments could have important consequences to our liquidity, particularly to the extent our borrowing capacity becomes covenant restricted. For example, these commitments could:
• make it more difficult for us to satisfy contractual obligations;
• increase our vulnerability to general adverse economic and industry conditions;
• limit our ability to fund future working capital, capital expenditures, acquisitions or other corporate requirements;
• increase our vulnerability to interest rate fluctuations because the interest payments on a portion of our debt are based upon variable interest rates and a portion can adjust based on our credit statistics;
• limit our flexibility in planning for, or reacting to, changes in our business and our industry;
• place us at a disadvantage compared to our competitors that have less debt or less restrictive covenants in such debt; and
• limit our ability to incur indebtedness in the future.
Covenants in our Debt Agreements may impair our ability to operate our business.
Our Debt Agreements contain various covenants with which we or certain of our subsidiaries must comply, including, but not limited to, restrictions on the use of proceeds from borrowings, limitations on the incurrence of indebtedness, investments, acquisitions, making loans, liens on assets, repurchasing equity, making dividends, transactions with affiliates, mergers, consolidations, dispositions of assets and other provisions customary in similar types of agreements. The Debt Agreements also contain various covenants requiring mandatory prepayments from the net cash proceeds of certain asset transfers.
Our Credit Facility is also subject to financial covenants, including the following ratios, as defined in the corresponding agreement:
EBITDA to Interest Expense
2.5 to 1.0
Senior Secured Debt to EBITDA
3.0 to 1.0
Total Debt to EBITDA (1)
5.25 to 1.0
(1) Subject to a temporary increase to 5.50 to 1.0 for any quarter during which an acquisition satisfying certain thresholds is completed and for the two quarters immediately following such quarter.
If we were to anticipate non-compliance with these financial ratios, we may take actions to maintain compliance with them. These actions include reductions in our general and administrative expenses, capital expenditures or the payment of cash dividends. Any of these measures may reduce the amount of cash available for payment of dividends and the funding of our business requirements, which could have an adverse effect on our business, operations, cash flows or the price of our common stock.
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The breach of any of the covenants under the Debt Agreements could result in a default under the Debt Agreements, which could cause indebtedness under the Debt Agreements to become due and payable. If the repayment obligations under the Debt Agreements were to be accelerated, we may not be able to repay the debt or refinance the debt on acceptable terms and our financial position would be materially adversely affected. A material adverse effect on our assets, liabilities, financial condition, business or operations that, taken as a whole, impacts our ability to perform the obligations under the Debt Agreements could lead to a default under those agreements. Further, a default under one or more of the Debt Agreements would trigger cross-default provisions under the other Debt Agreements, which would accelerate our obligation to repay the indebtedness under those agreements.
As of December 31, 2023, we were in compliance with all covenants under the Debt Agreements.
We may be unable to access the capital and credit markets or borrow on affordable terms to obtain additional capital that we may require.
Historically, we have financed acquisitions, operating expenditures and capital expenditures with a combination of cash provided by operating and financing activities. However, to the extent we are unable to finance our operating expenditures, capital expenditures, scheduled interest and debt repayments and any future dividends with net cash provided by operating activities and borrowings under the Credit Facility, we may require additional capital. Periods of instability in the capital and credit markets (both generally and in the oil and gas industry in particular) could limit our ability to access these markets to raise debt or equity capital on affordable terms or to obtain additional financing. Among other things, our lenders may seek to increase interest rates, enact tighter lending standards, refuse to refinance existing debt at maturity at favorable terms or at all and may reduce or cease to provide funding to us. If we are unable to access the capital and credit markets on favorable terms, or if we are not successful in raising capital within the time period required or at all, we may not be able to grow or maintain our business, which could have a material adverse effect on our business, results of operations and financial condition.
Our inability to fund purchases of additional compression equipment could adversely impact our financial results.
We may not be able to maintain or increase our asset and customer base unless we have access to sufficient capital to purchase additional compression equipment. Cash flow from our operations and availability under our Credit Facility may not provide us with sufficient cash to fund our capital expenditure requirements, including any funding requirements related to acquisitions. Our ability to grow our asset and customer base could be impacted by limits on our ability to access additional capital.
We may be vulnerable to interest rate increases due to our variable rate debt obligations.
Borrowings under our Credit Facility are subject to variable interest rates. Changes in economic conditions outside of our control could result in higher interest rates, thereby increasing our interest expense and reducing the funds available for capital investment, operations or other purposes. In addition, a substantial portion of our cash flow must be used to service our debt obligations. Any increase in our interest expense could negatively impact our results of operations and cash flows, including our ability to pay dividends in the future.
Our Amended and Restated Credit Agreement changed the referenced rate from LIBOR to SOFR so that borrowings under the Credit Facility bear interest at, based on our election, either a base rate or SOFR, plus an applicable margin. The Amended and Restated Credit Agreement contains SOFR benchmark replacement provisions. At this time, there can be no assurance as to whether any alternative benchmark or resulting interest rates may be more or less favorable than SOFR.
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Uncertainty relating to the phasing out of LIBOR may adversely affect the market value of our current or future debt obligations, including our Credit Facility.
The Federal Reserve Board and the Federal Reserve Bank of New York organized the ARRC, which identified SOFR as its preferred alternative to U.S. dollar LIBOR in financial contracts. There can be no assurance that SOFR or any other alternative reference rate will perform in the same way as LIBOR would have at any time, including as a result of changes in interest and yield rates in the market, market volatility or global or regional economic, financial, political, regulatory, judicial or other events. Additionally, ARRC has recommended credit spread adjustments for use with SOFR due to LIBOR representing an unsecured lending rate while SOFR represents a secured lending rate. However, market acceptance of the ARRC-recommended credit spread adjustments, as opposed to no or alternative credit spread adjustments, has been mixed. Accordingly, we cannot predict whether changes related to the phase-out of LIBOR, including any credit spread adjustments, insufficient liquidity in SOFR or alternative reference rate markets or other reforms, as they occur, will have an adverse effect on the market value of, the applicable interest rate on and the amount of interest paid on our current or future debt obligations, including the Credit Facility.
Customer and Contract Risks
The erosion of the financial condition of our customers could adversely affect our business.
Many of our customers finance their exploration and production activities through cash flow from operations, the incurrence of debt or the issuance of equity. During times when the oil or natural gas markets weaken, our customers are more likely to experience a downturn in their financial condition. Additionally, some of our midstream customers may provide their gathering, transportation and related services to a limited number of companies in the oil and gas production business. A reduction in borrowing bases under reserve-based credit facilities, the lack of availability of debt or equity financing or other factors that negatively impact our customers’ financial condition could result in a reduction in our customers’ spending for our products and services, which may result in their cancellation of contracts, the cancellation or delay of scheduled maintenance of their existing natural gas compression equipment, their determination not to enter into new natural gas compression service contracts or their determination to cancel or delay orders for our services. Furthermore, the loss by our midstream customers of their key customers could reduce demand for their services and result in a deterioration of their financial condition, which would in turn decrease their demand for our services. Any such action by our customers would reduce demand for our services. Reduced demand for our services could adversely affect our business, results of operations, financial condition and cash flows. In addition, in the event of the financial failure of a customer, we could experience a loss on all or a portion of our outstanding accounts receivable associated with that customer.
The loss of any of our most significant customers would result in a decline in our revenue and cash available to pay dividends to our common stockholders.
Our five most significant customers collectively accounted for 33%, 32% and 31% of our revenues during the years ended December 31, 2023, 2022 and 2021, respectively. Our services are provided to these customers pursuant to contract operations service agreements, which typically have an initial term of 12 to 48 months and continue thereafter until terminated by either party with 30 days’ advance notice. The loss of all or even a portion of the services we provide to these customers, as a result of competition or otherwise, could have a material adverse effect on our business, results of operations and financial condition.
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Many of our contract operations service agreements have short initial terms and are cancelable on short notice after the initial term, and we cannot be sure that such contracts will be extended or renewed after the end of the initial contractual term. Any such nonrenewals, or renewals at reduced rates or the loss of contracts with any significant customer could adversely impact our results of operations.
The length of our contract operations service agreements with customers varies based on operating conditions and customer needs. Our initial contract terms typically are not long enough to enable us to recoup the cost of the equipment we utilize to provide contract operations services, and these contracts are typically cancelable on short notice after the initial term. We cannot be sure that a substantial number of these contracts will be extended or renewed by our customers or that any of our customers will continue to contract with us. The inability to negotiate extensions or renew a substantial portion of our contract operations services contracts, the renewal of such contracts at reduced rates, the inability to contract for additional services with our customers or the loss of all or a significant portion of our services contracts with any significant customer could lead to a reduction in revenue and net income and could require us to record asset impairments. Moreover, we have limited ability to increase prices during our initial contract terms. As a result, we are unable to pass increases in the prices of the equipment, materials and services we utilize to provide contract operations services, as a result of inflation of otherwise, onto our customers, which could result in a reduction in net income. This could have a material adverse effect upon our business, results of operations, financial condition and cash flows.
Labor and Supply Chain Risks
Our ability to manage and grow our business effectively may be adversely affected if we lose management or operational personnel.
We believe that our ability to hire, train and retain qualified personnel will continue to be challenging and important. The supply of experienced operational and field personnel, in particular, decreases as other energy companies’ needs for the same personnel increase. Our ability to grow and to continue our current level of service to our customers will be adversely impacted if we are unable to successfully hire, train and retain these important personnel. In addition, the cost of labor has increased and may continue to increase in the future with increases in demand, which could require us to incur additional costs and negatively impact our results of operations.
We depend on particular suppliers and are vulnerable to product shortages and price increases. With respect to our suppliers of newly-fabricated compression equipment specifically, we occasionally experience long lead times, and therefore may at times make purchases in anticipation of future business. If we are unable to purchase compression equipment or other integral equipment, materials and services from third party suppliers, we may be unable to retain existing customers or compete for new customers, which could have a material adverse effect on our business, results of operations and financial condition.
Some equipment, materials and services used in our business are obtained from a limited group of suppliers. Our reliance on these suppliers involves several risks, including price increases (as a result of inflation or otherwise), inferior quality and a potential inability to obtain an adequate supply of such equipment, materials and services in a timely manner. Additionally, we occasionally experience long lead times from our suppliers of newly-fabricated compression equipment and may at times make purchases in anticipation of future business. We do not have long-term contracts with some of these suppliers, and the partial or complete loss of certain of these suppliers could have a negative impact on our results of operations and could damage our customer relationships.
If we are unable to purchase compression equipment, in particular, on a timely basis to meet the demands of our customers, our existing customers may terminate their contractual relationships with us, or we may not be able to compete for business from new or existing customers, which, in each case, could have a material adverse effect on our business, results of operations and financial condition. Further, supply chain bottlenecks could adversely affect our ability to obtain necessary materials, parts or lube oil used in our operations or increase the costs of such items. A significant increase in the price of such equipment, materials and services as a result of inflation, or other factors, could have a negative impact on our business, results of operations, financial condition and cash flows.
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Information Technology and Cybersecurity Risks
We may not realize the intended benefits of our process and technology transformation project, which could have an adverse effect on our business.
Between 2019 and 2021, we invested in a process and technology transformation project that replaced our existing ERP, supply chain and inventory management systems and expanded the remote monitoring capabilities of our compression fleet. During 2023, our focus shifted to fully harnessing these technologies across our business. We expect the technological transformations to lower our internal costs and improve our profitability over time. However, the implementation of the process and technology transformation project has required significant capital and other resources from which we may not realize the benefits we expect to realize. Any such difficulties could have an adverse effect on our business, results of operations and financial condition.
Threats of cyber-attacks or terrorism could affect our business.
We rely on our information technology systems for critical operations. We own and manage some of these technology systems, but also rely on the systems provided by a host of third-party service providers, vendors, and business partners. We and certain of our third-party providers collect, maintain and process data about customers, employees, business partners and others, including personally identifiable information, as well as proprietary information belonging to our business, such as trade secrets. We are subject to numerous and evolving cybersecurity risks and threats, including cyber-attacks, computer viruses or terrorism that threaten the confidentiality, integrity and availability of critical technology systems or information and may disrupt our operations and harm our operating results. Our industry requires the continued operation of sophisticated information technology systems and network infrastructure. Despite our implementation of security measures, our technology systems are vulnerable to disability or failures due to social engineering/phishing, malware (including ransomware), malfeasance by insiders, human or technological error, hacking, viruses, and as a result of bugs, misconfigurations or exploited vulnerabilities in software or hardware, acts of war or terrorism and other causes. In addition, because we use third-party suppliers and service providers, such as cloud services that support our internal and customer-facing operations, successful cyberattacks that disrupt or result in unauthorized access to third-party technology systems can materially impact our operations and financial results.
Cyberattacks are expected to accelerate on a global basis in frequency and magnitude as threat actors are increasingly sophisticated in using techniques and tools, including generative and other artificial intelligence, that circumvent security controls, evade detection and remove forensic evidence. As a result, we may be unable to detect, investigate, remediate or recover from future attacks or incidents, or to avoid a material adverse impact to our systems or information. If our information technology systems were to fail and we were unable to recover in a timely way, we may be unable to fulfill critical business functions, which could have a material adverse effect on our business, results of operations and financial condition. There can be no assurance that our cybersecurity risk management program and processes, including our policies, controls or procedures, will be fully implemented, complied with or effective in protecting our systems and information.
In addition, our assets may be targets of terrorist activities that could disrupt our ability to service our customers. We may be required by our regulators or by the future terrorist threat environment to make investments in security that we cannot currently predict. The implementation of security guidelines and measures and maintenance of insurance, to the extent available, addressing such activities could increase costs. We cannot guarantee that any costs and liabilities incurred in relation to an attack or incident will be covered by our existing insurance policies or that applicable insurance will be available to us in the future on economically reasonable terms or at all. These types of events could materially adversely affect our business and results of operations. In addition, these types of events could require significant management attention and resources and could adversely affect our reputation among customers and the public.
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Tax-related Risks
Tax legislation and administrative initiatives or challenges to our tax positions could adversely affect our results of operations and financial condition.
We operate in locations throughout the U.S. and, as a result, we are subject to the tax laws and regulations of U.S. federal, state and local governments. We have investments in unconsolidated affiliates that operate in the U.S. and international locations. From time to time, various legislative or administrative initiatives may be proposed that could adversely affect our tax positions. There can be no assurance that our tax provision or tax payments will not be adversely affected by these initiatives. In addition, U.S. federal, state and local, and international tax laws and regulations are extremely complex and subject to varying interpretations. There can be no assurance that our tax positions will not be challenged by relevant tax authorities or that we would be successful in any such challenge.
Our ability to use NOLs and interest expense limitation carryovers to offset future income may be limited.
Our ability to use any NOLs and interest expense limitation carryovers generated by us could be substantially limited if we were to experience an “ownership change” as defined under Section 382 of the Code. In general, an “ownership change” would occur if our “5-percent stockholders,” as defined under Section 382 of the Code, including certain groups of persons treated as “5-percent stockholders,” collectively increased their ownership in us by more than 50 percentage points over a rolling three-year period. An ownership change can occur as a result of a public offering of our common stock, as well as through secondary market purchases of our common stock and certain types of reorganization transactions. We have experienced ownership changes, which may result in an annual limitation on the use of its pre-ownership change NOLs (and certain other losses and/or credits) equal to the equity value of our stock immediately before the ownership change, multiplied by the long-term tax-exempt rate for the month in which the ownership change occurs. During the year ended December 31, 2019, the IRS proposed regulations that would prevent us from using unrealized built-in gains to increase this limitation. If these regulations were finalized and we experienced an ownership change our ability to use our NOLs (and certain other losses and/or credits) may be limited. Such a limitation could, for any given year, have the effect of increasing the amount of our U.S. federal and state income tax liability, which would negatively impact the amount of after-tax cash available for distribution to our stockholders and our financial condition.
Legal and Regulatory Risks
Temporary pause on pending approvals of LNG exports may negatively impact our business.
On January 26, 2024, the Biden administration announced that the U.S. implemented a temporary pause on pending decisions on permits to export LNG to non-Free Trade Agreement countries until the DOE can update its underlying analyses for authorization. This temporary pause on pending approvals of LNG exports may be unpredictable and may negatively impact our business.
From time to time, we are subject to various claims, tax audits, litigation and other proceedings that could ultimately be resolved against us and require material future cash payments or charges, which could impair our financial condition or results of operations.
The size, nature and complexity of our business make us susceptible to various claims, tax audits, litigation and binding arbitration proceedings. We are currently, and may in the future become, subject to various claims, which, if not resolved within amounts we have accrued, could have a material adverse effect on our financial position, results of operations or cash flows, including our ability to pay dividends. Similarly, any claims, even if fully indemnified or insured, could negatively impact our reputation among our customers and the public, and make it more difficult for us to compete effectively or obtain adequate insurance in the future. See Part I, Item 3 “Legal Proceedings” of this form 10-K and Note 16 (“Commitments and Contingencies”) to our Financial Statements for additional information regarding certain legal proceedings to which we are a party.
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New regulations, proposed regulations and proposed modifications to existing regulations under the CAA, if implemented, could result in increased compliance costs.
In June 2016, the EPA issued final regulations amending the NSPS for the oil and natural gas source category and applying to sources of emissions of methane and VOC from certain processes, activities and equipment that is constructed, modified or reconstructed after September 18, 2015. Specifically, the regulation contains both methane and VOC standards for several emission sources not previously covered by the NSPS, such as fugitive emissions from compressor stations and pneumatic pumps and methane standards for certain emission sources that are already regulated for VOC, such as equipment leaks at natural gas processing plants. The amendments also establish methane standards for a subset of equipment that the current NSPS regulates, including reciprocating compressors and pneumatic controllers, and extend the current VOC standards to the remaining unregulated equipment.
In December 2023, the EPA adopted even more stringent rules with respect to methane and VOC for new and existing sources, via NSPS OOOOb and NSPS OOOOc. While the rules have been approved by the EPA Administrator and published on the EPA website, they have not yet been published in the Federal Register. Once published, the rules become effective 60 days thereafter.
A separate BoLM rule to address methane emissions on public lands was proposed in November 2022. Among the newly adopted and proposed methane requirements that may impact our operations are broader applicability to compression equipment relative to the existing rules, increased work practices and inspection requirements and mandates for certain new zero-emissions equipment.
Meanwhile, several states - including, most notably, New Mexico and Colorado - have been developing their own more stringent methane rules that will or are anticipated to impose additional requirements on the industry. We, together with a consortium of other Gas Compressor Association member companies, were actively involved in the rulemaking effort in New Mexico, including working directly with the New Mexico Environmental Department and participating in the New Mexico Environmental Improvement Board’s hearing in late 2021.
We do not believe that the current rules will have a material adverse impact on our business, financial condition, results of operations or cash flows, but we cannot yet definitively predict the impact of any revision of the current rules or issuance of new rules, which impact could be material.
On October 1, 2015, the EPA issued a new NAAQS ozone standard of 70 ppb, which is a tightening from the 75 ppb standard set in 2008. This new standard became effective on December 28, 2015, and the EPA completed designating attainment/non-attainment regions under the revised ozone standard in 2018. In November 2016, the EPA proposed an implementation rule for the 2015 NAAQS ozone standard, but the agency has yet to issue a final implementation rule. State implementation of the revised 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, the costs of which could be significant. By law, the EPA must review each NAAQS every five years. In December 2018 and again in December 2020, the EPA announced that it was retaining without revision the 2015 NAAQS ozone standard. In June 2021, the EPA commenced a process for reconsidering the December 2020 decision but more recent EPA announcements suggest that no changes are expected until 2025. We do not believe continued implementation of the NAAQS ozone standard will have a material adverse impact on our business, financial condition, results of operations or cash flows, but we cannot yet predict the impact, if any, of any new Federal Implementation Plan involving new NAAQS standards.
New environmental regulations and proposals similar to these, when finalized, and any other new regulations requiring the installation of more sophisticated pollution control equipment or the adoption of other environmental protection measures, could have a material adverse impact on our business, financial condition, results of operations and cash flows. Notably, opposition to energy development and infrastructure projects has led to regulatory and judicial challenges to new facilities, including compression facilities, in states such as Massachusetts and Virginia. While we have not directly faced any such challenges to the facilities at which we provide contract operations and know of no pending or threatened efforts targeting those facilities, expanded opposition to energy infrastructure, including facilities at which we provide contract operations or in the future might otherwise have an opportunity to provide contract operations, could potentially give rise to material impacts in the future.
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We are subject to a variety of governmental regulations; failure to comply with these regulations may result in administrative, civil and criminal enforcement measures and changes in these regulations could increase our costs or liabilities.
We are subject to a variety of U.S. federal, state and local laws and regulations, including relating to the environment, health and safety, labor and employment and taxation. Many of these laws and regulations are complex, change frequently, are becoming increasingly stringent, and the cost of compliance with these requirements can be expected to increase over time. Failure to comply with these laws and regulations may result in a variety of administrative, civil and criminal enforcement measures, including assessment of monetary penalties, imposition of remedial requirements and issuance of injunctions as to future compliance. From time to time, as part of our operations, including newly acquired operations or in the future might otherwise have an opportunity to provide contract operations, we may be subject to compliance audits by regulatory authorities in the various states in which we operate.
Environmental laws and regulations may, in certain circumstances, impose strict liability for environmental contamination, which may render us liable for remediation costs, natural resource damages and other damages as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior owners or operators or other third parties. In addition, where contamination may be present, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury, property damage and recovery of response costs. Remediation costs and other damages arising as a result of environmental laws and regulations, and costs associated with new information, changes in existing environmental laws and regulations or the adoption of new environmental laws and regulations could be substantial and could negatively impact our financial condition, profitability and results of operations. Moreover, failure to comply with these environmental laws and regulations may result in the imposition of administrative, civil and criminal penalties and the issuance of injunctions delaying or prohibiting operations.
We may need to apply for or amend facility permits or licenses from time to time with respect to storm water or wastewater discharges, waste handling, or air emissions relating to manufacturing activities or equipment operations, which subjects us to new or revised permitting conditions that may be onerous or costly to comply with. In addition, certain of our customer service arrangements may require us to operate, on behalf of a specific customer, petroleum storage units such as underground tanks or pipelines and other regulated units, all of which may impose additional compliance and permitting obligations. Any failure to obtain or delay in obtaining required permits, licenses and other governmental approvals by our customers could result in production delays and thereby, indirectly materially and adversely impact our operations and business.
We conduct operations at numerous facilities in a wide variety of locations across the continental U.S. The operations at many of these facilities require environmental permits or other authorizations. Additionally, natural gas compressors at many of our customers’ facilities require individual air permits or general authorizations to operate under various air regulatory programs established by rule or regulation. These permits and authorizations frequently contain numerous compliance requirements, including monitoring and reporting obligations and operational restrictions, such as emission limits. Given the large number of facilities in which we operate, and the numerous environmental permits and other authorizations that are applicable to our operations, we may occasionally identify or be notified of technical violations of certain requirements existing in various permits or other authorizations. Occasionally, we have been assessed penalties for our non-compliance, and we could be subject to such penalties in the future.
We routinely deal with oil, natural gas and other petroleum products. Hydrocarbons or other hazardous substances or wastes may have been disposed or released on, under or from properties used by us to provide contract operations services or inactive compression storage or on or under other locations where such substances or wastes have been taken for disposal. These properties may be subject to investigatory, remediation and monitoring requirements under environmental laws and regulations, and such requirements may vary.
The modification or interpretation of existing environmental laws or regulations, the more vigorous enforcement of existing environmental laws or regulations, or the adoption of new environmental laws or regulations may also negatively impact oil and natural gas exploration and production, gathering and pipeline companies, including our customers, which in turn could have a negative impact on us.
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Climate change legislation, regulatory initiatives and stakeholder pressures could result in increased compliance costs, financial risks and potential reduction in demand for our services.
Climate change legislation and regulatory initiatives may arise from a variety of sources, including international, national, regional and state levels of government and associated administrative bodies, seeking to restrict or regulate emissions of GHG, such as carbon dioxide and methane.
Congress has previously considered legislation to restrict or regulate emissions of GHG. Energy legislation and other initiatives continue to be proposed that may be relevant to GHG emissions issues. Almost half of the states, either individually or through multi-state regional initiatives, have begun to address GHG emissions, primarily through the planned development of emission inventories or regional GHG cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of GHG emissions, such as electric power plants, it is possible that smaller sources such as our natural gas-powered compressors could become subject to GHG-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for GHG emissions resulting from our operations.
The $1 trillion legislative infrastructure package passed by Congress in November 2021 includes a number of climate-focused spending initiatives targeted at climate resilience, enhanced response and preparation for extreme weather events, and clean energy and transportation investments. Significant additional legislative action by Congress also occurred in August 2022 with the Inflation Reduction Act, which provides $391 billion in funding for research and development and incentives for low-carbon energy production methods, carbon capture, and other programs directed at encouraging de-carbonization and addressing climate change.
Independent of Congress, the EPA has promulgated regulations controlling GHG emissions under its existing CAA authority. The EPA has adopted rules requiring many facilities, including petroleum and natural gas systems, to inventory and report their GHG emissions. In 2023, we did not operate any facilities that were subject to these reporting obligations. In addition, the EPA rules provide air permitting requirements for certain large sources of GHG emissions. The requirement for large sources of GHG emissions to obtain and comply with permits will affect some of our and our customers’ largest new or modified facilities going forward, but is not expected to cause us to incur material costs. As noted above, the EPA has undertaken efforts to regulate emissions of methane, considered a GHG, in the oil and gas sector, with the development of additional, more stringent rules under way.
In an executive order issued on January 20, 2021, the POTUS asked the heads of all executive departments and agencies to review and take action to address any federal regulations, orders, guidance documents, policies and any similar agency actions promulgated during the prior administration that may be inconsistent with or present obstacles to the administration’s stated goals of protecting public health and the environment, and conserving national monuments and refuges. The executive order also established an Interagency Working Group on the Social Cost of Greenhouse Gases, which is called on to, among other things, capture the full costs of GHG emissions, including the “social cost of carbon,” “social cost of nitrous oxide” and “social cost of methane,” which are “the monetized damages associated with incremental increases in greenhouse gas emissions,” including “changes in net agricultural productivity, human health, property damage from increased flood risk, and the value of ecosystem services.” The current administration adopted an interim social cost of carbon of $51 per ton in February 2021, but in recent rulemakings the EPA has referenced a figure as high as $2,400 per ton effective in 2030. This figure is intended to be used to guide federal decisions on the costs and benefits of various policies and approvals; such efforts have been the subject of a series of judicial challenges, which have been largely unsuccessful to date. At this time, we cannot determine whether the administration’s efforts on social cost or other interagency climate efforts will lead to any particular actions that give rise to a material adverse effect on our business, financial condition, results of operations and cash flows.
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At the international level, the U.S. joined the international community at the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change in Paris, France, which resulted in an agreement intended to nationally determine their contributions and set GHG emission reduction goals every five years beginning in 2020. While the Agreement did not impose direct requirements on emitters, national plans to meet its pledge could have resulted in new regulatory requirements. In November 2019, however, plans were formally announced for the U.S. to withdraw from the Paris Agreement with an effective exit date in November 2020. In April 2021, the current administration announced reentry of the U.S. into the Paris Agreement along with a new “nationally determined contribution” for U.S. GHG emissions that would achieve emissions reductions of at least 50% relative to 2005 levels by 2030. Those national commitments by themselves create no binding requirements on individual companies or facilities, but they do provide indications of the current administration’s policy direction and the types of legislative and regulatory requirements, such as the EPA’s proposed methane rules, that may be needed to achieve those commitments. Relatedly, the U.S. and European Union jointly announced the launch of the “Global Methane Pledge,” which aims to cut global methane pollution at least 30% by 2030 relative to 2020 levels, including “all feasible reductions” in the energy sector. More recently the international community’s December 2023 meeting known as COP28 reaffirmed commitments to the Paris Agreement and concluded an agreement that the world must move away from fossil fuel energy in a just, orderly, and equitable manner and achieve net zero GHG emissions by 2050, while recognizing a transitional role for fossil fuels. With the exception of the proposed methane rules discussed above, we cannot predict whether re-entry into the Paris Agreement or other international pledges will result in any particular new regulatory requirements or whether such requirements will cause us to incur material costs.
In sum, any legislation, regulatory programs or social pressures related to climate change could increase our costs and require substantial capital, compliance, operating and maintenance costs, reduce demand for our services and reduce our access to financial markets. Current, as well as potential future, laws and regulations that limit GHG emissions or that otherwise promote the use of renewable energy over fossil fuel energy sources could increase the cost of our midstream services and, thereby, further reduce demand and adversely affect our sales volumes, revenues and margins.
A climate-related decrease in demand for oil and natural gas could negatively affect our business.
Supply and demand for oil and natural gas is dependent upon a variety of factors, many of which are beyond our control. These factors include, among others, the potential adoption of new government regulations, including those related to fuel conservation measures and climate change regulations, technological advances in fuel economy and energy generation devices. For example, legislative, regulatory or executive actions intended to reduce emissions of GHG could increase the cost of consuming crude oil and natural gas, thereby potentially causing a reduction in the demand for such products. A broader transition to alternative fuels or energy sources, whether resulting from potential new government regulation, carbon taxes or consumer preferences could result in decreased demand for crude oil, natural gas and NGLs. Any decrease in demand for these products could consequently reduce demand for our services and could have a negative effect on our business.
Also, recent activism directed at shifting funding away from companies with energy-related assets could result in a reduction of funding for the energy sector overall, which could have an adverse effect on our ability to obtain external financing as well as negatively affect the cost of, and terms for, financing to fund capital expenditures or other aspects of our business.
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Climate change may increase the frequency and severity of weather events that could result in severe personal injury, property and environmental damage, which could curtail our or our customers’ operations and otherwise materially adversely affect our cash flows.
Some scientists have concluded that increasing concentrations of GHG in the 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 assets and operations, including damages to our or our customers’ facilities and assets from powerful wind or rising waters. We may experience increased insurance costs, or difficulty obtaining adequate insurance coverage, for our assets in areas subject to more frequent severe weather. We may not be able to recoup these increased costs through the rates we charge our customers. Extreme weather events could cause damage to property or facilities that could exceed our insurance coverage and our business, financial condition and results of operations could be adversely affected.
Another possible consequence of climate change is increased volatility in seasonal temperatures. The market for natural gas and natural gas liquids is generally impacted by periods of colder weather and warmer weather, so any changes in climate could affect the market for those 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.
Increased environmental, social and governance scrutiny and changing expectations from stakeholders may impose additional costs or additional risks.
In recent years, increasing attention has been given to corporate activities related to ESG matters. A number of advocacy groups, both domestically and internationally, have campaigned for governmental and private action to promote change at public companies related to ESG matters, including increasing attention and demands for action related to climate change, promoting the use of substitutes to fossil fuel products and encouraging the divestment of companies in the fossil fuel industry. Companies which do not adapt to or comply with expectations and standards on ESG matters, as they continue to evolve, or which are perceived to have not responded appropriately to the growing concern for ESG issues, regardless of whether there is a legal requirement to do so, may suffer from reputational damage and the business, financial condition and/or stock price of such a company could be materially and adversely affected.
Our operations, projects and growth opportunities require us to have strong relationships with various key stakeholders, including our shareholders, employees, suppliers, customers, local communities and others. We may face pressures from stakeholders, many of whom are increasingly focused on climate change, to prioritize sustainable energy practices, reduce our carbon footprint and promote sustainability while at the same time remaining a successfully operating public company. If we do not successfully manage expectations across these varied stakeholder interests, it could erode our stakeholder trust and thereby affect our brand and reputation. Such erosion of confidence could negatively impact our business through decreased demand and growth opportunities, delays in projects, increased legal action and regulatory oversight, adverse press coverage and other adverse public statements, difficulty hiring and retaining top talent, difficulty obtaining necessary approvals and permits from governments and regulatory agencies on a timely basis and on acceptable terms, and difficulty securing investors and access to capital. The occurrence of any of the foregoing could have a material adverse effect on our business and financial condition.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments
None.
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ITEM 2. PROPERTIES
Item 2. Properties
The following table describes the material facilities that we owned or leased at December 31, 2023:
Location
Status
Square Feet
Use by Segment
Houston, Texas
Leased
75,000
Corporate office - Contract Operations and Aftermarket Services
Greeley, Colorado
Leased
10,000
Contract Operations and Aftermarket Services
Houma, Louisiana
Owned
60,000
Contract Operations and Aftermarket Services
Carlsbad, New Mexico
Leased
11,200
Contract Operations and Aftermarket Services
Yukon, Oklahoma
Owned
85,000
Contract Operations and Aftermarket Services
West Alexander, Pennsylvania
Leased
15,000
Contract Operations and Aftermarket Services
Asherton, Texas
Leased
9,000
Contract Operations and Aftermarket Services
Kenedy, Texas
Leased
11,000
Contract Operations and Aftermarket Services
Midland, Texas
Owned
51,000
Contract Operations and Aftermarket Services
Pecos, Texas
Leased
10,000
Contract Operations and Aftermarket Services
Victoria, Texas
Owned
23,000
Contract Operations and Aftermarket Services
Victoria, Texas
Owned
66,000
Contract Operations and Aftermarket Services
Our executive office is located at 9807 Katy Freeway, Suite 100, Houston, Texas 77024 and our telephone number is 281-836-8000.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings
In the ordinary course of business, we are involved in various pending or threatened legal actions. While we are unable to predict the ultimate outcome of these actions, we believe that any ultimate liability arising from any of these actions will not have a material adverse effect on our consolidated financial position, results of operations or cash flows, including our ability to pay dividends. However, because of the inherent uncertainty of litigation and arbitration proceedings, we cannot provide assurance that the resolution of any particular claim or proceeding to which we are a party will not have a material adverse effect on our consolidated financial position, results of operations or cash flows, including our ability to pay dividends.
See note 16 (“Commitments and Contingencies”) to our Financial Statements for additional information regarding litigation, claims and other legal proceedings.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures
Not applicable.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Common Stock
Our common stock is traded on the New York Stock Exchange under the symbol “AROC.” On February 14, 2024, the closing price of our common stock was $16.26 per share.
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Comparison of Five Year Cumulative Total Return
The performance graph below shows the cumulative total stockholder return on our common stock compared with the S&P 500, AMNAX and AMZ indices over the five-year period beginning on December 31, 2018. The results are based on an investment of $100 in each of our common stock, the S&P 500, the AMNAX and the AMZ. The graph assumes reinvestment of dividends and adjusts all closing prices and dividends for stock splits.
The performance graph shall not be deemed incorporated by reference by any general statement incorporating by reference this 2023 Form 10-K into any filing under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that we specifically incorporate this information by reference, and shall not otherwise be deemed filed under those Acts.
Holders
As of February 14, 2024, there were approximately 1,550 holders of record of our common stock. The actual number of stockholders is greater than this number of record holders and includes stockholders who are beneficial owners but whose shares are held in street name by banks, brokers and other nominees.
Dividends
On January 25, 2024, our Board of Directors declared a quarterly dividend of $0.165 per share of common stock, or approximately $25.9 million, which was paid on February 13, 2024 to stockholders of record at the close of business on February 6, 2024. Any future determinations to pay cash dividends to our stockholders will be at the discretion of our Board of Directors and will be dependent upon our financial condition, results of operations, and credit and loan agreements in effect at that time and other factors deemed relevant by our Board of Directors. We cannot provide assurance that we will declare or pay dividends in any particular amount or at all in the future.
Securities Authorized for Issuance under Equity Compensation Plans
For disclosures regarding securities authorized for issuance under equity compensation plans, see Part III, Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” of this 2023 Form 10-K.
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Unregistered Sales of Equity Securities and Use of Proceeds
None.
Purchases of Equity Securities by Issuer and Affiliated Purchasers
The following table summarizes our purchases of equity securities during the three months ended December 31, 2023:
Approximate Dollar
Value of Shares
Total Number of
That May Yet be
Average
Shares Purchased
Purchased Under
Total Number
Price
as Part of Publicly
the Publicly
of Shares
Paid per
Announced Plans
Announced Plans
(dollars in thousands, except per share amounts)
Purchased (1)
Share(2)
or Programs
or Programs
October 1, 2023 - October 31, 2023
79,112
$
12.26
79,112
$
42,535
November 1, 2023 - November 30, 2023
3,444
13.18
-
42,535
December 1, 2023 - December 31, 2023
95,000
14.68
95,000
41,140
Total
177,556
$
13.57
174,112
(1) Represents shares of common stock purchased from employees to satisfy tax withholding obligations in connection with the vesting of restricted stock awards and shares repurchased under the 2023 Share Repurchase Program during the period. See Note 17 (“Stockholders’ Equity”) for further details on the 2023 Share Repurchase Program.
(2) Average price paid per share includes costs associated with the repurchase, as applicable.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. [Reserved]

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our Financial Statements, the notes thereto, and the other financial information appearing elsewhere in this 2023 Form 10-K. The following discussion includes forward-looking statements that involve certain risks and uncertainties. See “Forward-Looking Statements” and Part I, Item 1A. “Risk Factors” in this 2023 Form 10-K.
This section primarily discusses 2023 and 2022 items and comparisons between these years. For a discussion of changes from 2021 to 2022 and other financial information related to 2021, refer to Part II, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our Annual Report on Form 10-K for the year ended December 31, 2022 filed with the SEC on February 23, 2023.
Overview
We are an energy infrastructure company with a pure-play focus on midstream natural gas compression. We are the leading provider of natural gas compression services to customers in the oil and natural gas industry throughout the U.S., in terms of total compression fleet horsepower, and a leading supplier of aftermarket services to customers that own compression equipment in the U.S. Our business supports a must-run service that is essential to the production, processing, transportation and storage of natural gas. The natural gas that we help transport satisfies demand from electricity generation, heating and cooking and the industrial and manufacturing sectors. Our geographic diversity, technically experienced personnel and large fleet of natural gas compression equipment enable us to provide reliable contract operations services to our customers.
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We operate in two business segments:
• Contract Operations. Our contract operations business is comprised of our owned fleet of natural gas compression equipment that we use to provide compression operations services to our customers.
• Aftermarket Services. Our aftermarket services business provides a full range of services to support the compression needs of our customers that own compression equipment, including operations, maintenance, overhaul and reconfiguration services and sales of parts and components.
Significant 2023 Transactions
In November 2023, we agreed to serve as the lead investor in a series A financing round for Ionada, a global carbon capture technology company committed to reducing GHG emissions and creating a sustainable future. Ionada has developed a post-combustion carbon capture solution to reduce carbon dioxide emissions from various small to mid-sized industrial emitters in the energy, marine and e-fuels industries, among others. See Note 12 (“Investments in Unconsolidated Affiliates”) to our Financial Statements for additional information about this investment.
Trends and Outlook
The key driver of our business is the production of U.S. oil and natural gas. Approximately 75% of our operating fleet is deployed for midstream natural gas gathering applications, with the remaining fleet being used in gas lift applications to enhance oil production. As our business is so closely aligned with production and is typically less directly impacted by commodity prices, we are not exposed to the volatility often faced in shorter-cycle oil field service businesses.
Domestic natural gas production generally occurs in either basins where natural gas is produced alongside oil, also known as “associated” gas, such as the Permian and Delaware Basins, the Eagle Ford and the Mid-Continent or in natural gas basins, such as the Marcellus, Utica and Haynesville Shales. Significant investment in domestic exploration and production and midstream infrastructure across the energy industry has been made over much of the past decade, particularly in the low-cost basins characterized by oil and associated natural gas production. The development of these basins producing both commodities has created additional incremental demand for natural gas compression over the recent past as it is a critical method to transport associated gas volumes or enhance oil production through gas lift.
Current Trends
According to the EIA Outlook, average U.S. oil and dry natural gas and production were as follows:
Year Ended December 31,
Average dry natural gas production (Bcf/d)
103.8
98.0
93.6
Average oil production (MMb/d)
12.9
11.9
11.2
During 2023, U.S. natural gas and oil production grew to record levels, resulting in strong demand for our compression services and we increased our investment in new fleet units. Our contract operations revenue and total operating horsepower increased 19% and 5%, respectively in 2023. Similar increases in demand in 2023 were seen in our aftermarket services business, where we experienced an increase of 8% in aftermarket services revenue.
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Outlook
The EIA Outlook forecasts the following year-over-year changes:
Year Ended December 31,
U.S. dry natural gas production
%
%
U.S. oil production
%
%
U.S. natural gas domestic consumption
%
(1)
%
Liquefied natural gas exports
%
%
The EIA Outlook expects natural gas production to continue to increase to all-time highs in 2024 and 2025. Natural gas consumption is also expected to increase, reflecting consistent usage of natural gas in the electric power generation and residential sectors, as well as increased LNG exports and exports of natural gas via pipeline to Mexico.
We believe the outlook for the energy industry in the U.S. is positive. While we anticipate that the combination of commodity prices and demand may likely have a positive impact on activity levels in both the upstream and midstream sectors, we cannot predict the ultimate magnitude of that impact on our business and expect it to be varied across our operations, depending on the region, customer, nature of our services, contract term and other factors. However, we continue to believe that overall the long-term demand for our compression services will continue given the necessity of compression in facilitating the transportation and processing of natural gas.
Regarding our aftermarket services business, the base of owned compression in the U.S. has increased over the past several years, which we believe will help sustain our aftermarket services business over the long term.
Key Challenges and Uncertainties
In addition to general market conditions in the oil and natural gas industry and competition in the natural gas compression industry, we believe the following represent the key challenges and uncertainties we will face in the future.
Capital Requirements and the Availability of External Sources of Capital. We have funded a significant portion of our capital expenditures and acquisitions through borrowings under our Credit Facility and have issued a substantial amount of debt, which could limit our ability to fund future planned capital expenditures. Current conditions could limit our ability to access the debt and equity markets to raise capital on affordable terms in 2024 and beyond. If we are not successful in raising capital within the time period required or at all, we may not be able to fund these capital expenditures, which could impair our ability to grow or maintain our business.
Cost Management. In order to improve our operations and further reduce operating expenses, we are investing significant resources into a process and technology transformation project that has, among other things, replaced our existing ERP, supply chain and inventory management systems and expanded the remote monitoring capabilities of our compression fleet. Cost management continues to be challenging, however, and there is no guarantee that our efforts will result in a reduction in our operating expenses. Natural gas production growth and resulting demand for our services could cause us to experience increased operating expenses as we hire employees and incur additional expenses needed to support the rebound in market demand.
Further, we depend on suppliers for the materials, parts, equipment and lube oil necessary to our operations, which exposes us to volatility in prices. Significant price increases for these inputs could adversely affect our operating profits. Supply chain disruptions could also adversely affect our ability to obtain, or increase the cost of, such items. While we generally attempt to mitigate the impact of increased prices through strategic purchasing decisions, diversification of our supplier base, where possible, and the passing along of increased costs to customers, there may be a time delay between the increased commodity prices and the ability to increase the price of our services.
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Labor. We believe that our ability to hire, train and retain qualified personnel will continue to be important. Although we have been able to historically satisfy our personnel needs, retaining employees in our industry continues to be a challenge. Our ability to grow and to continue our current level of service to our customers will depend in part on our success in hiring, training and retaining our employees. Further, the cost of labor has increased and may continue to increase in the future with increases in demand, which will require us to incur additional costs.
Demand for natural gas-powered compression. Demand for our services is dependent on the demand for natural gas in the markets we serve. Although the EIA currently forecasts natural gas demand will grow through 2050, technological advances and accelerated adoption of renewable sources of energy could reduce demand for natural gas in our markets and have an adverse effect on our business. In addition, increased focus of our customers on reducing emissions from, or the use of, combustion engines in compression could increase demand for electric motor-driven compressors or require us to make modifications to our existing natural gas-powered units.
Operating Highlights
Year Ended December 31,
(horsepower in thousands)
Total available horsepower (at period end)(1)
3,759
3,726
3,878
Total operating horsepower (at period end)(2)
3,607
3,448
3,247
Average operating horsepower
3,554
3,328
3,282
Horsepower utilization:
Spot (at period end)
%
%
%
Average
%
%
%
(1) Defined as idle and operating horsepower. Includes new compressors completed by third party manufacturers that have been delivered to us.
(2) Defined as horsepower that is operating under contract and horsepower that is idle but under contract and generating revenue such as standby revenue.
Non-GAAP Financial Measures
Management uses a variety of financial and operating metrics to analyze our performance. These metrics are significant factors in assessing our operating results and profitability and include the non-GAAP financial measure of gross margin.
We define gross margin as total revenue less cost of sales (excluding depreciation and amortization). Gross margin is included as a supplemental disclosure because it is a primary measure used by our management to evaluate the results of revenue and cost of sales (excluding depreciation and amortization), which are key components of our operations. We believe gross margin is important because it focuses on the current operating performance of our operations and excludes the impact of the prior historical costs of the assets acquired or constructed that are utilized in those operations, the indirect costs associated with our SG&A activities, our financing methods and income taxes. In addition, depreciation and amortization may not accurately reflect the costs required to maintain and replenish the operational usage of our assets and therefore may not portray the costs of current operating activity. As an indicator of our operating performance, gross margin should not be considered an alternative to, or more meaningful than, net income (loss) as determined in accordance with GAAP. Our gross margin may not be comparable to a similarly-titled measure of other entities because other entities may not calculate gross margin in the same manner.
Gross margin has certain material limitations associated with its use as compared to net income (loss). These limitations are primarily due to the exclusion of SG&A, depreciation and amortization, impairments, restructuring charges, interest expense, debt extinguishment loss, gain on sale of assets, net, other (income) expense, net, and provision for (benefit from) income taxes. Because we intend to finance a portion of our operations through borrowings, interest expense is a necessary element of our costs and our ability to generate revenue. Additionally, because we use capital assets, depreciation expense is a necessary element of our costs and our ability to generate revenue and SG&A is necessary to support our operations and required corporate activities. To compensate for these limitations, management uses this non-GAAP measure as a supplemental measure to other GAAP results to provide a more complete understanding of our performance.
Table Archrock, Contents
The reconciliation of net income to gross margin is as follows:
Year Ended December 31,
(in thousands)
Net income
$
104,998
$
44,296
$
28,217
Selling, general and administrative
116,639
117,184
107,167
Depreciation and amortization
166,241
164,259
178,946
Long-lived and other asset impairment
12,041
21,442
21,397
Restructuring charges
1,775
-
2,903
Interest expense
111,488
101,259
108,135
Gain on sale of assets, net
(10,199)
(40,494)
(30,258)
Other expense (income), net
1,086
1,845
(4,707)
Provision for income taxes
37,249
16,293
10,744
Gross margin
$
541,318
$
426,084
$
422,544
RESULTS OF OPERATIONS
Summary of Results
Revenue was $990.3 million and $845.6 million during the years ended December 31, 2023 and 2022, respectively. The increase in revenue was due to increased revenue from both our contract operations business and aftermarket services business. See “Contract Operations” and “Aftermarket Services” below for further details.
Net income was $105.0 million and $44.3 million during the years ended December 31, 2023 and 2022, respectively. The increase was primarily driven by a higher gross margin from both our contract operations business and aftermarket services business and decreases in long-lived asset impairment expense and SG&A. These changes were partially offset by a decrease in the gain on sale of assets and the unrealized change in fair value of our investment in an unconsolidated affiliate and increases in our provision for income taxes, interest expense, depreciation and amortization and restructuring charges.
Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
Contract Operations
Year Ended December 31,
Increase
(dollars in thousands)
(Decrease)
Revenue
$
809,439
$
677,801
%
Cost of sales (excluding depreciation and amortization)
306,748
278,898
%
Gross margin
$
502,691
$
398,903
%
Gross margin percentage (1)
%
%
%
(1) Defined as gross margin divided by revenue.
Revenue in our contract operations business increased primarily due to higher rates for contract compression in response to market conditions and an increase in average operating horsepower, partially offset by the impact of strategic dispositions of horsepower in 2022.
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The increase in cost of sales was primarily due to a $10.8 million increase in parts expense as a result of an increase in maintenance activities and a $1.9 million increase in lube oil expenses which were both driven by higher pricing throughout our supply chain, as well as increased volumes associated with unit redeployment as customer activity accelerated. The increase in cost of sales was also due to an increase of $8.1 million in total employee compensation expense. Further, cost of sales for the year ended December 31, 2023 includes an increase of $9.1 million for sales tax as a result of a change in tax compliance for sales tax associated with contract operations cost of sales. Prior to 2023, contract operations sales tax amounts were recognized in SG&A. Partially offsetting these cost increases was the decrease in expense attributable to the horsepower sold in 2022.
Gross margin percentage increased primarily due to an increase in revenue which exceeded the increase in cost of sales.
Aftermarket Services
Year Ended December 31,
Increase
(dollars in thousands)
(Decrease)
Revenue
$
180,898
$
167,767
%
Cost of sales (excluding depreciation and amortization)
142,271
140,586
%
Gross margin
$
38,627
$
27,181
%
Gross margin percentage
%
%
%
Revenue in our aftermarket services business increased primarily due to higher service activities and parts sales from the continuation of the market recovery which began in the prior year and continues to drive an increase in customer demand.
Gross margin increased in our aftermarket services business as a result of increased revenues which exceeded the increase in cost of sales due to differences in the scope, timing and type of activities performed. The increase in cost of sales resulted from an increase in cost of service activities of $5.0 million attributable to increased labor and parts costs, which was partially offset by a reduction in the use of parts and labor from third party providers, which resulted in savings of $3.2 million.
Costs and Expenses
Year Ended December 31,
(in thousands)
Selling, general and administrative
$
116,639
$
117,184
Depreciation and amortization
166,241
164,259
Long-lived and other asset impairment
12,041
21,442
Restructuring charges
1,775
-
Interest expense
111,488
101,259
Gain on sale of assets, net
(10,199)
(40,494)
Other expense (income), net
1,086
1,845
Selling, general and administrative. The decrease in SG&A was primarily due to a decrease of $8.0 million for sales tax as a result of a change in tax compliance for sales tax associated with contract operations cost of sales. Beginning in 2023, contract operations sales tax amounts are recognized in contract operations cost of sales. Further, SG&A for the year ended December 31, 2023 includes a $2.2 million decrease in professional expense and a $1.3 million decrease in accrued expenses, partially offset by a $5.4 million increase in long-term performance-based incentive compensation expense, a $4.0 million increase in short-term incentive expense and a $1.6 million increase in software and maintenance expense.
Depreciation and amortization. The increase in depreciation and amortization expense was primarily due to an increase in depreciation expense associated with fixed asset additions and accelerated depreciation associated with certain assets. These increases were partially offset by a decrease in depreciation expense resulting from assets reaching the end of their depreciable lives, the impact of compression and other asset sales, and long-lived asset impairments.
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Long-lived and other asset impairment. We periodically review the future deployment of our idle compressors for units that are not of the type, configuration, condition, make or model that are cost efficient to maintain and operate. We also evaluate for impairment our idle units that have been culled from our compression fleet in prior years and are available for sale. During the years ended December 31, 2023 and 2022, we recognized $12.0 million and $21.4 million, respectively, of impairment charges to write down these compressors to their fair value. The decrease in impairment charges on compressors is due to an increase in customer demand and as a result, higher utilization of our equipment. See Note 21 (“Long-Lived Asset and Other Impairments”) for further details on these impairment charges. The following table presents the results of our compression fleet impairment review, as recorded in our contract operations segment:
Year Ended December 31,
(dollars in thousands)
Idle compressors retired from the active fleet
Horsepower of idle compressors retired from the active fleet
53,000
100,000
Impairment recorded on idle compressors retired from the active fleet
$
12,034
$
21,431
Restructuring charges. Restructuring charges of $1.8 million during the year ended December 31, 2023 consisted of severance and consulting costs related to our restructuring activities. See Note 22 (“Restructuring Charges”) for further details on these restructuring charges.
Interest expense. The increase in interest expense was due to an increase in interest rates, a higher average outstanding balance of long-term debt and the write-off of $1.0 million of unamortized deferred financing costs as a result of the Amended and Restated Credit Agreement, partially offset by an increase in capitalized interest.
Gain on sale of assets, net. The decrease in gain on sale of assets was primarily due to gains of $7.6 million on compression asset sales during the year ended December 31, 2023 compared to gains of $38.5 million on compression asset sales during the year ended December 31, 2022.
The net gain on the sales of assets during 2022 was primarily the result of $28.1 million of gains recognized on sales of certain contract operations customer service agreements and approximately 770 compressors and $12.4 million of gains recognized on other compression asset sales and transportation and shop asset sales during the period.
Other expense (income), net. The decrease in other expense (income), net was primarily due to a $0.9 million decrease in the unrealized change in the fair value of our investment in an unconsolidated affiliate during the year ended December 31, 2023 compared to the year ended December 31, 2022.
Provision for Income Taxes
The increase in provision for income taxes was primarily due to the tax effect of the increase in book income during the year ended December 31, 2023, compared to the year ended December 31, 2022.
Year Ended December 31,
Increase
(dollars in thousands)
(Decrease)
Provision for income taxes
$
37,249
$
16,293
%
Effective tax rate
%
%
(1)
%
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LIQUIDITY AND CAPITAL RESOURCES
Overview
Our ability to fund operations, finance capital expenditures and pay dividends depends on the levels of our operating cash flows and access to the capital and credit markets. Our primary sources of liquidity are cash flows generated from our operations and our borrowing availability under our Credit Facility. Our cash flow is affected by numerous factors including prices and demand for our services, oil and natural gas exploration and production spending, conditions in the financial markets and other factors. We have no near-term maturities and believe that our operating cash flows and borrowings under the Credit Facility will be sufficient to meet our future liquidity needs.
We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or exchanges for equity or debt securities in open market purchases, privately negotiated transactions or otherwise. Such repurchases or exchanges, if any, may be material, will be upon terms and prices as we may determine and will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors.
Cash Requirements
Our contract operations business is capital intensive, requiring significant investment to maintain and upgrade existing operations. Our capital spending is primarily dependent on the demand for our contract operations services and the availability of the type of compression equipment required for us to provide those contract operations services to our customers. Our capital requirements have consisted primarily of, and we anticipate will continue to consist of, the following:
• operating expenses, namely employee compensation and benefits, inventory and lube oil purchases;
• growth capital expenditures;
• maintenance capital expenditures;
• interest on our outstanding debt obligations; and
• dividend payments to our stockholders.
Capital Expenditures
Growth Capital Expenditures. The majority of our growth capital expenditures are related to the acquisition cost of new compressors when our idle equipment cannot be reconfigured to economically fulfill a project’s requirements and the new compressor is expected to generate economic returns that exceed our cost of capital over the compressor’s expected useful life. In addition to newly-acquired compressors, growth capital expenditures include the upgrading of major components on an existing compression package where the current configuration of the compression package is no longer in demand and the compressor is not likely to return to an operating status without the capital expenditures. These expenditures substantially modify the operating parameters of the compression package such that it can be used in applications for which it previously was not suited.
Growth capital expenditures were $190.3 million and $146.3 million during the years ended December 31, 2023 and 2022, respectively. The increase in growth capital expenditures from 2022 to 2023 was the result of increased investment in new compression equipment as a result of higher customer demand.
Maintenance Capital Expenditures. Maintenance capital expenditures are related to major overhauls of significant components of a compression package, such as the engine, compressor and cooler, which return the components to a like-new condition, but do not modify the application for which the compression package was designed.
Maintenance capital expenditures were $92.2 million and $84.2 million during the years ended years ended December 31, 2023 and 2022, respectively. The increase in maintenance capital expenditures from 2022 to 2023 was the result of an increase in scheduled maintenance activities due to maintenance cycle requirements as well as additional make-ready investment as we return idle equipment to work to meet customer demand.
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Projected Capital Expenditures. While market activity continues to be strong, we currently anticipate reducing capital expenditures in 2024 compared to 2023 to support free cash flow generation after dividends, and plan to spend approximately $275.0 million to $290.0 million in capital expenditures during the year ended December 31, 2024, primarily consisting of approximately $175.0 million to $180.0 million for growth capital expenditures and approximately $80.0 million to $85.0 million for maintenance capital expenditures.
Dividends
On January 25, 2024, our Board of Directors declared a quarterly dividend of $0.165 per share of common stock, or approximately $25.9 million, which was paid on February 13, 2024 to stockholders of record at the close of business on February 6, 2024. Any future determinations to pay cash dividends to our stockholders will be at the discretion of our Board of Directors and will be dependent upon our financial condition, results of operations, and credit and loan agreements in effect at that time and other factors deemed relevant by our Board of Directors.
Share Repurchase Program
On April 27, 2023, our Board of Directors authorized the 2023 Share Repurchase Program which allows us to repurchase up to $50.0 million of outstanding common stock. Under the 2023 Share Repurchase Program, shares of our common stock may be repurchased periodically, including in the open market, privately negotiated transactions, or otherwise in accordance with applicable federal securities laws, at any time until April 27, 2024. The actual timing, manner, number, and value of shares repurchased under the program will be determined by us at our discretion.
The following table summarizes shares repurchased under the 2023 Share Repurchase Program during the year ended December 31, 2023:
Year Ended
(dollars in thousands, except per share amounts)
December 31, 2023
Total cost of shares repurchased
$
8,860
Average price per share
$
11.81
Total number of shares repurchased
750,374
Contractual Obligations
Our material contractual obligations as of December 31, 2023 consisted of the following:
• Long-term debt of $1.6 billion, all of which is due in 2027 and 2028;
• Estimated interest on our long-term debt of $428.8 million, consisting of annual payments of approximately $108.3 million in 2024 through 2026, approximately $82.5 million in 2027, and approximately $21.4 million in 2028;
• Purchase commitments of $192.7 million, of which $151.6 million is due in 2024, that primarily consist of commitments to purchase fleet assets and information technology-related costs; and
• Operating lease payments of $18.0 million that are spread relatively evenly in 2024 through 2032.
In addition, we had $19.5 million of unrecognized tax benefits (including discontinued operations) recorded as liabilities related to uncertain tax positions at December 31, 2023, which are uncertain as to if or when such amounts may be settled. We had a liability of $2.5 million recorded for potential penalties and interest (including discontinued operations) related to these unrecognized tax benefits at December 31, 2023, which we are uncertain as to if or when such amounts may be settled.
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Sources of Cash
Revolving Credit Facility
During the years ended December 31, 2023 and 2022, our Credit Facility had an average daily balance of $298.8 million and $235.4 million, respectively. The weighted average annual interest rate on the outstanding balance under the Credit Facility, excluding the effect of interest rate swaps, was 7.7% and 6.9% at December 31, 2023 and 2022, respectively. As of December 31, 2023, there were $4.5 million of letters of credit outstanding under the Credit Facility and the applicable margin on borrowings outstanding was 2.1%. We amended and restated our Credit Facility on May 16, 2023; see Note 15 (“Long-Term Debt”) to our Financial Statements for details on the Amended and Restated Credit Agreement.
Credit Facility Terms. Our Credit Facility matures on May 16, 2028 (or December 2, 2026 or December 3, 2027, as applicable, if any portion of our 2027 Senior Notes and 2028 Senior Notes, respectively, remain outstanding at such date) and has an aggregate revolving commitment of $750.0 million. Portions of the Credit Facility, up to $75.0 million, are available for the issuance of swing line loans and $50.0 million is available for the issuance of letters of credit. Subject to certain conditions, including approval by the lenders, we are able to increase the aggregate commitments under the Credit Facility by up to an additional $250.0 million. The Credit Facility borrowing base consists of eligible accounts receivable, inventory and compressors.
Covenants. Our Credit Facility agreement requires that we meet certain financial ratios (see Note 15 (“Long-Term Debt”) and contains various additional covenants including, but not limited to, mandatory prepayments from the net cash proceeds of certain asset transfers, restrictions on the use of proceeds from borrowings and limitations on our ability to incur additional indebtedness, engage in transactions with affiliates, merge or consolidate, sell assets, make certain investments and acquisitions, make loans, grant liens, repurchase equity and pay distributions. As of December 31, 2023, we were in compliance with all covenants under our Credit Facility agreement. Additionally, all undrawn capacity on our Credit Facility was available for borrowings as of December 31, 2023.
Senior Notes
As of both December 31, 2023 and 2022, we had a principal balance of $1.3 billion of outstanding senior notes that consisted of the following:
• $800.0 million of 6.25% senior notes due in April 2028 and
• $500.0 million of 6.875% senior notes due in April 2027.
See Note 15 (Long-term Debt”) to our Financial Statements for further details of these notes.
At-the-Market Continuous Equity Offering Program
Under our ATM Agreement, we may sell, from time to time, shares of our common stock having an aggregate offering price of up to $50.0 million. The agreement terminates upon the earlier of (i) the sale of all shares of common stock subject to the agreement or (ii) the termination of the agreement by us or by each of the sales agents. Any sales agent may also terminate the agreement but only with respect to itself. We used the net proceeds of these offerings for general corporate purposes. During the year ended December 2022, we sold 447,020 shares of common stock, respectively, for net proceeds of $4.2 million, pursuant to the ATM Agreement. There were no shares of common stock sold during the year ended December 31, 2023.
Other Sources of Cash
Business Dispositions and Other Asset Sales. We received proceeds of $72.2 million and $120.3 million from business dispositions and other asset sales during the years ended December 31, 2023 and 2022, respectively. We typically use the proceeds from these sales to repay borrowings outstanding under our Credit Facility, however, we are not able to estimate the timing of asset sales nor the amount of proceeds to be received and as such, we do not rely on asset sale proceeds as a future source of capital.
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Cash Flows
Cash flows provided by (used in) each type of activity were as follows:
Year Ended December 31,
(in thousands)
Net cash provided by (used in):
Operating activities
$
310,187
$
203,450
Investing activities
(232,491)
(130,916)
Financing activities
(77,924)
(72,537)
Net decrease in cash and cash equivalents
$
(228)
$
(3)
Operating Activities.
The increase in net cash provided by operating activities was primarily due to increased cash inflows of $115.2 million from gross margin and changes of $15.4 million in deferred revenue, partially offset by changes of $24.3 million in contract costs, $12.2 million in accounts payable and other liabilities and decreased cash inflows of $9.1 million from accounts receivable.
Investing Activities.
The increase in net cash used in investing activities was primarily due to a $58.8 million increase in capital expenditures and a $99.6 million decrease in proceeds from the sale of business, partially offset by a $51.6 million increase in proceeds from sales of property, plant and equipment and a $7.4 million decrease in investments in non-consolidated affiliates.
Financing Activities.
The increase in net cash used in financing activities was primarily due to $8.9 million of common stock purchased under the 2023 Share Repurchase Program, a $6.0 million payment for debt issuance costs related to the Amended and Restated Credit Agreement, a $5.5 million increase in dividends paid to stockholders and a $4.2 million decrease in proceeds from the sale of shares under the ATM Agreement, partially offset by a $19.0 million increase in net borrowings of long-term debt.
Critical Accounting Estimates
We describe our significant accounting policies more fully in Note 2 (“Basis of Presentation and Significant Accounting Policies”) to our Financial Statements. As disclosed in Note 2, the preparation of financial statements in conformity with GAAP requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, expenses and related disclosures of contingent assets and liabilities. We evaluate our estimates and accounting policies on an ongoing basis and base our estimates on historical experience and other assumptions that we believe are reasonable under the circumstances. The results of this process form the basis of our judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions and these differences can be material to our financial condition, results of operations and cash flows.
Depreciation
Property, plant and equipment, net, at December 31, 2023 was $2.3 billion and depreciation expense was $159.3 million for the year ended December 31, 2023. Property, plant and equipment are carried at cost and depreciated using the straight-line basis over the estimated useful life of the asset.
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Our estimate of useful lives and salvage values are based on assumptions and judgments that reflect both historical experience and expectations regarding future use of our assets, including wear and tear, obsolescence, technical standards, market demand and geographic location. The use of different assumptions and judgments in the calculation of depreciation, especially those involving useful lives, would likely result in significantly different net book values and results of operations.
The estimated useful life of an asset is monitored to determine its appropriateness, especially when business circumstances change. For example, changes in technology, excessive wear and tear, or unanticipated government actions may result in a shorter estimated useful life than originally anticipated. In these cases, we would depreciate the remaining net book value over the new estimated remaining life, thereby increasing depreciation expense per year on a prospective basis. Likewise, if the estimated useful life is increased, the adjustment to the useful life would decrease depreciation expense per year on a prospective basis.
Impairment of Assets
During the year ended December 31, 2023, we recorded long-lived and other asset impairments of $12.0 million.
Impairment Assessments of Property, Plant and Equipment and Identifiable Intangible Assets
We review long-lived assets, which include property, plant and equipment and intangibles assets that are being amortized, for impairment whenever events or changes in circumstances, including the removal of compressors from our active fleet, indicate that the carrying amount of an asset may not be recoverable. An impairment loss may exist when the estimated undiscounted cash flows expected from the use of the asset and its eventual disposition are less than its carrying amount. Determining whether the carrying amount of an asset is recoverable requires us to make judgments regarding long-term forecasts of future revenue and costs related to the asset subject to review. These forecasts are uncertain as they require significant assumptions about future market conditions. Significant and unanticipated changes to these assumptions could require a provision for impairment in a future period. Given the nature of these evaluations and their application to specific assets and specific times, it is not possible to reasonably quantify the impact of changes in these assumptions.
Compression Fleet. The fair value of a compressor is estimated on the expected net sale proceeds compared to fleet units we recently sold, a review of other units recently offered for sale by third parties or the estimated component value of the equipment we plan to use. See Note 21 (“Long-Lived and Other Asset Impairment”) and Note 26 (“Fair Value Measurements”) to our Financial Statements for further details of our fleet asset impairments.
Income Taxes
Our income tax expense, deferred tax assets and liabilities and reserves for unrecognized tax benefits reflect management’s best assessment of estimated current and future taxes to be paid. We operate in the U.S. and have investments in unconsolidated affiliates that operate in the U.S. and international locations. Significant judgments and estimates are required in determining consolidated income tax expense.
Deferred income taxes arise from temporary differences between the financial statements and the tax basis of assets and liabilities. In evaluating our ability to recover our deferred tax assets, we consider all available positive and negative evidence including scheduled reversals of deferred tax liabilities, projected future taxable income, tax-planning strategies and results of recent operations. In projecting future taxable income, we begin with historical results adjusted for results of discontinued operations and changes in accounting policies and incorporate assumptions, including the amount of future U.S. federal, state, and international pretax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax-planning strategies. These assumptions require significant judgment about the forecasts of future taxable income and are consistent with the plans and estimates we use to manage the underlying businesses. In evaluating the objective evidence that historical results provide, we consider three years of cumulative income (loss) before income taxes.
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Changes in tax laws and rates could also affect recorded deferred tax assets and liabilities in the future. Management is not aware of any such changes that would have a material effect on our financial position, results of operations or cash flows. The calculation of our tax liabilities involves dealing with uncertainties in the application of complex tax laws and regulations in various state and local jurisdictions.
The accounting standards for income taxes provide that a tax benefit from an uncertain tax position may be recognized when it is more likely than not that the position will be sustained upon examination, including resolutions of any related appeals or litigation processes, on the basis of the technical merits. We adjust these liabilities when our judgment changes as a result of the evaluation of new information not previously available. Because of the complexity of some of these uncertainties, the ultimate resolution may result in a payment that is materially different from our current estimate of the liabilities. Such differences are reflected as increases or decreases to income tax expense in the period in which the new information becomes available.
Recent Accounting Developments
See Note 3 (“Recent Accounting Developments”) to our Financial Statements.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
We are exposed to market risk associated with changes in the variable interest rate of our Credit Facility. We had previously used derivative instruments to manage our exposure to fluctuations in this variable interest rate; however, our interest rate swaps matured in March 2022, and all borrowings under the Credit Facility are now subject to variable interest rates.
A 1% increase in the effective interest rate on the outstanding balance under our Credit Facility at December 31, 2023 would have resulted in an annual increase in our interest expense of $2.9 million.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data
The information specified by this Item is presented in Part IV, Item 15 of this 2023 Form 10-K.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
None.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures
Management’s Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this 2023 Form 10-K, our principal executive officer and principal financial officer evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) of the Exchange Act), which are designed to provide reasonable assurance that we are able to record, process, summarize and report the information required to be disclosed in our reports under the Exchange Act within the time periods specified in the rules and forms of the SEC. Based on the evaluation, as of December 31, 2023, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective to provide reasonable assurance that the information required to be disclosed in reports that we file or submit under the Exchange Act is accumulated and communicated to management, and made known to our principal executive officer and principal financial officer, on a timely basis to ensure that it is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.
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Management’s Annual Report on Internal Control Over Financial Reporting
As required by Exchange Act Rules 13a-15(c) and 15d-15(c), our management, including the Chief Executive Officer and Chief Financial Officer, is responsible for establishing and maintaining adequate internal control over financial reporting. Management conducted an evaluation of the effectiveness of internal control over financial reporting based on the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness as 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. Based on the results of management’s evaluation described above, management concluded that our internal control over financial reporting was effective as of December 31, 2023.
The effectiveness of internal control over financial reporting as of December 31, 2023 was audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in its report found within this 2023 Form 10-K.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) during the last fiscal quarter that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the shareholders and the Board of Directors of Archrock, Inc.
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of Archrock, Inc. and subsidiaries (the “Company”) as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2023, of the Company and our report dated February 21, 2024, expressed an unqualified opinion on those financial statements.
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, included in the accompanying Management’s Annual 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 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 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, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and 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 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/ DELOITTE & TOUCHE LLP
Houston, Texas
February 21, 2024
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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information
Insider Trading Arrangements
During the three months ended December 31, 2023, none of our directors or officers adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers and Corporate Governance
The information required by Part III Item 10 of this 2023 Form 10-K is incorporated by reference to the sections entitled “Election of Directors,” “Governance” and “Stock Ownership” in the definitive proxy statement related to our 2024 Annual Meeting of Stockholders, which is to be filed with the SEC within 120 days following the end of our 2023 fiscal year.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation
The information required by Part III Item 11 of this 2023 Form 10-K is incorporated by reference to the sections entitled “Governance” and “Compensation Discussion and Analysis” in the definitive proxy statement related to our 2024 Annual Meeting of Stockholders, which is to be filed with the SEC within 120 days following the end of our 2023 fiscal year.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Portions of the information required in Part III Item 12 of this 2023 Form 10-K are incorporated by reference to the section entitled “Stock Ownership” in the definitive proxy statement related to our 2024 Annual Meeting of Stockholders, which is to be filed with the SEC within 120 days following the end of our 2023 fiscal year.
Securities Authorized for Issuance under Equity Compensation Plans
The following table sets forth information as of December 31, 2023, with respect to our compensation plans under which our common stock is authorized for issuance, aggregated as follows:
Number of Securities
to be Issued Upon
Weighted Average
Number of Securities
Exercise of
Exercise Price of
Remaining Available for
Outstanding Options,
Outstanding Options,
Future Issuance Under
Warrants and Rights
Warrants and Rights
Equity Compensation Plans
(a)
(b)
(c)
Equity compensation plans approved by security holders (1)
548,262
(2)
$
-
(3)
4,841,098
Equity compensation plans not approved by security holders (4)
-
-
37,771
Total
548,262
-
4,878,869
(1) Comprised of the 2013 Plan, the 2020 Plan and the ESPP.
(2) Comprised of unvested performance-based restricted stock units payable in common stock upon vesting at target performance.
(3) Performance-based restricted stock units do not have an exercise price.
(4) Comprised of our DSDP. See Note 19 (“Stock-Based Compensation”) to our Financial Statements for further details of our DSDP.
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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions and Director Independence
The information required by Part III Item 13 of this 2023 Form 10-K is incorporated by reference to the section entitled “Governance” in the definitive proxy statement related to our 2024 Annual Meeting of Stockholders, which is to be filed with the SEC within 120 days following the end of our 2023 fiscal year.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accountant Fees and Services
The information required by Part III Item 14 of this 2023 Form 10-K is incorporated by reference to the section entitled “Ratification of the Appointment of the Independent Registered Public Accounting Firm” in the definitive proxy statement related to our 2024 Annual Meeting of Stockholders, which is to be filed with the SEC within 120 days following the end of our 2023 fiscal year.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits and Financial Statement Schedules
(a)
List of Documents filed as a part of this 2023 Form 10-K
1.
Financial Statements. The following financial statements are filed as a part of this 2023 Form 10-K.
Report of Independent Registered Public Accounting Firm (PCAOB ID 34)
Consolidated Balance Sheets
Consolidated Statements of Operations
Consolidated Statements of Comprehensive Income
Consolidated Statements of Equity
Consolidated Statements of Cash Flows
Notes to Consolidated Financial Statements
2.Financial Statement Schedules
All financial statement schedules are omitted because they are not applicable or the information is set forth in the consolidated financial statements or notes thereto within Item 8 “Financial Statements and Supplementary Data.”
3.Exhibits
Exhibit No.
Description
2.1
Separation and Distribution Agreement, dated as of November 3, 2015, by and among Exterran Holdings, Inc., Exterran General Holdings LLC, Exterran Energy Solutions, L.P., Exterran Corporation, AROC Corp., EESLP LP LLC, AROC Services GP LLC, AROC Services LP LLC and Archrock Services, L.P., incorporated by reference to Exhibit 2.1 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
2.2
Amendment No. 1 to Separation and Distribution Agreement, dated as of December 15, 2015, by and among Archrock, Inc., formerly named Exterran Holdings, Inc., Exterran General Holdings LLC, Exterran Energy Solutions, L.P., Exterran Corporation, AROC Corp., EESLP LP LLC, AROC Services GP LLC, AROC Services LP LLC and Archrock Services, L.P., incorporated by reference to Exhibit 2.3 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2015
2.3
Agreement and Plan of Merger, dated as of January 1, 2018, by and among Archrock, Inc., Archrock GP LLC, Archrock General Partner, L.P. and Archrock Partners, L.P., incorporated by reference to Exhibit 2.1 to the Registrant’s Current Report on Form 8-K filed on January 2, 2018
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Exhibit No.
Description
2.4
Amendment No. 1 to Agreement and Plan of Merger, dated as of January 11, 2018, by and among Archrock, Inc., Archrock GP LLC, Archrock General Partner, L.P., Archrock Partners, L.P. and Amethyst Merger Sub LLC, incorporated by reference to Exhibit 2.2 to the Registrant’s Current Report on Form 8-K filed on January 16, 2018
3.1
Composite Restated Certificate of Incorporation of Archrock, Inc., incorporated by reference to Exhibit 3.3 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2015
3.2
Fourth Amended and Restated Bylaws of Archrock, Inc. (incorporated by reference to Exhibit 3.1 of Archrock Inc.’s Current Report on Form 8-K filed on July 28, 2023)
4.1
Indenture, dated as of March 21, 2019, by and among Archrock Partners, L.P., Archrock Partners Finance Corp., the guarantors party thereto and Wells Fargo Bank, National Association, as trustee, incorporated by reference to Exhibit 4.1 of the Registrant’s Current Report on Form 8-K filed on March 21, 2019
4.2
Indenture, dated as of December 20, 2019, by and among Archrock Partners, L.P., Archrock Partners Finance Corp., the guarantors party thereto and Wells Fargo Bank, National Association, as trustee, incorporated by reference to Exhibit 4.1 of the Registrant’s Current Report on Form 8-K filed on December 20, 2019
4.3
Description of Common Stock
10.1†
Exterran (now Archrock, Inc.) Employees’ Supplemental Savings Plan, incorporated by reference to Exhibit 10.30 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2007
10.2†
Summary of Donna A. Henderson Compensation Arrangement, incorporated by reference to Exhibit 10.50 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2015
10.3†
Summary of Jason Ingersoll Compensation Arrangement, incorporated by reference to Exhibit 10.51 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2015
10.4†
Form of Compensation Letter applicable to Mr. Childers, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on August 4, 2016.
10.5†
Form of Indemnification Agreement, incorporated by reference to Exhibit 10.7 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
10.6†
Exterran Holdings, Inc. (now Archrock, Inc.) Directors’ Stock and Deferral Plan, incorporated by reference to Exhibit 10.16 of the Registrant’s Current Report on Form 8-K filed on August 23, 2007
10.7†
First Amendment to Exterran Holdings, Inc. (now Archrock, Inc.) Directors’ Stock and Deferral Plan, incorporated by reference to Exhibit 10.22 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2008
10.8†
Second Amendment to Exterran Holdings, Inc. (now Archrock, Inc.) Directors’ Stock and Deferral Plan, incorporated by reference to Exhibit 10.16 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
10.9†
Form of Employment Letter applicable to Messrs. Childers and Ingersoll, incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
10.10†
Form of Severance Benefit Agreement applicable to Messrs. Childers and Ingersoll, incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
10.11†
Form of Change of Control Agreement applicable to Messrs. Childers and Ingersoll, incorporated by reference to Exhibit 10.10 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
10.12†
Archrock, Inc. 2017 Employee Stock Purchase Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A filed March 16, 2017
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Exhibit No.
Description
10.13†
Form of Amendment to Severance Benefit Agreement incorporated by reference to Exhibit 10.3 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2017
10.14†
Form of Second Amendment to Severance Benefit Agreement, incorporated by reference to Exhibit 10.73 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2017
10.15
Pledge and Security Agreement, dated as of March 30, 2017, among Archrock Partners Operating LLC and the other Grantors party thereto in favor or JPMorgan Chase Bank, N.A., as Administrative Agent, incorporated by reference to Exhibit 10.2 to Archrock Partners, L.P.’s Current Report on Form 8-K filed on April 5, 2017.
10.16
Omnibus Joinder Agreement, dated as of April 26, 2018, by and among Archrock, Inc., Archrock Services, L.P., AROC Corp., AROC Services GP LLC, AROC Services LP LLC, Archrock Services Leasing LLC, Archrock GP LP LLC, and Archrock MLP LP LLC and acknowledged and accepted by JPMorgan Chase Bank, N.A., as the Administrative Agent, incorporated by reference to Exhibit 10.3 of the Registrant’s Current Report on Form 8-K filed on April 26, 2018
10.17
Amendment and Supplement to Pledge and Security Agreement dated as of April 26, 2018, by and among Archrock Partners Operating LLC, Archrock Partners, L.P., Archrock Partners Finance Corp., Archrock Partners Leasing LLC, Archrock, Inc., Archrock Services, L.P., AROC Corp., AROC Services GP LLC, AROC Services LP LLC, Archrock Services Leasing LLC, Archrock GP LP LLC, Archrock MLP LP LLC and JPMorgan Chase Bank, N.A., as the Administrative Agent, incorporated by reference to Exhibit 10.4 of the Registrant’s Current Report on Form 8-K filed on April 26, 2018
10.18†
Form of Employment Letter applicable to Mr. Douglas S. Aron, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on July 12, 2018
10.19†
Form of Change of Control Agreement applicable to Mr. Douglas S. Aron, incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on July 12, 2018
10.20†
Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock, incorporated by reference to Exhibit 10.85 to the Registrant’s Annual Report on Form 10-K filed on February 20, 2019
10.21†
Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Cash-Settled), incorporated by reference to Exhibit 10.87 to the Registrant’s Annual Report on Form 10-K filed on February 20, 2019
10.22†
Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Stock-Settled), incorporated by reference to Exhibit 10.88 to the Registrant’s Annual Report on Form 10-K filed on February 20, 2019
10.23
Purchase Agreement, dated as of March 7, 2019, by and among Archrock Partners, L.P., Archrock Partners Finance Corp., Archrock, Inc., the other guarantors party thereto and J.P. Morgan Securities LLC, as representative of the initial purchasers named therein, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 8, 2019
10.24
Omnibus Joinder Agreement, dated as of March 21, 2019, by and among Archrock GP LLC, Archrock Partners Corp., Archrock General Partner, L.P. and JPMorgan Chase Bank, N.A., incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 21, 2019
10.25
Purchase Agreement, dated as of December 16, 2019, by and among Archrock Partners, L.P., Archrock Partners Finance Corp., Archrock, Inc., the other guarantors party thereto and RBC Capital Markets, LLC, as representative of the initial purchasers named therein, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on December 17, 2019
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Exhibit No.
Description
10.26†
Form of Compensation Letter applicable to Messrs. Childers, Aron, Ingersoll and Thode and Mme. Hildebrandt, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on April 30, 2020
10.27
Purchase Agreement, dated as of December 14, 2020, by and among Archrock Partners, L.P., Archrock Partners Finance Corp., Archrock, Inc., the other guarantors party thereto and RBC Capital Markets, LLC, as representative of the initial purchasers named therein, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on December 15, 2020
10.28†
Archrock Deferred Compensation Plan, dated as of October 28, 2021, incorporated by reference to Exhibit 10.41 to Registrant’s Annual Report on Form 10-K filed on February 22, 2023
10.29†
Archrock, Inc. 2020 Stock Incentive Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 17, 2020
10.30†
Form of Letter Agreement, incorporated by reference to Exhibit 10.99 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.31†
Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock, incorporated by reference to Exhibit 10.100 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.32†
Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock for Non-Employee Directors, incorporated by reference to Exhibit 10.101 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.33†
Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock Units for Non-Employee Directors, incorporated by reference to Exhibit 10.102 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.34†
Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Cash-Settled) , incorporated by reference to Exhibit 10.103 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.35†
Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Stock-Settled) , incorporated by reference to Exhibit 10.104 of the Registrant’s Annual Report on Form 10-K filed on February 23, 2022
10.36†
Form of Compensation Letter (incorporated by reference and filed as Exhibit 10.1 to Form 8-K filed on April 30, 2020), incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on June 21, 2021
10.37
Amended and Restated Credit Agreement, dated as of May 16, 2023, by and among Archrock, Inc., Archrock Partners Operating LLC, Archrock Services, L.P., the other Loan Parties thereto, the Lenders thereto, and JPMorgan Chase Bank, N.A., as the Administrative Agent, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on May 18, 2023
10.38
Retention Incentive Agreement, dated January 25, 2024, by and between Archrock, Inc. and D. Bradley Childers, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on January 26, 2024
10.39
Fourth Amended and Restated Omnibus Agreement, dated November 3, 2015, by and among Archrock, Inc. (formerly named Exterran Holdings, Inc.), Archrock Services, L.P. (formerly named Exterran US Services OpCo, L.P.), Archrock GP LLC (formerly named Exterran GP, LLC), Archrock General Partner, L.P. (formerly named Exterran General Partner, L.P.), Archrock Partners, L. P. (formerly named Exterran Partners, L.P.) and Archrock Partners Operating LLC, incorporated by reference to Exhibit 10.16 to the Registrant’s Annual Report on Form 10-K filed on February 29, 2016 (portions of this exhibit have been omitted by redacting a portion of the text (indicated by asterisks in the text) and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment)
Table Archrock, Contents
Exhibit No.
Description
10.40
First Amendment to Fourth Amended and Restated Omnibus Agreement, dated November 19, 2016, by and among Archrock, Inc., Archrock Services, L.P., Archrock GP LLC, Archrock General Partner, L.P., Archrock Partners, L.P., and Archrock Partners Operating LLC incorporated by reference to the Registrant’s Current Report on Form 8-K filed on November 23, 2016 (portions of this exhibit have been omitted by redacting a portion of the text (indicated by asterisks in the text) and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment)
10.41
Tax Matters Agreement, dated as of November 3, 2015, by and between Exterran Holdings, Inc. (now Archrock, Inc.) and Exterran Corporation, incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015
21.1*
List of Subsidiaries of Archrock, Inc.
23.1*
Consent of Deloitte & Touche LLP
31.1*
Certification of the Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2*
Certification of the Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1**
Certification of the Chief Executive Officer pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2**
Certification of the Chief Financial Officer pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
97.1*
Archrock’s Compensation Recovery Policy, dated effective October 2, 2023
101.1*
Interactive data files pursuant to Rule 405 of Regulation S-T
104.1*
Cover page interactive data files pursuant to Rule 406 of Regulation S-T
†
Management contract or compensatory plan or arrangement.
*
Filed herewith.
**
Furnished, not filed.
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