AroCell
Annual Report 2021

Plain-text annual report

2 0 2 1 A N N U A L R E P O R T AROC_2021_ANNUAL.indd 2 AROC_2021_ANNUAL.indd 2 3/9/22 1:37 PM 3/9/22 1:37 PM FINANCIAL HIGHLIGHTS (Dollars in thousands, except per share amounts) Revenue: Contract operations Aftermarket services Total revenue Gross margin(1): Contract operations Aftermarket services Total gross margin Gross margin percentage: Contract operations Aftermarket services Adjusted EBITDA (2) Total assets Long-term debt Total equity Net income (loss) Net income (loss) per common share Dividends declared and paid per common share Year ended December 31, 2021 2020 2019 $648,311 133,150 $781,461 $738,918 136,052 $874,970 $771,539 193,946 $965,485 $403,825 18,719 $422,544 $477,831 19,946 $497,777 $474,279 34,968 $509,247 62% 14% 65% 15% 61% 18% $360,809 $414,770 $416,505 $2,589,966 1,530,825 891,438 $28,217 0.18 $0.580 $2,779,722 1,688,867 935,557 $(68,445) (0.46) $0.580 $3,109,975 1,842,549 1,085,963 $97,330 0.70 $0.554 (1) See “Non-GAAP Financial Measures” in Part II Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of our accompanying 2021 Form 10-K for information on gross margin. (2) See “Reconciliation of Net Income (Loss) to Adjusted EBITDA” below. RECONCILIATION OF NET INCOME (LOSS) TO ADJUSTED EBITDA (In thousands) Net income (loss) Loss from discontinued operations, net of tax Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Restatement and other charges Restructuring charges Interest expense Debt extinguishment loss Transaction-related costs Stock-based compensation expense Indemnification (income) expense, net Provision for (benefit from) income taxes Adjusted EBITDA(1) Year ended December 31, 2021 $28,217 - 178,946 21,397 - - 2,903 108,135 - - 11,336 (869) 10,744 $360,809 2020 $(68,445) - 193,138 79,556 99,830 - 8,450 105,716 3,971 - 10,551 (460) (17,537) $414,770 2019 $97,330 273 188,084 44,663 - 445 - 104,681 3,653 8,213 8,105 203 (39,145) $416,505 (1) Adjusted EBITDA, a non-GAAP measure, is defined as net income (loss) excluding loss from discontinued operations, net of tax, interest expense, income taxes, depreciation and amortization, long-lived and other asset impairment, goodwill impairment, restatement and other charges, restructuring charges, debt extinguishment loss, transaction-related costs, non-cash stock- based compensation expense, indemnification (income) expense, net and other items. AROC_2021_ANNUAL.indd 3 AROC_2021_ANNUAL.indd 3 3/9/22 1:37 PM 3/9/22 1:37 PM UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549 Form 10-K (MARK ONE) (cid:1409) ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended December 31, 2021 or (cid:1407) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to Commission file no. 001-33666 Archrock, Inc. (Exact name of registrant as specified in its charter) (State or other jurisdiction of incorporation or organization) (I.R.S. Employer Identification No.) Delaware 74-3204509 9807 Katy Freeway, Suite 100, Houston, Texas 77024 (Address of principal executive offices, zip code) (281) 836-8000 (Registrant’s telephone number, including area code) Securities registered pursuant to Section 12(b) of the Act: Title of each class Common Stock, $0.01 par value per share Trading Symbol AROC Name of exchange on which registered New York Stock Exchange Securities registered pursuant to 12(g) of the Act: None Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes (cid:1409) No (cid:1407) Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes (cid:1407) No (cid:1409) Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes (cid:1409) No (cid:1407) Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes (cid:1409) No (cid:1407) Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. (cid:1409) Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. Large accelerated filer Non-accelerated filer (cid:1409) (cid:1407) Accelerated filer Smaller reporting company Emerging growth company (cid:1407) (cid:1407) (cid:1407) If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. (cid:134) Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. (cid:1409) Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes (cid:1407) No (cid:1409)(cid:3) Aggregate market value of the common stock of the registrant held by non-affiliates as of June 30, 2021: $1,191,894,665. Number of shares of the common stock of the registrant outstanding as of February 16, 2022: 155,231,118 shares. DOCUMENTS INCORPORATED BY REFERENCE Portions of the registrant’s definitive proxy statement for the 2021 Meeting of Stockholders, which is expected to be filed with the Securities and Exchange Commission within 120 days after December 31, 2021, are incorporated by reference into Part III of this Form 10-K. TABLE OF CONTENTS Page 3 5 6 19 32 32 33 33 33 36 49 50 50 50 52 52 52 52 52 53 53 61 Glossary Forward-Looking Statements Part I Item 1. Business Item 1A. Risk Factors Item 1B. Unresolved Staff Comments Item 2. Properties Item 3. Legal Proceedings Item 4. Mine Safety Disclosures Part II Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations Item 7A. Quantitative and Qualitative Disclosures About Market Risk Item 8. Financial Statements and Supplementary Data Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure Item 9A. Controls and Procedures Item 9B. Other Information Part III Item 10. Directors, Executive Officers and Corporate Governance Item 11. Executive Compensation Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters Item 13. Certain Relationships and Related Transactions and Director Independence Item 14. Principal Accountant Fees and Services Part IV Item 15. Exhibits and Financial Statement Schedules Signatures 2 The following terms and abbreviations appearing in the text of this report have the meanings indicated below. GLOSSARY 2013 Plan 2020 Plan 2021 Form 10-K 2021 Notes 2022 Notes 2027 Notes 2028 Notes Amendment No. 2 Amendment No. 3 AMNAX AMZ Archrock, our, we, us ASU 2016-13 ASU 2020-04 ATM Agreement BBA Bcf/d BoLM CAA CARES Act CERCLA Code Congress COVID-19 Credit Facility CWA Debt Agreements DSDP EBITDA EIA Elite Acquisition Elite Compression EPA ERP ESG ESPP Exchange Act FASB FCA 2013 Stock Incentive Plan 2020 Stock Incentive Plan Annual Report on Form 10-K for the year ended December 31, 2021 $350.0 million of 6.00% senior notes due April 2021, issued in March 2013 $350.0 million of 6.00% senior notes due October 2022, issued in April 2014 $500.0 million of 6.875% senior notes due April 2027, issued in March 2019 $800.0 million of 6.25% senior notes due April 2028, $500.0 million of which was issued in December 2019, $300.0 million of which was issued in December 2020 Amendment No. 2 to Credit Agreement, dated November 8, 2019, which amended that Credit Agreement, dated as of March 30, 2017, which governs the Credit Facility Amendment No. 3 to Credit Agreement, dated February 22, 2021, which amended that Credit Agreement, dated as of March 30, 2017, which governs the Credit Facility Alerian Midstream Energy Index Alerian MLP Index Archrock, Inc., individually and together with its wholly-owned subsidiaries Accounting Standards Update No. 2016-13—Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments Accounting Standards Update No. 2020-04—Reference Rate Reform (Topic 848)— Facilitation of the Effects of Reference Rate Reform on Financial Reporting Equity Distribution Agreement, dated February 23, 2021, entered into with Wells Fargo Securities, LLC and BofA Securities, Inc., as sales agents, relating to the at-the-market offer and sale of shares of our common stock from time to time British Bankers’ Association Billion cubic feet per day U.S. Department of the Interior’s Bureau of Land Management Clean Air Act Coronavirus Aid, Relief, and Economic Security Act, Public Law No. 116-136, a tax stimulus and economic stabilization bill signed into law on March 27, 2020 Comprehensive Environmental Response, Compensation, and Liability Act Internal Revenue Code of 1986, as amended U.S. Congress Coronavirus disease 2019 $750.0 million asset-based revolving credit facility due November 2024, as governed by Amendment No. 3 Clean Water Act Credit Facility, 2027 Notes and 2028 Notes, collectively Directors’ Stock and Deferral Plan Earnings before interest, taxes, depreciation and amortization U.S. Energy Information Administration Transaction completed on August 1, 2019 pursuant to the Asset Purchase Agreement entered into with Elite Compression on June 23, 2019, whereby we acquired from Elite Compression substantially all of its assets and certain liabilities Elite Compression Services, LLC U.S. Environmental Protection Agency Enterprise Resource Planning Environmental, Social and Governance Employee Stock Purchase Plan Securities Exchange Act of 1934, as amended Financial Accounting Standards Board United Kingdom Financial Conduct Authority 3 February 2021 Disposition Financial Statements GAAP Harvest Harvest Sale Hilcorp IRS JDH Capital July 2021 Dispositions July 2020 Disposition LIBOR March 2020 Disposition MMb/d NAAQS NOL NSPS OSHA OTC Paris Agreement Partnership POTUS ppb RCRA ROU S&P 500 SEC SG&A Spin-off Sale completed in February 2021 of certain contract operations customer service agreements, compressors and other assets Consolidated financial statements included in Part IV Item 15 of this 2021 Form 10-K U.S. generally accepted accounting principles Harvest Four Corners, LLC Transaction completed on August 1, 2019 pursuant to the Asset Purchase Agreement entered into with Harvest on June 23, 2019 Hilcorp Energy Company Internal Revenue Service JDH Capital Holdings, L.P. Sales completed in July 2021 of certain contract operations customer service agreements, compressors and other assets Sale completed in July 2020 of the turbocharger business included within our aftermarket services segment London Interbank Offered Rate Sale completed in March 2020 of certain contract operations customer service agreements, compressors and other assets Million barrels per day National Ambient Air Quality Standards Net operating loss New Source Performance Standards Occupational Safety and Health Act Over-the-counter, as related to aftermarket services parts and components Resulting agreement of the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change held in Paris, France Archrock Partners, L.P., together with its subsidiaries President of the United States of America Parts per billion Resource Conservation and Recovery Act Right-of-use, as related to the lease model under Accounting Standards Codification Topic 842 Leases S&P 500 Composite Stock Price Index U.S. Securities and Exchange Commission Selling, general and administrative Spin-off completed in November 2015 of our international contract operations, international aftermarket services and global fabrication businesses into a standalone public company operating as Exterran Corporation U.S. VOC Working Group Williams Partners United States of America Volatile organic compounds Working Group on the Social Cost of Greenhouse Gases Williams Partners, L.P. 4 FORWARD-LOOKING STATEMENTS This 2021 Form 10-K contains “forward-looking statements” intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995. All statements other than statements of historical fact contained in this 2021 Form 10-K are forward-looking statements within the meaning of Section 21E of the Exchange Act, including, without limitation, statements regarding the effects of the COVID-19 pandemic on our business, operations, customers and financial condition; our business growth strategy and projected costs; future financial position; the sufficiency of available cash flows to fund continuing operations and pay dividends; the expected amount of our capital expenditures; anticipated cost savings; future revenue, gross margin and other financial or operational measures related to our business; the future value of our equipment; and plans and objectives of our management for our future operations. You can identify many of these statements by words such as “believe,” “expect,” “intend,” “project,” “anticipate,” “estimate,” “will continue” or similar words or the negative thereof. Such forward-looking statements are subject to various risks and uncertainties that could cause actual results to differ materially from those anticipated as of the date of this 2021 Form 10-K. Although we believe that the expectations reflected in these forward-looking statements are based on reasonable assumptions, no assurance can be given that these expectations will prove to be correct. Known material factors that could cause our actual results to differ materially from those in these forward-looking statements are described in Part I Item 1A “Risk Factors” and Part II Item 7 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this 2021 Form 10-K. All forward-looking statements included in this 2021 Form 10-K are based on information available to us on the date of this 2021 Form 10-K. Except as required by law, we undertake no obligation to publicly update or revise any forward- looking statement, whether as a result of new information, future events or otherwise. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements contained throughout this 2021 Form 10-K. 5 PART I 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 the parent entity of Universal Compression Holdings, Inc. and Hanover Compressor Company, named “Exterran Holdings, Inc.” 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 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. 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 77% of our operating fleet being used in the gathering and processing cycle stages. The remaining 23% 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. 6 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 natural gas and crude oil 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 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, 2021, 2020 and 2019, we generated 83%, 84% and 80%, respectively, of our total revenue from contract operations. 7 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 are also equipped with telematic devices that enable us to remotely monitor the units. We maintain field service locations from which our field technicians 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, minimize avoidable downtime and reduce the overall maintenance expenditures over the equipment life. As of December 31, 2021, 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, 2021: 0 — 1,000 horsepower per unit 1,001 — 1,500 horsepower per unit Over 1,500 horsepower per unit Total Aggregate Number Horsepower % of of Units 2,291 1,424 604 4,319 (in thousands) Horsepower 745 1,923 1,210 3,878 19 % 50 % 31 % 100 % 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 expected natural gas volumes and pressures associated with a specific application, and are required to pay a reduced monthly fee during periods of limited or disrupted natural gas flows, which enhances the stability and predictability of our cash flows. We are typically responsible for the costs and expenses associated with our compression equipment except for fuel gas, 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. 8 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, 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, 2021, 2020 and 2019, we generated 17%, 16% and 20%, respectively, of our total revenue from aftermarket services. Competitive Strengths We believe we have the following key competitive strengths: Large horsepower. We have the largest fleet of large horsepower equipment among all outsourced compression service providers in the U.S. As of December 31, 2021, 80% 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 is 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. We guarantee our customers 98% availability in all of our contract operations service agreements, and during the year ended December 31, 2021, our availability was 99.3%. Our sales efforts concentrate on demonstrating our commitment to enhancing our customers’ cash flows through superior customer service and after-market support. 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 2021 total recordable incident rate of 0.10. 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 400 customers operating throughout all major U.S. natural gas and crude oil producing regions. 9 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 three years. We believe this fee structure and the longevity of our operations reduces volatility and enhances the stability and predictability of our cash flows. Diversified geographic footprint. We operate in substantially all major natural gas and crude oil producing regions in the U.S. 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 Transformation. As of the end of 2021, we had completed several major phases of a process and technology transformation project that enables us to harness technology in all aspects of our business to drive operational efficiencies and enhance our value proposition to our customers. Our investments have focused on the automation of workflows, integration of digital and mobile tools for our field service technicians and expanded remote monitoring capabilities of our vehicle and compressor fleets. We expect this project to, among other things, 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 natural gas and crude oil production, decreasing natural reservoir pressures 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. 10 Improve profitability. We are focused on increasing productivity and optimizing our processes. As of the end of 2021, we had completed several major phases of 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. By using technology to make our systems and processes more efficient, we intend to lower our internal costs and improve our profitability over time. Implementing telematics and advanced data analysis across our fleet will enable 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 also reduce vehicle miles traveled and fuel consumption, thereby also reducing emissions. In addition, we continue to focus on increasing the percentage of large horsepower equipment within our fleet 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 147,000 and 74,000 non-core horsepower during the years ended December 31, 2021 and 2020, respectively, which drove an increase in our large operating horsepower from 74% of our fleet as of year end 2019, to 80% as of December 31, 2021. 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 natural gas and crude oil 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 three 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. Market, Suppliers and Customers We conduct our contract operations activities in substantially all major natural gas and crude oil producing areas throughout the U.S. 11 We have pricing agreements in place with all of our primary suppliers of compression equipment, parts and services, including Ariel, Waukesha and Caterpillar and its distributors, 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. Our customer base consists primarily of companies engaged in all aspects of the oil and gas industry, including large integrated and independent natural gas and crude oil producers, 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, 2021, 2020 and 2019, our five most significant customers collectively accounted for 31%, 28% and 25%, 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, 2021, 2020 and 2019. Sales and Marketing Our marketing and client service functions are coordinated and performed by our sales and field service personnel. Sales and field service personnel 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. 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. 12 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. While the EPA in 2020 adopted deregulatory amendments to the 2016 rule that removed the transmission and storage segments from the oil and natural gas source category and rescinded the methane-specific requirements for production and processing facilities, that 2020 rulemaking was voided by action of Congress and the President effective June 30, 2021. As a result, the 2016 rules became effective again immediately. Further, in November 2021, the EPA proposed the framework for more stringent methane rules for newer sources, along with emissions standards that will for the first time be applicable to existing sources. The actual proposed rule language is expected to be published in early 2022, and a final rule likely in the second half of 2022, following a public notice and comment period. The current administration and the EPA have indicated that additional rule proposals on oil and gas-related methane emissions are in the works. 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 and that may be effective sooner than any new EPA rules. 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. Those decisions have been subject to judicial challenge. In October 2021, the EPA revealed in court filings that it will revisit the December 2020 decision to retain the existing ozone standard. 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 or of the possible reconsideration and issuance of new NAAQS standards. 13 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, 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 greenhouse gases, such as carbon dioxide and methane. Congress has previously considered legislation to restrict or regulate emissions of greenhouse gases. Energy legislation and other initiatives continue to be proposed that may be relevant to greenhouse gas emissions issues. Almost half of the states, either individually or through multi-state regional initiatives, have begun to address greenhouse gas emissions, primarily through the planned development of emission inventories or regional greenhouse gas cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of greenhouse gas emissions, such as electric power plants, it is possible that smaller sources such as our natural gas-powered compressors could become subject to greenhouse gas-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for greenhouse gas 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 proposals are also under consideration in Congress in early 2022 that reportedly could provide significant funding for research and development of low-carbon energy production methods, carbon capture, and other programs directed at addressing climate change. Independent of Congress, the EPA has promulgated regulations controlling greenhouse gas 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 greenhouse gas emissions. In 2021, 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 greenhouse gas emissions. The requirement for large sources of greenhouse gas 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 greenhouse gas, 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 greenhouse gas 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, with an updated cost figure expected early in 2022. That figure is intended to be used to guide federal decisions on the costs and benefits of various policies and approvals, although such efforts have been the subject of a series of judicial challenges. 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. 14 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 greenhouse gas 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. greenhouse gas 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. With the exception of those proposed EPA methane rules, which were announced by the POTUS at the United Nations Climate Change Conference in Glasgow in November 2021, we cannot predict whether re-entry into the Paris Agreement or pledges made in connection therewith 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 greenhouse gas or climate change legislation or regulation promulgated by Congress, the states or multi-state regions will impact our business, any regulation of greenhouse gas 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, 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. As a result of judicial and regulatory action, different approaches to the definitions adopted in 2015 and in 2020 by the EPA and the Army Corps of Engineers were stayed or vacated during 2021, with the effect of restoring to effectiveness rules and guidance from the mid-1980s. In the meantime, the current administration is developing new rules intended to provide a legally durable definition designed to clarify and stabilize the scope of the agencies’ jurisdiction. In January 2022, the U.S. Supreme Court agreed to take up the issue of the appropriate scope of CWA jurisdiction. 15 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 sub-contracted 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. On January 21, 2021, the POTUS issued an executive order on protecting worker health and safety, the stated goal of which is to protect the health and safety of workers from COVID-19. In the executive order, Department of Labor leaders and, in some cases, the leaders of other Federal Departments are called on to, among other things, issue revised guidance to employers on workplace safety during the pandemic, consider whether emergency temporary standards (e.g., mask in the workplace) are necessary, review OSHA enforcement efforts related to COVID-19, focus those enforcement efforts on violations that put the largest number of workers at serious risk or are contrary to anti-retaliation principles and coordinate with State and local government entities responsible for public employee safety. The widespread availability of COVID-19 vaccines and apparent improvements in health outcomes present important opportunities for the safe operation of our business. 16 On November 5, 2021, OSHA issued an Emergency Temporary Standard requiring most employers of over 100 employees to require workers to be vaccinated or to wear masks and be tested weekly. However, on January 13, 2022, the U.S. Supreme Court granted emergency relief staying the implementation of that OSHA standard pending further review in the lower courts. The current administration has announced that it will continue to urge employers to take steps to safeguard worker health and will use its existing authorities to hold businesses accountable for doing so. Additionally, there is the possibility that individual states may implement “vaccinate or test” requirements similar to the stayed OSHA standard. While we have robust measures in place that meet or exceed current applicable requirements with respect to the COVID-19 pandemic, at this time we do not know if or how any additional developments with the pandemic, or any regulatory initiatives adopted in response to it, will affect our operations. We will continue to monitor and act in accordance with applicable law and in the best interests of our employees and those with whom we interact. Human Capital As of December 31, 2021, we had approximately 1,100 employees and had a presence in 41 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 nine directors are gender or ethnically diverse. Similarly, one third of our executive leadership team is female and 40% of our total workforce is gender or ethnically diverse. We support gender and ethnic pay equity and believe we offer competitive and comprehensive compensation and benefits packages that include annual bonuses, stock awards, 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, family leave, an employee assistance program and tuition assistance, among many others. 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 Nominating and Corporate Governance 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. 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 15 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, that are designed to foster a mindset that integrates safety into every work process. Through this program, we have successfully lowered our total recordable incident rate from 0.54 in 2019, to 0.25 in 2020, and to 0.10 in 2021, and 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. 17 Response to COVID-19 Pandemic Beginning in 2020, we took swift action regarding employee well-being in response to the COVID-19 pandemic, establishing a multidisciplinary team, with representation from human resources, health safety and environment, facilities and information technology, to develop a pandemic response plan. We implemented comprehensive protocols to protect the health and safety of our employees, customers and communities, including contactless parts pickup for field employees and customers and mandated social distancing and additional personal protection equipment requirements in the field. We adopted remote work for office-based employees and all travel deemed non-essential was eliminated. Office occupancy in 2021 varied based on conditions in the local area. Since the start of the pandemic, we have provided increased signage, sanitizer, fresh air flow, personal protective equipment and frequent cleaning services at all office locations. 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 27,000 hours of operational and technical training during 2021. Every new hire field employee enters 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. 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 annual 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. Available Information Our website address is www.archrock.com. 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 on our website, without charge, as soon as reasonably practicable after they are filed electronically with the SEC. Information on our website is not incorporated by reference in this 2021 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. 18 Item 1A. Risk Factors As described in “Forward-Looking Statements,” this 2021 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 The COVID-19 pandemic may continue to negatively affect demand for our services, and may continue to have a material adverse impact on our financial condition, results of operations and cash flows. COVID-19 continues to impact public health, economic growth, supply chains and markets. While the magnitude and duration of potential social, economic and labor instability as a direct result of the COVID-19 pandemic cannot be estimated at this time, we continue to closely monitor the effects of the pandemic on commodity demands and on our customers, as well as on our operations and employees. These effects may include adverse revenue and net income effects, disruptions to our operations and supply chain, customer shutdowns of oil and gas exploration and production, employee impacts from illness, school closures and other community response measures, and temporary inaccessibility or closures of our facilities or the facilities of our customers and suppliers. The extent to which our operating and financial results continue to be affected by the COVID-19 pandemic will depend on various factors and consequences beyond our control, such as the duration and scope of the pandemic, additional actions by businesses and governments in response to the pandemic and the speed and effectiveness of responses to combat the virus. The COVID-19 pandemic 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. 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. 19 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. 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 per unit. 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. Following the closing of the Elite Acquisition, an affiliate of Hilcorp holds a significant portion of our common stock, and Hilcorp’s interest as an equity holder may conflict with the interests of our other shareholders or our noteholders. In connection with the closing of the Elite Acquisition, we issued 21.7 million shares of our common stock to JDH Capital, an affiliate of our customer Hilcorp. As long as JDH Capital, together with affiliates of Hilcorp, owns at least 7.5% of our outstanding common stock, it will have the right to designate one director to our Board of Directors. As of December 31, 2021, JDH Capital owned 11.1% of our outstanding common stock. Given its ownership level and board representation, JDH Capital may have some influence over our operations and strategic direction and may have interests that conflict with the interests of other equity and debt holders. While we paid quarterly dividends of $0.145 per share of common stock during the year ended December 31, 2021, there can be no assurance that we will pay dividends in the future. We paid quarterly cash dividends of $0.145 per share of common stock during the year ended December 31, 2021. 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 such surplus or 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; 20 • 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. 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. At December 31, 2021, we had $1.5 billion in outstanding debt obligations, net of unamortized debt premiums and unamortized deferred financing costs. 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 and associated commitments could have important adverse 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 our 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 or distributions, 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. 21 Our Credit Facility is also subject to financial covenants, including the following ratios, as defined in the corresponding agreement: EBITDA to Interest Expense Senior Secured Debt to EBITDA Total Debt to EBITDA Through fiscal year 2022 January 1, 2023 through September 30, 2023 Thereafter (1) 2.5 to 1.0 3.0 to 1.0 5.75 to 1.0 5.50 to 1.0 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 distributions. 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. 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, 2021, 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. 22 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. After taking into consideration interest rate swaps, we did not have any outstanding indebtedness that was subject to variable interest rates as of December 31, 2021. However, our interest rate swaps mature in the first quarter of 2022, at which time all borrowings under our Credit Facility will be 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. 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. On May 3, 2021, the FCA announced that certain U.S. dollar LIBOR rates, including the 1-month rate used to determine the amount of interest payable related to borrowings under our Credit Facility, will cease to be provided after June 30, 2023. In the U.S., efforts to identify a set of alternative U.S. dollar reference interest rates that could replace LIBOR include proposals by the Alternative Reference Rates Committee of the Federal Reserve Board and the Federal Reserve Bank of New York. Our Credit Facility agreement requires that we execute an amendment that establishes an alternate reference rate should the 1-month U.S. dollar LIBOR cease to be published, to be agreed upon by us and the lenders under the facility. The alternate reference rate selected may result in interest obligations which are more than or do not otherwise correlate over time with the payments that would have been made on any current or future debt obligations, including the Credit Facility, if U.S. dollar LIBOR was available in its current form. Replacement of the 1-month U.S. dollar LIBOR may, therefore, materially adversely affect 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. 23 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 31%, 28% and 25% of our revenue for the years ended December 31, 2021, 2020 and 2019, 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. 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. 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, 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. 24 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 resulting from the COVID-19 pandemic 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 the COVID-19 pandemic or otherwise, could have a negative impact on our business, results of operations, financial condition and cash flows. 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. In the fourth quarter of 2018, we began a process and technology transformation project, which has, among other things, replaced our existing ERP, supply chain and inventory management systems and expanded the remote monitoring capabilities of our compression fleet. By using technology to make our systems and processes more efficient, we intend 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 may be threatened by problems such as cyber-attacks, computer viruses or terrorism that 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 hacking, viruses, acts of war or terrorism and other causes. 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. 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. 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. 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. 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 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. 25 Our ability to use NOLs to offset future income may be limited. Our ability to use any NOLs 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. Due to the COVID-19 pandemic, the U.S. Federal Reserve has lowered the long-term tax-exempt rate. Market volatility due to reduced demand from the COVID-19 pandemic and oil oversupply and the related decrease in our equity value may cause increased interest in our common stock, which may result in an additional ownership change. Both of these changes could further limit our use of pre- ownership change NOLs if we experience an additional ownership change. Furthermore, the IRS has recently 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 may be limited. Such a limitation could, for any given year, have the effect of increasing the amount of our U.S. federal income tax liability, which would negatively impact the amount of after-tax cash available for distribution to our stockholders and our financial condition. We are subject to continuing contingent tax liabilities following the Spin-off. In connection with the Spin-off, we entered into a tax matters agreement with Exterran Corporation that allocates the responsibility for prior period taxes of the Exterran Holdings consolidated U.S. federal and state tax reporting group between us and Exterran Corporation. If Exterran Corporation is unable to pay any prior period taxes related to these consolidated U.S. federal and state tax filings for which it is responsible, we would be required to pay the entire amount of such taxes. Legal and Regulatory Risks 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” and Note 26 (“Commitments and Contingencies”) to our Financial Statements for additional information regarding certain legal proceedings to which we are a party. U.S. federal, state and local legislative and regulatory initiatives relating to hydraulic fracturing as well as governmental reviews of such activities could result in increased costs and additional operating restrictions or delays in the completion of oil and natural gas wells and adversely affect demand for our contract operations services. Hydraulic fracturing is an important and common practice that is used to stimulate production of natural gas and/or oil from dense subsurface rock formations. We do not perform hydraulic fracturing, but many of our customers do. Hydraulic fracturing involves the injection of water, sand or alternative proppant and chemicals under pressure into target geological formations to fracture the surrounding rock and stimulate production. Hydraulic fracturing is typically regulated by state agencies, but recently, there has been increased public concern regarding an alleged potential for hydraulic fracturing to adversely affect drinking water supplies, and proposals have been made to enact separate U.S. federal, state and local legislation that would increase the regulatory burden imposed on hydraulic fracturing. 26 On January 27, 2021, the POTUS issued an executive order directing the Secretary of the Interior to pause all new oil and natural gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices in light of potential climate and other impacts associated with oil and natural gas activities thereon. Some legal challenges to the suspension have been successful and the current administration has resumed leasing activities, although there are substantial indications that future leasing activities will involve more stringent environmental conditions. At the state level, several states have adopted or are considering legal requirements that could impose more stringent permitting, disclosure and well construction requirements on hydraulic fracturing activities. For example, in May 2013, the Texas Railroad Commission adopted new rules governing well casing, cementing and other standards for ensuring that hydraulic fracturing operations do not contaminate nearby water resources. Local governments may also seek to adopt ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or hydraulic fracturing activities in particular or prohibit the performance of well drilling in general or hydraulic fracturing in particular. While we cannot predict the ultimate outcome of such recent developments, if new or more stringent U.S. federal, state or local legal restrictions relating to the hydraulic fracturing process are adopted in areas where our natural gas exploration and production customers operate, those customers could incur potentially significant added costs to comply with such requirements, experience delays or curtailment in the pursuit of exploration, development or production activities and perhaps even be precluded from drilling wells. Any such restrictions could reduce demand for our contract operations services, and as a result could have a material adverse effect on our business, financial condition, results of operations and cash flows. 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. While the EPA in 2020 adopted deregulatory amendments to the 2016 rule that removed the transmission and storage segments from the oil and natural gas source category and rescinded the methane-specific requirements for production and processing facilities, that 2020 rulemaking was voided by action of Congress and the President effective June 30, 2021. As a result, the 2016 rules became effective again immediately. Further, in November 2021, the EPA proposed the framework for more stringent methane rules for newer sources, along with emissions standards that will for the first time be applicable to existing sources. The actual proposed rule language is expected to be published in early 2022, and a final rule likely in the second half of 2022, following a public notice and comment period. The current administration and the EPA have indicated that additional rule proposals on oil and gas-related methane emissions are in the works. 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 and that may be effective sooner than any new EPA rules. 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. 27 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. Those decisions have been subject to judicial challenge. In October 2021, the EPA revealed in court filings that it will revisit the December 2020 decision to retain the existing ozone standard. 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 or of the possible reconsideration and issuance of 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, could potentially give rise to material impacts in the future. 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, 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 land owners 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. Notably, the current administration has indicated an intention to expand environmental enforcement efforts, and that it plans to target for enhanced enforcement locations and violations that involve harm to minority and low-income communities that historically have faced disproportionate environmental burdens. 28 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. 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 natural gas, oil 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. 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. 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 greenhouse gases, such as carbon dioxide and methane. Congress has previously considered legislation to restrict or regulate emissions of greenhouse gases. Energy legislation and other initiatives continue to be proposed that may be relevant to greenhouse gas emissions issues. Almost half of the states, either individually or through multi-state regional initiatives, have begun to address greenhouse gas emissions, primarily through the planned development of emission inventories or regional greenhouse gas cap and trade programs. Although most of the state-level initiatives have to date been focused on large sources of greenhouse gas emissions, such as electric power plants, it is possible that smaller sources such as our natural gas-powered compressors could become subject to greenhouse gas-related regulation. Depending on the particular program, we could be required to control emissions or to purchase and surrender allowances for greenhouse gas 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 proposals are also under consideration in Congress in early 2022 that reportedly could provide significant funding for research and development of low-carbon energy production methods, carbon capture, and other programs directed at addressing climate change. 29 Independent of Congress, the EPA has promulgated regulations controlling greenhouse gas 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 greenhouse gas emissions. In 2021, 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 greenhouse gas emissions. The requirement for large sources of greenhouse gas 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 greenhouse gas, 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 greenhouse gas 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, with an updated cost figure expected early in 2022. That figure is intended to be used to guide federal decisions on the costs and benefits of various policies and approvals, although such efforts have been the subject of a series of judicial challenges. 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. 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 greenhouse gas 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. greenhouse gas 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. With the exception of those proposed EPA methane rules, which were announced by the POTUS at the United Nations Climate Change Conference in Glasgow in November 2021, we cannot predict whether re-entry into the Paris Agreement or pledges made in connection therewith 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 greenhouse gas or climate change legislation or regulation promulgated by Congress, the states or multi-state regions will impact our business, any regulation of greenhouse gas 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. 30 Apart from governmental regulation, there are also increasing financial risks for companies in the energy sector as shareholders and bondholders currently invested in energy companies may elect in the future to shift some or all of their investments toward non-fossil fuel energy sources. In recent years there have been increased efforts to encourage the consideration of ESG practices of companies in making investment decisions and, as a result, investment banks and asset managers based both domestically and internationally have announced that they are adopting climate change guidelines for their banking and investing activities. Institutional lenders who provide financing to energy companies such as ourselves have become more attentive to sustainable lending practices, and some may elect not to provide traditional energy producers or companies that support such producers with funding. ESG considerations may also affect others in the investment community, including investment advisers, sovereign wealth funds, public pension funds and other groups, and may result in their divestment of energy-related equities. Limitation of investments in and financings for energy companies could result in the restriction, delay or cancellation of infrastructure projects and energy production activities. This potential for reduced access to the capital and financial markets, whether impacting our customers and/or our company, may further adversely affect the demand for and price of our securities. Furthermore, at this time, there is significant uncertainty with respect to the extent to which climate change may lead to more extreme weather patterns, but it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere can change the climate in a manner that results in significant weather- related effects, such as increased frequency and severity of storms, droughts, floods and other such events. Energy needs could increase or decrease as a result of extreme weather conditions depending on the duration and magnitude of any such climate changes. Increased energy use due to weather changes may require us to invest in order to serve increased demand. A decrease in energy use due to weather changes may affect our financial condition through decreased revenues. To the extent the frequency of extreme weather events increases, this could increase our cost of providing service. If any of these results occur, it could have an adverse effect on our assets and operations and cause us to incur costs in preparing for and responding to them. 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 emissions of greenhouse gases 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 the company’s sales volumes, revenues and margins. 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. 31 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. Item 1B. Unresolved Staff Comments None. Item 2. Properties The following table describes the material facilities that we owned or leased at December 31, 2021: Status Square Feet Location Leased Houston, Texas Leased Brookwood, Alabama Leased Bakersfield, California Leased Greeley, Colorado Owned Broussard, Louisiana Owned Houma, Louisiana Leased Gaylord, Michigan Leased Carlsbad, New Mexico Owned Farmington, New Mexico Leased Oklahoma City, Oklahoma Owned Waynoka, Oklahoma Owned Yukon, Oklahoma Leased Tunkhannock, Pennsylvania West Alexander, Pennsylvania Leased Leased Asherton, Texas Leased Big Lake, Texas Owned Brenham, Texas Leased Bridgeport, Texas Leased Cotulla, Texas Leased Kenedy, Texas Leased Marshall, Texas Owned Midland, Texas Leased Pecos, Texas Owned Victoria, Texas Owned Victoria, Texas Leased Zapata, Texas Leased Evansville, Wyoming Leased Rock Springs, Wyoming 75,000 14,000 18,000 10,000 89,000 60,000 13,000 6,000 62,000 41,000 13,000 85,000 9,000 15,000 9,000 12,000 10,000 12,000 10,000 11,000 11,000 51,000 10,000 23,000 66,000 24,000 15,000 9,000 Use by Segment Corporate office — Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Aftermarket Services Contract Operations and Aftermarket Services Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services Contract Operations and Aftermarket Services 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. 32 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. Item 4. Mine Safety Disclosures Not applicable. PART II 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 16, 2022, the closing price of our common stock was $8.57 per share. 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, 2016. 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. In 2021, we added the AMZ index to the performance graph. We are an energy infrastructure company in the midstream space that derives our cash flows from fee-based contract operations services. Similarly, the AMZ includes several small and mid-cap midstream companies that derive their cash flows from fee-based energy infrastructure activities. 33 Comparison of Five Year Cumulative Total Return The performance graph shall not be deemed incorporated by reference by any general statement incorporating by reference this 2021 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 16, 2022, there were approximately 1,770 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. 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 2021 Form 10-K. Unregistered Sales of Equity Securities and Use of Proceeds None. 34 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, 2021: Maximum Number of Shares That May Yet be Average Shares Purchased Purchased Under Total Number of Total Number Price as Part of Publicly the Publicly of Shares Paid per Announced Plans Announced Plans Purchased (1) Share or Programs or Programs October 1, 2021 — October 31, 2021 November 1, 2021 — November 30, 2021 December 1, 2021 — December 31, 2021 Total — $ 6,656 — 6,656 — 8.39 — 8.39 N/A N/A N/A N/A N/A N/A N/A N/A (1) Represents shares withheld to satisfy employees’ tax withholding obligations in connection with the vesting of restricted stock awards during the period. 35 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 2021 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 2021 Form 10-K. This section primarily discusses 2021 and 2020 items and comparisons between these years. For a discussion of changes from 2019 to 2020 and other financial information related to 2019, 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, 2020 filed with the SEC on February 23, 2021. 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. 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 2021 Transactions July 2021 Dispositions In July 2021, we completed sales of certain contract operations customer service agreements and approximately 575 compressors, comprising approximately 100,000 horsepower, used to provide compression services under those agreements, as well as other assets used to support the operations. We received cash consideration of $60.3 million for the sales and recorded gains on the sales of $13.0 million during the year ended December 31, 2021. The proceeds received from the sales were used to repay borrowings outstanding under our Credit Facility. See Note 4 (“Business Transactions”) to our Financial Statements for further details of these transactions. February 2021 Disposition In February 2021, we completed the sale of certain contract operations customer service agreements and approximately 300 compressors, comprising approximately 40,000 horsepower, used to provide compression services under those agreements as well as other assets used to support the operations. We recorded a gain on the sale of $6.0 million during the year ended December 31, 2021. See Note 4 (“Business Transactions”) to our Financial Statements for further details of this transaction. 36 Amendment No. 3 to our Credit Facility In February 2021, we amended our Credit Facility to, among other things, reduce the aggregate revolving commitment from $1.25 billion to $750.0 million and adjust the maximum Senior Secured Debt to EBITDA and Total Debt to EBITDA ratios. We incurred $1.8 million in transaction costs and wrote off $4.9 million of unamortized deferred financing costs as a result of Amendment No. 3. See Note 14 (“Long-Term Debt”) to our Financial Statements for further details of this amendment. At-the-Market Continuous Equity Offering Program In February 2021, we entered into an ATM Agreement whereby we may sell, from time to time, shares of our common stock for an aggregate offering price of up to $50.0 million. We use the proceeds of these offerings for general corporate purposes. During the year ended December 31, 2021, we sold 357,148 shares of common stock for net proceeds of $3.4 million pursuant to this agreement. See Note 16 (“Equity”) to our Financial Statements for further details of this agreement. Trends and Outlook The key driver of our business is the production of U.S. natural gas and crude oil. Approximately 77% of our operating fleet is deployed for midstream natural gas gathering applications, with the remaining fleet being used in gas lift applications to enhance crude oil production. Changes in natural gas and crude oil production spending therefore typically result in changes in demand for our services. Spending on natural gas and crude oil exploration and production typically declines when there is a significant and prolonged reduction in natural gas and crude oil prices or significant instability in energy markets, and increases during periods of rising prices and market stability. 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. COVID-19 Pandemic Beginning in the first quarter of 2020, the COVID-19 pandemic caused a deterioration in global macroeconomic conditions, including a collapse in the demand for natural gas and crude oil coupled with an oversupply of crude oil, which led to substantial spending cuts by our customers and a decline in natural gas and crude oil production. This global response to the pandemic adversely impacted our revenue and cash flows. Though demand and commodity prices have shown improvement since the lows reached in the second quarter of 2020, the potential for additional surges and variants of the disease remains and as such, uncertainty still exists around the timing and potential for a full economic recovery. Our customers substantially cut spending and activity beginning in the second quarter of 2020 as a result of the significant declines in natural gas and crude oil prices and demand and consequently, our horsepower, utilization and revenue experienced declines and remained at lower levels in 2021, as compared to early 2020 and periods prior, in both our contract operations and aftermarket services businesses. In addition to the decline in revenue, the impact of the COVID- 19 pandemic on our results is primarily visible in the $99.8 million non-cash impairment of goodwill and the impairment’s resulting $22.7 million tax benefit in the first quarter of 2020. Cost of sales, SG&A, long-lived and other asset impairment and restructuring charges have also been significantly impacted. See “Financial Results of Operations” below and Note 9 (“Goodwill”), Note 18 (“Long-Lived and Other Asset Impairment”), Note 19 (“Restructuring Charges”) and Note 20 (“Income Taxes”) to our Financial Statements for further discussion. 37 Current Trends In 2019, increased global demand for U.S. natural gas and crude oil production contributed to increased production for both resources and record U.S. natural gas production. Production fell sharply, however, in the second quarter of 2020 as a result of the global response to the COVID-19 pandemic, and remained at depressed levels until the latter half of 2021, at which point production rose relatively consistently through the remainder of the year. According to the EIA’s February 2022 Short-Term Energy Outlook, average U.S. dry natural gas and crude oil production in 2021, 2020 and 2019 were as follows: Year Ended December 31, 2020 2021 2019 Average dry natural gas production (Bcf/d) Average crude oil production (MMb/d) 93.6 11.2 91.3 11.3 92.0 12.2 The increases in production in 2019 resulted in strong demand for our compression services in that year and into the first quarter of 2020. Additionally, we increased our investment in new fleet units in 2019 to take advantage of improved market conditions. As a result of this increased demand and investment, our contract operations revenue and average operating horsepower increased 15% and 10%, respectively, in 2019. In 2020, however, the decrease in demand and production brought on by the COVID-19 pandemic drove revenue and average operating horsepower to below 2019 levels, where they remained through all of 2021, as producers limited drilling and completion activity to achieve maintenance levels of production and cash flows in the course of the pandemic. Similar decreases in demand as a result of the pandemic were seen in our aftermarket services business, where we experienced a rise in customer deferrals of maintenance activities throughout 2020 and the beginning of 2021, before demand picked up in the second quarter of 2021 and continued to improve through the remainder of the year. Outlook The EIA forecasts the following year-over-year changes in its February 2022 Short-Term Energy Outlook: U.S. dry natural gas production U.S. crude oil production U.S. natural gas domestic consumption Liquefied natural gas exports Increase (Decrease) 2022 2023 3 % 7 % 2 % 16 % 2 % 5 % (1)% 7 % Overall, natural gas and crude oil production is expected to increase in 2022 and 2023, returning to pre-COVID-19 levels in 2023, as U.S. onshore activity continues the rise it began in mid-2021. Accordingly, we anticipate demand for our compression services to also increase as we move into 2022. Longer term, per the EIA’s 2021 Annual Energy Outlook, the EIA expects dry natural gas production to increase 12%, 17% and 33% through 2025, 2030 and 2050, respectively. Natural gas provides an affordable and reliable solution that we believe will play a prominent role in a cleaner energy mix, even as energy generation from renewables increases. We believe that 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, aging producing natural gas fields that will require more compression to continue producing the same volume of natural gas 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. We expect that such an increase in demand for U.S. natural gas will in turn lead to continued strong demand for compression services. 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. 38 Key Challenges and Uncertainties In addition to general market conditions in the oil and gas industry – those caused by the COVID-19 pandemic and otherwise – 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 the 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 2022 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 anticipation of lower customer activity levels in response to the COVID-19 pandemic, we implemented a plan in the second quarter of 2020 to significantly reduce our annual operating, corporate and capital costs, many aspects of which we continued to execute on throughout 2021 and expect to continue in the foreseeable future. In addition, 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, once resumed in full, 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 bottlenecks resulting from the COVID-19 pandemic 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. 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, including those employees impacted by our headcount reduction and furloughs through the course of the COVID-19 pandemic. 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. Later-Cycle Market Participant. Compression service providers have traditionally been a later-cycle participant as energy markets fluctuate. As such, we anticipate that any significant change in the demand for our contract operations services will generally lag a change in drilling activity. Increased natural gas and crude oil production in 2018 and 2019 contributed to increased new orders for our compression services during those years and into the first quarter of 2020, the revenue gains from which were realized in 2019 and the first quarter of 2020. In the second quarter of 2020, however, customer demand dropped sharply in response to the COVID-19 pandemic, and the associated decrease in our revenue occurred almost immediately. Dry natural gas production, one of the key drivers of our business, increased 10% in 2019, decreased 1% in 2020, increased 3% in 2021, and is expected to increase 12% in 2022 through 2025. We believe that, similar to the rapid drops in customer demand and associated revenue experienced in 2020, our revenue will increase closely behind the pickup in customer demand as the COVID-19 pandemic runs its course. Long term, we expect to return to the more traditional cycle in which production growth increases demand for compression services, which results in increases in revenue and gross margin, though on a lag of several quarters or more. 39 Customer deferrals. Our aftermarket services revenue decreased in 2020 and 2019 as customers deferred near-term maintenance activities. We saw a decrease in these deferrals beginning in the second quarter of 2021, and we believe the large installed base of owned compression in the U.S. supports the long-term fundamentals of the aftermarket services business, however, the timing of a full recovery is difficult to predict, particularly in light of the economic downturn caused by the COVID-19 pandemic. In the meantime, we remain focused on cost management and the higher margin business within our aftermarket services operations. Increasing customer focus on free cash flow. Prior to the COVID-19 pandemic, many of our customers had begun transitioning their business model to focus on sustainable free cash flow generation rather than growth, and the COVID- 19 pandemic has further fueled this change in focus. We expect this transition to have a positive impact on the industry in the long term, as we anticipate the change will reduce volatility through cycles and improve the financial strength of our customers. In the near term, however, we can expect this transition, combined with the impact of the COVID-19 pandemic, to result in a modest natural gas production growth rate, to which demand for our products and services is closely aligned. 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 (horsepower in thousands) Total available horsepower (at period end)(1) Total operating horsepower (at period end)(2) Average operating horsepower Horsepower utilization: Spot (at period end) Average Year Ended December 31, 2020 2021 2019 3,878 3,247 3,282 4,120 3,388 3,657 4,395 3,926 3,708 84 % 82 % 82 % 86 % 89 % 88 % (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. 40 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, restatement and other charges, restructuring charges, interest expense, debt extinguishment loss, transaction-related costs, (gain) loss on sale of assets, net, other (income) expense, net, provision for (benefit from) income taxes and loss from discontinued operations, net of tax. 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. The following table reconciles net income (loss) to gross margin: (in thousands) Net income (loss) Selling, general and administrative Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Restatement and other charges Restructuring charges Interest expense Debt extinguishment loss Transaction-related costs Gain on sale of assets, net Other income, net Provision for (benefit from) income taxes Loss from discontinued operations, net of tax Gross margin Results of Operations: Summary of Results Revenue Year Ended December 31, 2020 2021 2019 $ $ 28,217 $ 107,167 178,946 21,397 — — 2,903 108,135 — — (30,258) (4,707) 10,744 — 422,544 $ (68,445) $ 105,100 193,138 79,556 99,830 — 8,450 105,716 3,971 — (10,643) (1,359) (17,537) — 497,777 $ 97,330 117,727 188,084 44,663 — 445 — 104,681 3,653 8,213 (16,016) (661) (39,145) 273 509,247 Revenue was $781.5 million and $875.0 million during the years ended December 31, 2021 and 2020, respectively. The decrease in revenue was due to declines in revenue from both our contract operations and aftermarket services businesses. See “Contract Operations” and “Aftermarket Services” below for further details. Net Income (Loss) We had net income of $28.2 million and a net loss of $68.4 million during the years ended December 31, 2021 and 2020, respectively. The change from net loss in 2020 to net income in 2021 was primarily driven by decreases in goodwill impairment, long-lived and other asset impairment, depreciation and amortization, restructuring charges and debt extinguishment loss, as well as increases in gain on sale of assets, net and other income, net. These changes were partially offset by decreases in gross margin of our contract operations and aftermarket services businesses and the change from a benefit from to a provision for income taxes. 41 Results of Operations: Year Ended December 31, 2021 Compared to Year Ended December 31, 2020 Contract Operations (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization) Gross margin Gross margin percentage (1) $ $ (1) Defined as gross margin divided by revenue. Year Ended December 31, 2021 648,311 244,486 403,825 $ $ 62 % 2020 738,918 261,087 477,831 65 % Increase (Decrease) (12)% (6)% (15)% (3)% Revenue decreased primarily due to returns of horsepower amidst the market downturn that began in early 2020, as well as the strategic disposition of horsepower in 2020 and 2021. Gross margin decreased due to the decrease in revenue, however, the decline was partially mitigated by the decrease in cost of sales. The lower operating horsepower discussed above drove a decrease in maintenance, freight and other operating expenses. Offsetting these decreases were (i) increases in start-up and other operating expense, which resulted from an increase in unit redeployment as customers returned to operations from standby status, and lube oil expense, which was primarily due to an increase in commodity price and increased volumes associated with unit redeployment, and (ii) a decrease in our sales and use tax benefit, which resulted from audit settlements in 2020 and no comparable settlements in 2021. Aftermarket Services (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization) Gross margin Gross margin percentage $ $ Year Ended December 31, 2021 133,150 114,431 18,719 $ $ 14 % 2020 136,052 116,106 19,946 15 % Increase (Decrease) (2)% (1)% (6)% (1)% Revenue decreased by $5.2 million due to the sale of our turbocharger business in July 2020, and was further reduced by a decrease in service activities, which was primarily driven by customer deferral of maintenance activities amidst the market downturn. These decreases were partially offset by an increase in parts sales that resulted from an increase in customer demand in the second half of 2021. Gross margin decreased due to the decrease in revenue, however, the decline was partially mitigated by the decrease in cost of sales. The decrease in cost of sales was driven by the decrease in service activities and the sale of our turbocharger business. These decreases to costs of sales were partially offset by the increase in parts sales. 42 Costs and Expenses (in thousands) Selling, general and administrative Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Restructuring charges Interest expense Debt extinguishment loss Gain on sale of assets, net Other income, net $ Year Ended December 31, 2020 2021 $ 107,167 178,946 21,397 — 2,903 108,135 — (30,258) (4,707) 105,100 193,138 79,556 99,830 8,450 105,716 3,971 (10,643) (1,359) Selling, general and administrative. The increase in SG&A was primarily due to a $4.1 million increase in sales and use tax that was mainly driven by audit settlements in 2020 and no comparable settlements in 2021, a $1.3 million increase in information technology expenses, which largely consisted of costs related to our process and technology transformation project, and a $0.8 million increase in professional expenses. These increases were partially offset by a $3.6 million decrease in our provision for credit losses and a $1.4 million decrease in compensation and benefits. Depreciation and amortization. The decrease in depreciation and amortization was primarily due to a decrease in depreciation expense resulting from assets reaching the end of their depreciable lives, the impact of compression and other asset impairments and sales and a decrease in amortization expense as certain intangible assets reached the end of their useful lives. These decreases were partially offset by increases in depreciation expense associated with fixed asset additions and the write-off of compression and building assets damaged by Hurricane Ida in 2021. 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. In addition, we evaluate for impairment idle units that have been culled from our compression fleet in prior years and are available for sale. See Note 18 (“Long-Lived and Other Asset Impairment”) to our Financial Statements for further details. The following table presents the results of our compression fleet impairment review, as recorded in our contract operations segment: (dollars in thousands) Idle compressors retired from the active fleet Horsepower of idle compressors retired from the active fleet Impairment recorded on idle compressors retired from the active fleet $ Year Ended December 31, 2020 2021 230 85,000 21,208 $ 730 261,000 77,590 Also during the year ended December 31, 2020, we impaired $1.7 million of capitalized implementation and unamortized prepaid costs related to the mobile workforce component of our process and technology transformation project. See Note 12 (“Hosting Arrangements”) to our Financial Statements for further details. Goodwill impairment. During the year ended December 31, 2020, we recorded goodwill impairment of $99.8 million due to the decline in the fair value of our contract operations reporting unit. See Note 9 (“Goodwill”) to our Financial Statements for further details. Restructuring charges. Restructuring charges of $2.9 million and $8.5 million during the years ended December 31, 2021 and 2020, respectively, primarily consisted of severance and property disposal costs related to our restructuring activities. See Note 19 (“Restructuring Charges”) to our Financial Statements for further details. 43 Interest expense. The increase in interest expense was primarily due to an increase in the weighted average effective interest rate and the $4.9 million write-off of unamortized deferred financing costs related to Amendment No. 3, which were largely offset by a decrease in the average outstanding balance of long-term debt. Debt extinguishment loss. We recorded a debt extinguishment loss of $4.0 million during the year ended December 31, 2020 as a result of the redemption of the 2022 Notes. See Note 14 (“Long-Term Debt”) to our Financial Statements for further details. Gain on sale of assets, net. Our net gain on the sale of assets during the year ended December 31, 2021 was primarily the result of $13.0 million of gains recognized on the July 2021 Dispositions, the $6.0 million gain on the February 2021 Disposition, $9.3 million of gains recognized on other compression asset sales during 2021 and $3.3 million of gains recognized on other transportation and shop asset sales during the period. Our net gain on the sale of assets during the year ended December 31, 2020 was primarily due to the $9.3 million gain on the July 2020 Disposition, the $3.2 million gain on the March 2020 Disposition and gains of $3.7 million on sales of other transportation and shop equipment. These gains were offset by a $5.1 million loss on other compression assets sold during 2020. Other income, net. The increase in other income, net was primarily due to an insurance settlement of $2.8 million related to damages caused by Hurricane Ida to facilities and compressors, as well as a $0.4 million decrease in indemnification expense remitted pursuant to our tax matters agreement with Exterran Corporation. Provision for (Benefit from) Income Taxes (dollars in thousands) Provision for (benefit from) income taxes Effective tax rate Year Ended December 31, 2021 2020 Increase (Decrease) $ 10,744 $ 28 % (17,537) 20 % (161)% 8 % The change from a benefit from to a provision for income taxes was primarily due to the tax effect of the increase in book income during the year ended December 31, 2021 compared to the year ended December 31, 2020. See Note 20 (“Income Taxes”) to our Financial Statements for further details. 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. Beginning in the first quarter of 2020, the COVID-19 pandemic caused a deterioration in global macroeconomic conditions, which adversely impacted our estimates of future revenues and cash flows. However, 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 securities in open market purchases, privately negotiated transactions or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. 44 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 and 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 $37.2 million and $79.1 million during the years ended December 31, 2021 and 2020, respectively. The decrease in growth capital expenditures from 2020 to 2021 was the result of a previously-planned decrease in spending in 2020, which was based on an expected deceleration in the growth rate of natural gas production, and further reductions in spend in response to the decreased customer demand that resulted from the COVID-19 pandemic. 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 $47.3 million and $32.0 million during the years ended December 31, 2021 and 2020, respectively. The increase in maintenance capital expenditures from 2020 to 2021 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. Projected Capital Expenditures. We currently plan to spend approximately $213 million to $235 million in capital expenditures during 2022, primarily consisting of approximately $150 million for growth capital expenditures and approximately $55 million to $75 million for maintenance capital expenditures. We anticipate increased 2022 capital expenditures, particularly growth capital expenditures, as compared to 2021 due to increased investment in new compression equipment as a result of higher customer demand. Dividends On January 27, 2022, our Board of Directors declared a quarterly dividend of $0.145 per share of common stock, or approximately $22.6 million, which was paid on February 15, 2022 to stockholders of record at the close of business on February 8, 2022. 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. 45 Contractual Obligations Our material contractual obligations as of December 31, 2021 consisted of the following: • Long-term debt of $1.5 billion, of which $1.3 billion is due in 2027 and 2028, with the remainder due in 2024; • Estimated interest on our long-term debt of $515 million, consisting of approximate annual payments of $90 million in 2021 through 2024 and annual payments of $85 million or less in 2025 through 2028; • Purchase commitments of $95.5 million, of which $89.2 million is due in 2022, that primarily consist of commitments to purchase fleet assets and information technology-related costs; and • Operating lease payments of $22.4 million that are spread relatively evenly in 2022 through 2030. In addition, we had $19.6 million of unrecognized tax benefits (including discontinued operations) recorded as liabilities related to uncertain tax positions at December 31, 2021, which we are uncertain as to if or when such amounts may be settled. We had a liability of $2.2 million recorded for potential penalties and interest (including discontinued operations) related to these unrecognized tax benefits. Sources of Cash Revolving Credit Facility During the years ended December 31, 2021 and 2020, our Credit Facility had an average daily balance of $295.3 million and $704.5 million, respectively. The weighted average annual interest rate on the outstanding balance under the Credit Facility, excluding the effect of interest rate swaps, was 2.6% and 2.7% at December 31, 2021 and 2020, respectively. As of December 31, 2021, there were $8.9 million letters of credit outstanding under the Credit Facility and the applicable margin on borrowings outstanding was 2.4%. We executed two amendments to our facility during the three-year period ended December 31, 2021; see Note 14 (“Long-Term Debt”) to our Financial Statements for details of these amendments. Certain Facility Terms. Our Credit Facility matures in November 2024 and has an aggregate revolving commitment of $750.0 million. Portions of the Credit Facility up to $50.0 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 14 (“Long-Term Debt”) to our Financial Statements) 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 a result of the financial ratio requirements, $502.5 million of the $506.6 million of undrawn capacity was available for additional borrowings as of December 31, 2021. We were in compliance with all other covenants under our Credit Facility agreement. Senior Notes As of both December 31, 2021 and 2020, 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 14 (“Long-Term Debt”) to our Financial Statements for further details of these notes. 46 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 use the net proceeds of these offerings for general corporate purposes. During the year ended December 31, 2021, we sold 357,148 shares of common stock for net proceeds of $3.4 million pursuant to the ATM Agreement. See Note 16 (“Equity”) to our Financial Statements for further details of this agreement. Other Sources of Cash Business Dispositions and Other Asset Sales. We received proceeds of $112.9 million and $52.6 million from business dispositions and other asset sales during the years ended December 31, 2021 and 2020, 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. Cash Flows Our cash flows, as reflected in our consolidated statements of cash flows, are summarized below: (in thousands) Net cash provided by (used in): Operating activities Investing activities Financing activities Net increase (decrease) in cash and cash equivalents Year Ended December 31, 2020 2021 $ $ 237,400 16,107 (253,035) 472 $ $ 335,278 (85,031) (252,835) (2,588) Operating Activities. The decrease in net cash provided by operating activities was primarily due to reduced cash inflows from revenue, deferred revenue, accounts receivable, contract costs and the receipt of cash proceeds from sales and use tax audit settlements in 2020 with no comparable settlements in 2021, as well as increased cash outflow for inventory. Partially offsetting these decreases in operating cash were decreased cash outflows for cost of sales, accounts payable and other liabilities, SG&A expenses and restructuring charges, and the receipt of additional cash proceeds from the July 2020 Disposition in 2021. Investing Activities. The change from net cash used in to net cash provided by investing activities was primarily due to a $60.3 million increase in proceeds from business dispositions and other sales of property, plant and equipment and a $42.4 million decrease in capital expenditures. Financing Activities. Net cash used in financing activities was relatively unchanged primarily due to several offsetting items, including an increase of $3.1 million in net repayments of long-term debt, which was offset by $3.4 million of net proceeds from the issuance of common stock under our ATM Agreement during 2021 and a $2.8 million decrease in payments for debt issuance costs. 47 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, 2021 was $2.2 billion and depreciation expense was $167.6 million for the year ended December 31, 2021. Property, plant and equipment are carried at cost and depreciated using the straight- line basis over the estimated useful life of the asset. 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, 2021, we recorded long-lived and other asset impairment of $21.4 million. Impairment Assessments of Property, Plant and Equipment and Identifiable Intangible Assets We review long-lived assets, including property, plant and equipment and identifiable intangibles 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 based on the expected net sale proceeds compared to other 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 18 (“Long-Lived and Other Asset Impairment”) and Note 23 (“Fair Value Measurements”) to our Financial Statements for further details of our fleet asset impairments. 48 Impairment Assessment of Goodwill In the first quarter of 2020, the global response to the COVID-19 pandemic significantly impacted our market capitalization and estimates of future revenues and cash flows, which triggered the need to perform a quantitative test of the fair value of our contract operations reporting unit. The fair value calculation required us to make significant estimates to determine future cash flows, including future revenues, costs and capital requirements and the appropriate risk-adjusted discount rate by which to discount the estimated future cash flows. See Note 2 (“Basis of Presentation and Significant Accounting Policies”) and Note 9 (“Goodwill”) for further details of the assessment performed on our goodwill in 2020. 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. only and, as a result, are subject to income taxes in the U.S. only. 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 the results of discontinued operations and changes in accounting policies and incorporate assumptions, including the amount of future U.S. federal and state 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. 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 standard for income taxes provides 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. 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 use derivative instruments to manage our exposure to fluctuations in this variable interest rate, however, our interest rate swaps mature in the first quarter of 2022, at which time all borrowings under the Credit Facility will be subject to variable interest rates. After taking into consideration our interest rate swaps, we did not have any debt subject to variable interest rates as of December 31, 2021. Not considering our interest rate swaps, a 1% increase in the effective interest rate on the outstanding balance under our Credit Facility at December 31, 2021 would have resulted in an annual increase in our interest expense of $2.3 million. 49 See Note 22 (“Derivatives”) to our Financial Statements for further information regarding our interest rate swaps. Item 8. Financial Statements and Supplementary Data The information specified by this Item is presented in Part IV Item 15 of this 2021 Form 10-K. Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure None. Item 9A. Controls and Procedures Management’s Evaluation of Disclosure Controls and Procedures As of the end of the period covered by this 2021 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, 2021, 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. 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, 2021. The effectiveness of internal control over financial reporting as of December 31, 2021 was audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in its report found within this 2021 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. 50 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, 2021, 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, 2021, 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, 2021, of the Company and our report dated February 23, 2022, 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 23, 2022 51 Item 9B. Other Information None. PART III Item 10. Directors, Executive Officers and Corporate Governance The information required in Part III Item 10 of this 2021 Form 10-K is incorporated by reference to the sections entitled “Election of Directors,” “Governance” and “Stock Ownership” in our definitive proxy statement to be filed with the SEC within 120 days of the end of our fiscal year. Item 11. Executive Compensation The information required in Part III Item 11 of this 2021 Form 10-K is incorporated by reference to the sections entitled “Governance” and “Compensation Discussion and Analysis” in our definitive proxy statement to be filed with the SEC within 120 days of the end of our fiscal year. 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 2021 Form 10-K are incorporated by reference to the section entitled “Stock Ownership” in our definitive proxy statement to be filed with the SEC within 120 days of the end of our fiscal year. Securities Authorized for Issuance under Equity Compensation Plans The following table sets forth information as of December 31, 2021, with respect to the Archrock compensation plans under which our common stock is authorized for issuance, aggregated as follows: Number of Securities to be Issued Upon Exercise of Weighted Average Exercise Price of Outstanding Options, Outstanding Options, Warrants and Rights Warrants and Rights (a) (b) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (c) 357,187 (2) $ — 357,187 — (3) — — 7,768,344 (4) 37,771 7,806,115 Equity compensation plans approved by security holders (1) Equity compensation plans not approved by security holders (5) Total (1) Comprised of the 2013 Plan, 2020 Plan and ESPP. No additional grants may be made under the 2013 Plan. (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) Includes 7,246,625 shares of common stock under the 2020 Plan and 521,719 shares of common stock under the ESPP. In addition, as of December 31, 2021, 1,698,150 restricted shares were outstanding, which are not included in column (c). (5) Comprised of our DSDP. See Note 24 (“Stock-Based Compensation”) to our Financial Statements for further details of our DSDP. Item 13. Certain Relationships and Related Transactions and Director Independence The information required in Part III Item 13 of this 2021 Form 10-K is incorporated by reference to the section entitled “Governance” in our definitive proxy statement to be filed with the SEC within 120 days of the end of our fiscal year. 52 Item 14. Principal Accountant Fees and Services The information required in Part III Item 14 of this 2021 Form 10-K is incorporated by reference to the section entitled “Ratification of the Appointment of the Independent Registered Public Accounting Firm” in our definitive proxy statement to be filed with the SEC within 120 days of the end of our fiscal year. PART IV Item 15. Exhibits and Financial Statement Schedules (a) Documents filed as a part of this 2021 Form 10-K 1. Financial Statements. The following financial statements are filed as a part of this 2021 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 F-1 F-3 F-4 F-5 F-6 F-7 F-9 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. 2.1 2.2 2.3 2.4 2.5 2.6 Description 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 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 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 of Archrock’s Current Report on Form 8-K filed on January 2, 2018 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 of Archrock’s Current Report on Form 8-K filed on January 16, 2018 Asset Purchase Agreement, dated as of June 23, 2019, by and among Archrock Services, L.P., Archrock, Inc. and Elite Compression Services, LLC, incorporated by reference to Exhibit 2.1 of the Registrant’s Current Report on Form 8-K filed on June 24, 2019 Asset Purchase Agreement, dated as of June 23, 2019, by and between Archrock Services, L.P. and Harvest Four Corners, LLC, incorporated by reference to Exhibit 2.2 of the Registrant’s Current Report on Form 8-K filed on June 24, 2019 53 Exhibit No. 3.1 3.2 3.3 4.1 4.2 4.3 10.1 10.2 10.3 10.4 10.5 10.6 10.7 10.8 Description 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 Third Amended and Restated Bylaws of Exterran Holdings, Inc. (now Archrock, Inc.), incorporated by reference to Exhibit 3.1 of the Registrant’s Current Report on Form 8-K filed on March 20, 2013 Amendment No. 1 to Third Amended and Restated Bylaws of Archrock, Inc., incorporated by reference to Exhibit 3.1 of the Registrant’s Current Report on Form 8-K filed on May 5, 2020 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 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 Description of Common Stock Credit Agreement, dated as of July 10, 2015, by and among Exterran Holdings, Inc. (now Archrock, Inc.), Archrock Services, L.P., the lenders from time to time party thereto and Wells Fargo Bank, National Association, as administrative agent, incorporated by reference to Exhibit 10.2 to the Company’s Current Report on Form 8-K filed on July 16, 2015 First Amendment to Credit Agreement, dated as of October 5, 2015, by and among Exterran Holdings, Inc. (now Archrock, Inc.), Archrock Services, L.P., the lenders signatory thereto and Wells Fargo Bank, National Association, as administrative agent, incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed on October 6, 2015 Amended and Restated Senior Secured Credit Agreement, dated as of November 3, 2010, by and among EXLP Operating LLC, as Borrower, Exterran Partners, L.P., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, Bank of America, N.A. and JPMorgan Chase Bank, N.A., as Co-Syndication Agents, Barclays Bank plc and The Royal Bank of Scotland plc, as Co- Documentation Agents, and the lenders signatory thereto, incorporated by reference to Exhibit 10.1 to Exterran Partners L.P.’s Current Report on Form 8-K filed on November 9, 2010 First Amendment to Amended and Restated Senior Secured Credit Agreement, dated March 7, 2012, among EXLP Operating LLC, as Borrower, Exterran Partners, L.P., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent and Swingline Lender, and the other lenders signatory thereto, incorporated by reference to Exhibit 10.1 to Exterran Partners, L.P.’s Current Report on Form 8-K filed on March 13, 2012 Third Amendment to Amended and Restated Senior Secured Credit Agreement, dated March 27, 2013, among EXLP Operating LLC, as Borrower, Exterran Partners, L.P., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders signatory thereto, incorporated by reference to Exhibit 10.1 to Exterran Partners, L.P.’s Current Report on Form 8-K filed on March 28, 2013 Fourth Amendment to Amended and Restated Senior Secured Credit Agreement, dated February 4, 2015, among EXLP Operating LLC, as Borrower, Exterran Partners, L.P., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders signatory thereto, incorporated by reference to Exhibit 10.1 to Exterran Partners, L.P.’s Current Report on Form 8-K filed on February 5, 2015 Fifth Amendment to Amended and Restated Senior Secured Credit Agreement and First Amendment to Amended and Restated Collateral Agreement, dated May 2, 2016, among Archrock Partners Operating LLC, as Borrower, Archrock Partners, L.P., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders party thereto, incorporated by reference to Exhibit 10.1 to Archrock Partners, L.P.’s Current Report on Form 8-K filed on May 6, 2016 Amended and Restated Guaranty Agreement, dated as of November 3, 2010, made by Exterran Partners, L.P. and EXLP Leasing LLC in favor of Wells Fargo Bank, National Association, as Administrative Agent, incorporated by reference to Exhibit 10.2 to Archrock Partner’s L.P.’s Current Report on Form 8-K filed on November 9, 2010 54 Exhibit No. 10.9 10.10 10.11 10.12 10.13 10.14 10.15 10.16† 10.17† 10.18† 10.19† 10.20† Description Amended and Restated Collateral Agreement, dated as of November 3, 2010, made by EXLP Operating LLC, Exterran Partners, L.P. and EXLP Leasing LLC in favor of Wells Fargo Bank, National Association, as Administrative Agent, incorporated by reference to Exhibit 10.3 to Archrock Partner’s L.P.’s Current Report on Form 8-K filed on November 9, 2010 Second Amendment, Consent and Waiver to Credit Agreement, dated as of May 10, 2016, among Archrock Services, L.P., as Borrower, Archrock, Inc., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders party thereto, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on May 11, 2016 Third Amendment, Consent and Waiver to Credit Agreement, dated as of July 21, 2016, among Archrock Services, L.P., as Borrower, Archrock, Inc., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders party thereto, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on July 26, 2016 Fourth Amendment, Consent and Waiver to Credit Agreement, dated as of September 21, 2016, among Archrock Services, L.P., as Borrower, Archrock, Inc., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders party thereto, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on September 22, 2016 Fifth Amendment, Consent and Waiver to Credit Agreement, dated as of December 9, 2016, among Archrock Services, L.P., as Borrower, Archrock, Inc., as Guarantor, Wells Fargo Bank, National Association, as Administrative Agent, and the other lenders party thereto. incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on December 12, 2016 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 for the year ended December 31, 2015 (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) 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) Exterran Holdings, Inc. (now Archrock, Inc.) 2013 Stock Incentive Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 19, 2013 First Amendment to the Exterran Holdings, Inc. (now Archrock, Inc.) 2013 Stock Incentive Plan, incorporated by reference to Exhibit 10.13 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Annex B to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 26, 2009 Amendment No. 1 to Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 26, 2009 Amendment No. 2 to Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Exhibit 10.10 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2009 55 Exhibit No. 10.21† 10.22† 10.23† 10.24† 10.25† 10.26† 10.27† 10.28† 10.29† 10.30† 10.31† 10.32† 10.33† 10.34† 10.35† 10.36† 10.37† 10.38† Description Amendment No. 3 to the Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 29, 2010 Amendment No. 4 to the Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Annex A to the Registrant’s Definitive Proxy Statement on Schedule 14A, filed March 29, 2011 Amendment No. 5 to the Exterran Holdings, Inc. (now Archrock, Inc.) Amended and Restated 2007 Stock Incentive Plan, incorporated by reference to Exhibit 10.14 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Exterran Holdings, Inc. 2011 (now Archrock, Inc.) Employment Inducement Long-Term Equity Plan, incorporated by reference to Exhibit 4.1 to the Registrant’s Registration Statement on Form S-8, filed November 4, 2011 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 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 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 Exterran Holdings, Inc. (now Archrock, Inc.) Employee Stock Purchase Plan, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on August 23, 2007 Amendment No. 1 to the Exterran Holdings, Inc. (now Archrock, Inc.) Employee Stock Purchase Plan, incorporated by reference to Annex D to the Registrant’s Definitive Proxy Statement on Schedule 14A filed on March 29, 2011 Amendment No. 2 to the Exterran Holdings, Inc. (now Archrock, Inc.) Employee Stock Purchase Plan, incorporated by reference to Annex C to the Registrant’s Definitive Proxy Statement on Schedule 14A, filed on March 29, 2011 Amendment No. 3 to the Exterran Holdings, Inc. (now Archrock, Inc.) Employee Stock Purchase Plan, incorporated by reference to Exhibit 10.15 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Archrock Deferred Compensation Plan, incorporated by reference to Exhibit 10.17 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 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 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Incentive Stock Option, incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2009 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Non-Qualified Stock Option, incorporated by reference to Exhibit 10.2 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2009 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Stock Option for Officers, incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2010 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Non-Qualified Stock Option, incorporated by reference to Exhibit 10.2 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2010 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Stock Option for Officers, incorporated by reference to Exhibit 10.63 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2010 56 Exhibit No. 10.39† 10.40† 10.41† 10.42† 10.43† 10.44† 10.45† 10.46† 10.47† 10.48† 10.49† 10.50† 10.51† 10.52† 10.53† 10.54† 10.55† 10.56† 10.57† Description Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice for Time-Vested Non-Qualified Stock Option, incorporated by reference to Exhibit 10.64 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2010 Form of Indemnification Agreement, incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed on August 23, 2007 Form of Amendment to Indemnification Agreement, incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2016 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Time- Vested Incentive Stock Option for Officers, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Time- Vested Non-Qualified Stock Option, incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Time- Vested Restricted Stock, incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Time- Vested Cash-Settled Restricted Stock Units, incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Time- Vested Stock-Settled Restricted Stock Units, incorporated by reference to Exhibit 10.5 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Performance Units, incorporated by reference to Exhibit 10.6 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Common Stock Award for Non-Employee Directors, incorporated by reference to Exhibit 10.7 to the Registrant’s Current Report on Form 8-K filed on March 10, 2014 Form of Exterran Holdings, Inc. (now Archrock, Inc.) Award Notice and Agreement for Performance Units incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on February 25, 2015 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 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 Form of Compensation Letter applicable to Messrs. Childers, Miller, Rice and Wayne, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on August 4, 2016. 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 Form of Employment Letter applicable to Messrs. Childers, Miller, Rice, Wayne and Ingersoll, incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Severance Benefit Agreement applicable to Messrs. Childers, Miller, Rice, Wayne and Ingersoll, incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Change of Control Agreement applicable to Messrs. Childers, Miller, Rice, Wayne and Ingersoll, incorporated by reference to Exhibit 10.10 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Award Notice and Agreement for Restricted Stock pursuant to the 2013 Stock Incentive Plan, incorporated by reference to Exhibit 10.11 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 57 Exhibit No. 10.58† 10.59† 10.60† 10.61† 10.62† 10.63 10.64 10.65 10.66 10.67† 10.68† 10.69† 10.70 10.71 10.72† 10.73† 10.74† 10.75† 10.76† Description Form of Award Notice and Agreement for Common Stock Award for Non-Employee Directors pursuant to the 2013 Stock Incentive Plan, incorporated by reference to Exhibit 10.12 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Archrock, Inc. Award Notice and Agreement for Performance Units, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on February 24, 2016 Form of Archrock, Inc. Award Notice and Agreement for Time-Vested Restricted Stock, incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on February 24, 2016 Form of Archrock, Inc. Award Notice and Agreement for Time-Vested Stock-Settled Restricted Stock Units, incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed on February 24, 2016 Form of Archrock, Inc. Award Notice and Agreement for Common Stock Award for Non-Employee Directors, incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed on February 24, 2016 Employee 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 10.1 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 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 Transition Services Agreement, dated as of November 3, 2015, by and between Exterran Holdings, Inc. (now Archrock, Inc.) and Exterran Corporation, incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Supply Agreement, dated as of November 3, 2015, by and among Archrock Services, L.P., EXLP Operating LLC and Exterran Energy Solutions, L.P., incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Archrock, Inc. Award Notice and Agreement for Performance Units, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on February 23, 2017 Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock for Non-Employee Directors, incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on February 23, 2017 Archrock, Inc. 2017 Employee Stock Purchase Plan, incorporated by reference to Annex A to Archrock’s Definitive Proxy Statement filed March 16, 2017 Sixth Amendment and Consent to Credit Agreement and Second Amendment to Guaranty and Collateral Agreement, dated as of March 30, 2017, by and among Archrock Services, L.P., Archrock, Inc., the Guarantors party thereto, the Lenders party thereto and Wells Fargo Bank, National Association, as administrative agent for the Lenders incorporated by reference to Exhibit 10.3 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2017 Consulting Agreement between Archrock, Inc. and Donald C. Wayne dated May 11, 2017 incorporated by reference to Exhibit 10.2 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2017 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 Form of Second Amendment to Severance Benefit Agreement Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Cash-Settled), incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on February 21, 2018 Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Stock-Settled), incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed on February 21, 2018 Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock Units, incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed on February 21, 2018 58 Exhibit No. 10.77† 10.78† 10.79† 10.80 10.81 10.82 10.83† 10.84† 10.85† 10.86† 10.87† 10.88† 10.89 10.90 10.91 10.92 Description Form of Letter Agreement Amending the Award Notice and Agreement for 2017 Performance Units, incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed on February 21, 2018 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 Form of Letter Agreement, dated as of March 19, 2018, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on March 21, 2018 Amendment No. 1 to Credit Agreement, dated as of February 23, 2018, by and among Archrock Partners, 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 to the Partnership’s Current Report on Form 8-K filed on February 28, 2018. 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 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 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 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 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 for the year ended December 31, 2018 Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock for Non-Employee Directors, incorporated by reference to Exhibit 10.86 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2018 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 for the year ended December 31, 2018 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 for the year ended December 31, 2018 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 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 Board Representation Agreement, dated as of August 1, 2019, by and between Archrock, Inc. and JDH Capital Holdings, L.P., incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on August 1, 2019 Registration Rights Agreement, dated as of August 1, 2019, by and between Archrock, Inc. and JDH Capital Holdings, L.P., incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed on August 1, 2019 59 Exhibit No. 10.93 10.94 10.95 10.96† 10.97 10.98 10.99† 10.100† 10.101† 10.102† 10.103† 10.104† 10.105† 21.1* 23.1* 31.1* 31.2* 32.1** 32.2** 101.1* 104.1* Description Amendment No. 2 to Credit Agreement, dated as of November 8, 2019, 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 Administrative Agent, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on November 12, 2019 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 Separation Agreement, dated effective as of January 31, 2020 between Archrock, Inc. and Sean K. Clawges, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on February 11, 2020 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 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 Amendment No. 3 to Credit Agreement, dated as of February 22, 2021, 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 Administrative Agent, incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed on February 23, 2021 Form of Letter Agreement Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock for Non-Employee Directors Form of Archrock, Inc. Award Notice and Agreement for Restricted Stock Units for Non-Employee Directors Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Cash-Settled) Form of Archrock, Inc. Award Notice and Agreement for Performance Units (Stock-Settled) 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 List of Subsidiaries of Archrock, Inc. Consent of Deloitte & Touche LLP Certification of the Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 Certification of the Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 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 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 Interactive data files pursuant to Rule 405 of Regulation S-T 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. 60 Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. SIGNATURES Archrock, Inc. /s/ D. Bradley Childers D. Bradley Childers President and Chief Executive Officer February 23, 2022 61 POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints D. Bradley Childers, Douglas S. Aron, Donna A. Henderson and Stephanie C. Hildebrandt, and each of them, his or her true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution for him or her and in his or her name, place and stead, in any and all capacities, to sign any and all amendments to this Report, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite and necessary to be done as fully to all said attorneys-in-fact and agents, or any of them, may lawfully do or cause to be done by virtue thereof. Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on February 23, 2022. Signature Title /s/ D. Bradley Childers D. Bradley Childers /s/ Douglas S. Aron Douglas S. Aron /s/ Donna A. Henderson Donna A. Henderson /s/ Anne-Marie N. Ainsworth Anne-Marie N. Ainsworth /s/ Gordon T. Hall Gordon T. Hall /s/ Frances Powell Hawes Frances Powell Hawes /s/ J.W.G. Honeybourne J.W.G. Honeybourne /s/ James H. Lytal James H. Lytal /s/ Leonard W. Mallett Leonard W. Mallett /s/ Jason C. Rebrook Jason C. Rebrook /s/ Edmund P. Segner, III Edmund P. Segner, III President, Chief Executive Officer and Director (Principal Executive Officer) Senior Vice President and Chief Financial Officer (Principal Financial Officer) Vice President and Chief Accounting Officer (Principal Accounting Officer) Director Director Director Director Director Director Director Director 62 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the shareholders and the Board of Directors of Archrock, Inc. Opinion on the Financial Statements We have audited the accompanying consolidated balance sheets of Archrock, Inc. and subsidiaries (the “Company”) as of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income, equity, and cash flows, for each of the three years in the period ended December 31, 2021, and the related notes listed in the Index at Item 15 (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America. We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2021, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 23, 2022 expressed an unqualified opinion on the Company's internal control over financial reporting. Basis for Opinion These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion. Critical Audit Matter The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. Long-Lived Asset Impairment - Refer to Note 18 to the financial statements. Critical Audit Matter Description Management’s evaluation of whether to retire compressor units from its active fleet takes into consideration the future deployment of the units that were not of the type, configuration, condition, make, or model that are cost efficient to maintain or operate. Once a compressor unit is retired from the active fleet, it is tested for impairment. As such, the timing of the identification of compressor units for removal could have a significant impact on the amount of any impairment charge. During the year ended December 31, 2021, the Company retired 230 units from the active fleet resulting in an F-1 asset impairment charge of $21.2 million. The determination of impairment requires management to make significant estimates and assumptions related to the timing of the identification of compressor units for removal. Changes in these assumptions could have a significant impact on the amount of impairment charged. Auditing the decisions on when compressor units are retired from the active fleet required a high degree of auditor judgment and an increased extent of effort, including the need to involve our fair value specialists, when performing audit procedures to evaluate the reasonableness of management’s assumptions. How the Critical Audit Matter Was Addressed in the Audit Our audit procedures related to management’s determination of whether to retire compressor unit from the Company’s active fleet included the following, among others: • We tested the operating effectiveness of internal controls over long-lived asset impairment process, including those over the identification of units to be retired and assessed for impairment, which includes the type, configuration, condition, make, or model that are cost efficient to maintain or operate. • We tested the completeness and accuracy of the compressor units identified for retirement by performing the following procedures: – Comparing the final listing of retired compressor units to the list evaluated and approved by management. – For a sample of compressor units, determining whether those units were (1) properly segregated from the active fleet, (2) identified appropriately in the system, and (3) no longer operating. • We evaluated the reasonableness of Fair Market Value assigned by management on impaired units by using Internal Fair Value Specialists. • We evaluated the reasonableness of management’s identification of the compressor units for removal, including assessments of type, configuration, condition, make, or model that are cost efficient to maintain or operate, by performing the following procedures: – Comparing the rationale for compression units identified with historical rationales made for compression units of a similar type, configuration, make, or model. – For a sample of compression units not retired, making inquiries of management and others within the Company with knowledge of the type, configuration, condition, make, or model and operating costs of the specific compressor units to identify if any units not retired exhibit characteristics indicating that they should be retired. – Comparing the compression units identified to internal communications to management and the Board of Directors. – Reading available peer company data and other external sources for information supporting or contradicting management’s conclusions. /s/ DELOITTE & TOUCHE LLP Houston, Texas February 23, 2022 We have served as the Company’s auditor since 2007. F-2 Archrock, Inc. Consolidated Balance Sheets (in thousands, except par value and share amounts) Assets Current assets: Cash and cash equivalents Accounts receivable, trade, net of allowance of $2,152 and $3,370, respectively Inventory Other current assets Total current assets Property, plant and equipment, net Operating lease ROU assets Intangible assets, net Contract costs, net Deferred tax assets Other assets Noncurrent assets associated with discontinued operations Total assets Liabilities and Equity Current liabilities: Accounts payable, trade Accrued liabilities Deferred revenue Total current liabilities Long-term debt Operating lease liabilities Deferred tax liabilities Other liabilities Noncurrent liabilities associated with discontinued operations Total liabilities Commitments and contingencies (Note 26) Equity: Preferred stock: $0.01 par value per share, 50,000,000 shares authorized, zero issued Common stock: $0.01 par value per share, 250,000,000 shares authorized, 161,482,852 and 160,014,960 shares issued, respectively Additional paid-in capital Accumulated other comprehensive loss Accumulated deficit Treasury stock: 7,417,401 and 7,052,769 common shares, at cost, respectively Total equity Total liabilities and equity December 31, 2021 2020 $ 1,569 $ 1,097 104,931 72,869 7,201 186,570 2,226,526 17,491 47,887 25,418 47,879 28,384 9,811 2,589,966 38,920 82,517 3,817 125,254 1,530,825 15,940 1,136 17,505 7,868 1,698,528 $ $ 104,425 63,670 12,819 182,011 2,389,674 19,236 61,531 29,216 56,934 30,084 11,036 2,779,722 30,819 76,993 3,880 111,692 1,688,867 16,925 725 18,088 7,868 1,844,165 $ $ — — 1,615 3,440,059 (984) (2,463,114) (86,138) 891,438 2,589,966 $ $ 1,600 3,424,624 (5,006) (2,401,988) (83,673) 935,557 2,779,722 The accompanying notes are an integral part of these consolidated financial statements. F-3 Archrock, Inc. Consolidated Statements of Operations (in thousands, except per share amounts) Year Ended December 31, 2020 2021 2019 Revenue: Contract operations Aftermarket services Total revenue Cost of sales (excluding depreciation and amortization): Contract operations Aftermarket services Total cost of sales (excluding depreciation and amortization) Selling, general and administrative Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Restatement and other charges Restructuring charges Interest expense Debt extinguishment loss Transaction-related costs Gain on sale of assets, net Other income, net Income (loss) before income taxes Provision for (benefit from) income taxes Income (loss) from continuing operations Loss from discontinued operations, net of tax Net income (loss) Basic and diluted net income (loss) per common share Weighted average common shares outstanding: Basic Diluted $ 648,311 $ 133,150 781,461 738,918 $ 136,052 874,970 244,486 114,431 261,087 116,106 358,917 107,167 178,946 21,397 — — 2,903 108,135 — — (30,258) (4,707) 38,961 10,744 28,217 — 28,217 $ 377,193 105,100 193,138 79,556 99,830 — 8,450 105,716 3,971 — (10,643) (1,359) (85,982) (17,537) (68,445) — (68,445) $ 771,539 193,946 965,485 297,260 158,978 456,238 117,727 188,084 44,663 — 445 — 104,681 3,653 8,213 (16,016) (661) 58,458 (39,145) 97,603 (273) 97,330 $ $ 0.18 $ (0.46) $ 0.70 151,684 151,830 150,828 150,828 137,492 137,528 The accompanying notes are an integral part of these consolidated financial statements. F-4 Archrock, Inc. Consolidated Statements of Comprehensive Income (in thousands) Net income (loss) Other comprehensive income (loss), net of tax: Interest rate swap gain (loss), net of reclassifications to earnings Amortization of dedesignated interest rate swap Total other comprehensive income (loss), net of tax Year Ended December 31, 2020 2021 2019 $ 28,217 $ (68,445) $ 97,330 3,159 863 4,022 (3,619) — (3,619) (7,160) — (7,160) 90,170 Comprehensive income (loss) $ 32,239 $ (72,064) $ The accompanying notes are an integral part of these consolidated financial statements. F-5 Archrock, Inc. Consolidated Statements of Equity (in thousands, except share data) Common Stock Additional Paid-in Capital Amount $ 1,358 135,787,509 $ 3,177,982 $ Shares Archrock Stockholders Accumulated Other Comprehensive Accumulated Income (Loss) Deficit Treasury Stock 1 87,933 770 11 1,104,793 8,094 217 21,656,683 225,663 Amount Shares Total 5,773 $ (2,263,677) $ (79,862) (2,007) (6,381,605) (212,080) $ 841,574 (2,007) (78,530) 97,330 (78,530) 771 (108,917) 8,105 225,880 97,330 $ 1,587 158,636,918 $ 3,412,509 $ (7,160) (1,387) $ (2,244,877) $ (81,869) (1,804) (6,702,602) (236,752) (7,160) $ 1,085,963 (1,804) 2 171,563 681 11 1,206,479 10,756 678 (88,832) 166 (68,445) (88,832) 683 (113,415) 10,767 678 166 (68,445) $ 1,600 160,014,960 $ 3,424,624 $ (3,619) (5,006) $ (2,401,988) $ (83,673) (2,465) (7,052,769) (283,972) (3,619) $ 935,557 (2,465) 1 89,988 712 10 1,020,756 11,326 4 357,148 3,397 (89,343) 28,217 3,159 863 (89,343) 713 (80,660) 11,336 3,401 28,217 3,159 863 Balance at December 31, 2018 Treasury stock purchased Cash dividends ($0.554 per common share) Shares issued in ESPP Stock-based compensation, net of forfeitures Shares issued for Elite Acquisition Comprehensive income Net income Interest rate swap loss, net of reclassifications to earnings Balance at December 31, 2019 Treasury stock purchased Cash dividends ($0.580 per common share) Shares issued in ESPP Stock-based compensation, net of forfeitures Contribution from Exterran Corporation Impact of ASU 2016-13 adoption Comprehensive loss Net loss Interest rate swap loss, net of reclassifications to earnings Balance at December 31, 2020 Treasury stock purchased Cash dividends ($0.580 per common share) Shares issued under ESPP Stock-based compensation, net of forfeitures Net proceeds from issuance of common stock Comprehensive income Net income Interest rate swap gain, net of reclassifications to earnings Amortization of dedesignated interest rate swap Balance at December 31, 2021 $ 1,615 161,482,852 $ 3,440,059 $ (984) $ (2,463,114) $ (86,138) (7,417,401) $ 891,438 The accompanying notes are an integral part of these consolidated financial statements. F-6 Archrock, Inc. Consolidated Statements of Cash Flows (in thousands) Cash flows from operating activities: Net income (loss) Adjustments to reconcile net income (loss) to net cash provided by operating activities: Year Ended December 31, 2020 2021 2019 $ 28,217 $ (68,445) $ 97,330 Loss from discontinued operations, net of tax Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Inventory write-downs Amortization of operating lease ROU assets Amortization of deferred financing costs Amortization of debt discount Amortization of debt premium Amortization of dedesignated interest rate swap Debt extinguishment loss Interest rate swaps Stock-based compensation expense Non-cash restructuring charges Provision for credit losses (Gain) loss on sale of assets, net Gain on sale of business Deferred income tax provision (benefit) Amortization of contract costs Deferred revenue recognized in earnings Change in assets and liabilities, net of acquisition: Accounts receivable, trade Inventory Other assets Contract costs, net Accounts payable and other liabilities Deferred revenue Other Net cash provided by continuing operations Net cash used in discontinued operations Net cash provided by operating activities Cash flows from investing activities: Capital expenditures Proceeds from sale of business Proceeds from sale of property, plant and equipment and other assets Proceeds from insurance and other settlements Cash paid in Elite Acquisition Net cash provided by (used in) investing activities Cash flows from financing activities: Borrowings of long-term debt Repayments of long-term debt Payments for debt issuance costs F-7 — 178,946 21,397 — 997 3,880 10,127 — (2,006) 863 — 3,539 11,336 — (90) (11,313) (18,945) 10,379 19,990 (10,382) 4,445 (12,989) 635 (16,991) 5,269 10,217 (121) 237,400 — 237,400 (97,885) 83,345 29,562 1,085 — 16,107 — 193,138 79,556 99,830 1,349 3,477 5,554 187 (84) — 3,971 3,178 10,551 1,660 3,525 1,832 (12,475) (17,764) 26,629 (19,489) 36,395 3,972 (5,797) (13,262) (15,089) 12,732 147 335,278 — 335,278 (140,302) 33,651 18,911 2,709 — (85,031) 273 188,084 44,663 — 944 2,931 6,211 910 — — 3,653 (1,071) 8,105 — 2,567 (16,016) — (39,597) 23,330 (42,268) 3,248 6,036 4,458 (27,237) (12,728) 36,578 12 290,416 (269) 290,147 (385,198) — 80,961 3,696 (214,019) (514,560) 704,751 (863,251) (2,451) 1,049,000 (1,204,375) (5,269) 2,395,250 (2,071,750) (22,426) Proceeds from (payments for) settlement of interest rate swaps that include financing elements Dividends paid to stockholders Net proceeds from issuance of common stock Proceeds from stock issued under ESPP Purchases of treasury stock Contribution from Exterran Corporation Net cash provided by (used in) financing activities Net increase (decrease) in cash and cash equivalents Cash and cash equivalents, beginning of period Cash and cash equivalents, end of period Supplemental disclosure of cash flow information: Interest paid Income taxes refunded (paid), net Supplemental disclosure of non-cash investing and financing transactions: Accrued capital expenditures Non-cash consideration received in July 2020 Disposition Issuance of Archrock common stock pursuant to Elite Acquisition, net of tax $ $ $ (4,390) (89,343) 3,401 713 (2,465) — (253,035) 472 1,097 1,569 (100,002) (247) $ $ (2,916) (88,832) — 683 (1,804) 678 (252,835) (2,588) 3,685 1,097 (99,797) (94) $ $ 1,180 (78,530) — 771 (2,007) — 222,488 (1,925) 5,610 3,685 (97,451) 1,973 7,641 — $ 1,624 5,762 $ 11,767 — — — 225,880 The accompanying notes are an integral part of these consolidated financial statements. F-8 ARCHROCK, INC. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS 1. Description of Business 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. and a leading supplier of aftermarket services to customers that own compression equipment in the U.S. We operate in two business segments: contract operations and aftermarket services. Our predominant segment, contract operations, primarily includes designing, sourcing, owning, installing, operating, servicing, repairing and maintaining our owned fleet of natural gas compression equipment to provide natural gas compression services to our customers. In our aftermarket services business, we sell parts and components and provide operations, maintenance, overhaul and reconfiguration services to customers who own compression equipment. 2. Basis of Presentation and Significant Accounting Policies Basis of Presentation Our Financial Statements include Archrock and its subsidiaries, all of which are wholly owned. All intercompany accounts and transactions have been eliminated in consolidation. Our Financial Statements are prepared in accordance with GAAP and the rules and regulations of the SEC. The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets, liabilities, revenues, expenses and disclosures of contingent assets and liabilities. Because of the inherent uncertainties in this process, actual future results could differ from those expected as of the reporting date. Management believes that the estimates and assumptions used are reasonable. Significant Accounting Policies Cash and Cash Equivalents We consider all highly-liquid investments purchased with an original maturity of three months or less to be cash equivalents. Revenue Recognition We recognize revenue when control of the promised goods or services is transferred to our customers, in an amount that reflects the consideration we are entitled to receive in exchange for those goods or services. Sales and usage-based taxes that are collected from the customer are excluded from revenue. Contract Operations Natural gas compression services. Natural gas compression services are generally satisfied over time, as the customer simultaneously receives and consumes the benefits provided by these services. Our performance obligation is a series in which the unit of service is one month, as the customer receives substantially the same benefit each month from the services regardless of the type of service activity performed, which may vary. If the transaction price is based on a fixed fee, revenue is recognized monthly on a straight-line basis over the period that we are providing services to the customer. Amounts invoiced to customers for costs associated with moving our compression assets to a customer site are also included in the transaction price and are amortized over the initial contract term. We do not consider the effects of the time value of money, as the expected time between the transfer of services and payment for such services is less than one year. F-9 Variable consideration exists if customers are billed at a lesser standby rate when a unit is not running. We recognize revenue for such variable consideration monthly, as the invoice corresponds directly to the value transferred to the customer based on our performance completed to date. The rate for standby service is lower to reflect the decrease in costs and effort required to provide standby service when a unit is not running. Billable Maintenance Service. We perform billable maintenance service on our natural gas compression equipment at the customer’s request on an as-needed basis. The performance obligation is satisfied and revenue is recognized at the agreed- upon transaction price at the point in time when service is complete and the customer has accepted the work performed and can obtain the remaining benefits of the service that the unit will provide. Aftermarket Services OTC Parts and Components Sales. For sales of OTC parts and components, the performance obligation is generally satisfied at the point in time when delivery takes place and the customer obtains control of the part or component. The transaction price is the fixed sales price for the part stated in the contract. Revenue is recognized upon delivery, as we have a present right to payment and the customer has legal title. Maintenance, Overhaul and Reconfiguration Services. For our service activities, the performance obligation is satisfied over time, as the work performed enhances the customer-controlled asset and another entity would not have to substantially re-perform the work we completed if they were to fulfill the remaining performance obligation. The transaction price may be a fixed monthly service fee, a fixed quoted fee or entirely variable, calculated on a time and materials basis. For service provided based on a fixed monthly fee, the performance obligation is a series in which the unit of service is one month. The customer receives substantially the same benefit each month from the service, regardless of the type of service activity performed, which may vary. As the progress towards satisfaction of the performance obligation is measured based on the passage of time, revenue is recognized monthly based on the fixed fee provided for in the contract. For service provided based on a quoted fixed fee, progress towards satisfaction of the performance obligation is measured using an input method based on the actual amount of labor and material costs incurred. The amount of the transaction price recognized as revenue each reporting period is determined by multiplying the transaction price by the ratio of actual costs incurred to date to total estimated costs expected for the service. Significant judgment is involved in the estimation of the progress to completion. Any adjustments to the measure of the progress to completion is accounted for on a prospective basis. Changes to the scope of service is recognized as an adjustment to the transaction price in the period in which the change occurs. Service provided based on time and materials is generally short-term in nature and labor rates and parts pricing is agreed upon prior to commencing the service. We apply an estimated gross margin percentage, which is fixed based on historical time and materials-based service, to actual costs incurred. We evaluate the estimated gross margin percentage at the end of each reporting period and adjust the transaction price as appropriate. Contract Assets and Liabilities We recognize a contract asset when we have the right to consideration in exchange for goods or services transferred to a customer when the right is conditioned on something other than the passage of time. We recognize a contract liability when we have an obligation to transfer goods or services to a customer for which we have already received consideration. F-10 Concentrations of Credit Risk Financial instruments that potentially subject us to concentrations of credit risk consist of cash and cash equivalents and trade accounts receivable. Our temporary cash investments have a zero-loss expectation because we maintain minimal balances in our cash investment accounts and have no history of loss. Trade accounts receivable are due from companies of varying size engaged principally in oil and natural gas activities throughout the U.S. We review the financial condition of customers prior to extending credit and generally do not obtain collateral for trade receivables. Payment terms are on a short-term basis and in accordance with industry practice. We consider this credit risk to be limited due to these companies’ financial resources, the nature of the products and services we provide and the terms of our customer agreements. Due to the short-term nature of our trade receivables, we consider the amortized cost to be the same as the carrying amount of the receivable, excluding the allowance for credit losses. We recognize an allowance for credit losses when a receivable is recorded, even when the risk of loss is remote. We utilize an aging schedule to determine our allowance for credit losses, and measure expected credit losses on a collective (pool) basis when similar risk characteristics exist. We rely primarily on ratings assigned by external rating agencies and credit monitoring services to assess credit risk and aggregate customers first by low, medium or high risk asset pools, and then by delinquency status. We also consider the internal risk associated with geographic location and the services we provide to the customer when determining asset pools. If a customer does not share similar risk characteristics with other customers, we evaluate the customer’s outstanding trade receivables for expected credit losses on an individual basis. Trade receivables evaluated individually are not included in our collective assessment. Each reporting period, we reassess our customers’ risk profiles and determine the appropriate asset pool classification, or perform individual assessments of expected credit losses, based on the customers’ risk characteristics at the reporting date. The contractual life of our trade receivables is primarily 30 days based on the payment terms specified in the contract. Contract operations services are generally billed monthly at the beginning of the month in which service is being provided. Aftermarket services billings typically occur when parts are delivered or service is completed. Loss rates are separately determined for each asset pool based on the length of time a trade receivable has been outstanding. We analyze two years of internal historical loss data, including the effects of prepayments, write-offs and subsequent recoveries, to determine our historical loss experience. Our historical loss information is a relevant data point for estimating credit losses, as the data closely aligns with trade receivables due from our customers. Ratings assigned by external rating agencies and credit monitoring services consider past performance and forecasts of future economic conditions in assessing credit risk. We routinely update our historical loss data to reflect our customers’ current risk profile, to ensure the historical data and loss rates are relevant to the pool of assets for which we are estimating expected credit losses. At both December 31, 2021 and 2020, Chevron U.S.A. Inc. and Williams Partners accounted for 14% and 10% of our trade accounts receivable balance, respectively. The following table summarizes the activity in our allowance for credit losses: (in thousands) Balance at beginning of period Impact of adoption of ASU 2016-13 on January 1, 2020 Provision for credit losses Write-offs charged against allowance Balance at end of period Year Ended December 31, 2020 2019 2021 $ $ 3,370 $ — (90) (1,128) 2,152 $ 2,210 $ (216) 3,525 (2,149) 3,370 $ 1,452 — 2,567 (1,809) 2,210 Inventory Inventory consists of parts used for maintenance of natural gas compression equipment. Inventory is stated at the lower of cost and net realizable value using the average cost method. F-11 Property, Plant and Equipment Property, plant and equipment are recorded at cost and depreciated using the straight-line method over their estimated useful lives as follows: Compression equipment, facilities and other fleet assets Buildings Transportation and shop equipment Computer hardware and software Other 3 to 30 years 20 to 35 years 3 to 10 years 3 to 5 years 3 to 10 years Major improvements that extend the useful life of an asset are capitalized and depreciated over the estimated useful life of the major improvement, up to seven years. Repairs and maintenance are expensed as incurred. Long-Lived Assets We review long-lived assets, including property, plant and equipment and identifiable intangibles 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 exists when estimated undiscounted cash flows expected from the use of the asset and its eventual disposition are less than its carrying amount. Impairment losses are recognized in the period in which the impairment occurs and represent the excess of the asset carrying value over its fair value. Identifiable intangibles are amortized over the estimated useful life of the asset. Leases We determine if an arrangement is a lease at inception and determine lease classification and recognize ROU assets and liabilities on the lease commencement date based on the present value of lease payments over the lease term. As the discount rate implicit in the lease is rarely readily determinable, we estimate our incremental borrowing rate using information available at commencement date in determining the present value of the lease payments. The lease term includes options to extend when we are reasonably certain to exercise the option. Short-term leases, those with an initial term of 12 months or less, are not recorded on the balance sheet. Variable costs such as our proportionate share of actual costs for utilities, common area maintenance, property taxes and insurance are not included in the lease liability and are recognized in the period in which they are incurred. Operating lease expense for lease payments is recognized on a straight- line basis over the term of the lease. Our facility leases, of which we are the lessee, contain lease and nonlease components, which we have elected to account for as a single lease component, as the nonlease components are not significant to the total consideration of the contract and separating the nonlease component would have no effect on lease classification. As it relates to our contract operations service agreements in which we are a lessor, the services nonlease component is predominant over the compression package lease component and therefore recognition of these agreements follows the Accounting Standards Codification Topic 606 Revenue from Contracts with Customers guidance. Goodwill The goodwill acquired in connection with the Elite Acquisition represented the excess of consideration transferred over the fair value of the assets and liabilities acquired. We review the carrying amount of our goodwill in the fourth quarter of every year, or whenever indicators of potential impairment exist, to determine if the carrying amount of a reporting unit exceeds its fair value, including the applicable goodwill. We perform a qualitative assessment to determine whether it is more likely than not that the fair value of a reporting unit is impaired. If the fair value is more likely than not impaired, we perform a quantitative impairment test to identify impairment and measure the amount of impairment loss to be recognized, if any. F-12 Our qualitative assessment includes consideration of various events and circumstances and their potential impact to a reporting unit’s fair value, including macroeconomic and industry conditions such as a deterioration in our operating environment and limitations on access to capital and other developments in the equity and credit markets, cost factors that could have a negative effect on earnings and cash flows, relevant entity-specific and reporting unit-specific events and overall financial performance such as declining earnings or cash flows or a sustained decrease in share price. The quantitative impairment test (i) allocates goodwill and our other assets and liabilities to our reporting units, contract operations and aftermarket services, (ii) calculates the fair value of the reporting units and (iii) determines the impairment loss, if any, as the amount by which the carrying amount of the reporting unit exceeds its fair value (limited to the total amount of goodwill allocated to that reporting unit). All of the goodwill recognized in the Elite Acquisition was allocated to our contract operations reporting unit. The fair value of the contract operations reporting unit is calculated using the expected present value of future cash flows method. Significant estimates are made to determine future cash flows including future revenues, costs and capital requirements and the appropriate risk-adjusted discount rate by which to discount the estimated future cash flows. In the first quarter of 2020, the global response to the COVID-19 pandemic significantly impacted our market capitalization and estimates of future revenues and cash flows, which triggered the need to perform a quantitative test of the fair value of our contract operations reporting unit as of March 31, 2020. The quantitative test determined that the carrying amount of our contract operations reporting unit exceeded its fair value and we recorded a full impairment loss on goodwill as a result. Internal-Use Software Certain of our contracts have been deemed to be hosting arrangements that are service contracts, including those related to the cloud migration of our ERP system and cloud services for our new mobile workforce, telematics and inventory management tools. Certain costs incurred for the implementation of a hosting arrangement that is a service contract are capitalized and amortized on a straight-line basis over the term of the respective contract. Amortization begins for each component of the hosting arrangement when the component becomes ready for its intended use. Capitalized implementation costs are presented in other assets, the same line item in our consolidated balance sheets that a prepayment of the fees for the associated hosting arrangement would be presented. Amortization expense of the capitalized implementation costs is presented in SG&A, the same line item in our consolidated statements of operations as the expense for fees for the associated hosting arrangement. Income Taxes We account for income taxes under the asset and liability method, which requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events included in the financial statements. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial statements and the tax basis of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse. The effect of a change in tax rate on deferred tax assets and liabilities is recognized in income in the period of the enactment date. We record net deferred tax assets to the extent we believe these assets will more likely than not be realized. In making such a determination, we consider all available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax-planning strategies and results of recent operations. If a valuation allowance was previously recorded and we subsequently determined we would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we would make an adjustment to the deferred tax assets’ valuation allowance, which would reduce the provision for income taxes. We record uncertain tax positions in accordance with the accounting standard on income taxes under a two-step process whereby (1) we determine whether it is more likely than not that the tax positions will be sustained based on the technical merits of the position and (2) for those tax positions that meet the more-likely-than-not recognition threshold, we recognize the largest amount of tax benefit that is greater than 50 percent likely to be realized upon ultimate settlement with the related tax authority. F-13 Hedging and Use of Derivative Instruments We use derivative instruments to manage our exposure to fluctuations in the variable interest rate of our Credit Facility and thereby minimize the risks and costs associated with financial activities. We do not use derivative instruments for trading or other speculative purposes. We record interest rate swaps on the balance sheet as either derivative assets or derivative liabilities measured at their fair value. The fair value of our derivatives is based on the income approach (discounted cash flow) using market observable inputs, including LIBOR forward curves. Changes in the fair value of the derivatives designated as cash flow hedges are recognized as a component of other comprehensive income (loss) until the hedged transaction affects earnings. At that time, amounts are reclassified into earnings to interest expense, the same statement of operations line item to which the earnings effect of the hedged item is recorded. Cash flows from derivatives designated as hedges are classified in our consolidated statements of cash flows under the same category as the cash flows from the underlying assets, liabilities or anticipated transactions unless the derivative contract contains a significant financing element, in which case, the cash settlements for these derivatives are classified as cash flows from financing activities. To qualify for hedge accounting treatment, we must formally document, designate and assess the effectiveness of the transactions. We perform quarterly qualitative prospective and retrospective hedge effectiveness assessments unless facts and circumstances related to the hedging relationships change such that we can no longer assert qualitatively that the cash flow hedge relationships were and continue to be highly effective. If the necessary correlation ceases to exist or if the anticipated transaction is no longer probable, we would discontinue hedge accounting and apply mark-to-market accounting. Amounts paid or received from interest rate swap agreements are recorded in interest expense and matched with the cash flows and interest expense of the debt being hedged, resulting in an adjustment to the effective interest rate. 3. Recent Accounting Developments Accounting Standards Updates Implemented Reference Rate Reform In June 2021, we prospectively adopted ASU 2020-04, which provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions that reference LIBOR or another reference rate expected to be discontinued as a result of reference rate reform. ASU 2020-04 is effective for all entities as of March 12, 2020 through December 31, 2022. Entities may elect to apply the amendments for contract modifications as of any date from the beginning of an interim period that includes or is subsequent to March 12, 2020, or prospectively from a date within an interim period that includes or is subsequent to March 12, 2020. On June 10, 2021, we amended one of our interest rate swap agreements and determined that the modifications meet the criteria for the optional expedients and exceptions, which allow us to forego dedesignation of the hedging relationship and to subsequently assess effectiveness on a qualitative basis. The adoption of ASU 2020-04 did not have a material impact on our consolidated financial statements. In the first quarter, we evaluated Amendment No. 3 to our Credit Facility and determined that ASU 2020-04 was not applicable. We will continue to assess any modifications to our interest rate swap and Credit Facility agreements during the effective period of this update and will apply the amendments as applicable. 4. Business Transactions July 2021 Dispositions In July 2021, we completed sales of certain contract operations customer service agreements and approximately 575 compressors, comprising approximately 100,000 horsepower, used to provide compression services under those agreements, as well as other assets used to support the operations. We allocated customer-related and contract-based intangible assets based on a ratio of the horsepower sold relative to the total horsepower of the asset group. We received cash consideration of $60.3 million for the sales and recorded gains on the sales of $13.0 million in gain on sale of assets, net in our consolidated statements of operations during the year ended December 31, 2021. F-14 February 2021 Disposition In February 2021, we completed the sale of certain contract operations customer service agreements and approximately 300 compressors, comprising approximately 40,000 horsepower, used to provide compression services under those agreements as well as other assets used to support the operations. We allocated customer-related and contract-based intangible assets based on a ratio of the horsepower sold relative to the total horsepower of the asset group. We recorded a gain on the sale of $6.0 million in gain on sale of assets, net in our consolidated statements of operations during the year ended December 31, 2021. July 2020 Disposition In July 2020, we completed the sale of the turbocharger business included within our aftermarket services segment. In connection with the sale, we entered into a supply agreement to purchase a minimum amount of turbocharger goods and services over a two-year term. In addition to cash of $9.5 million received upon closing, an additional $3.0 million was received on the first anniversary of the closing date in July 2021, and $3.5 million was received through the purchase of turbocharger goods and services under the supply agreement, including $2.8 million that was received during the year ended December 31, 2021. We recognized a gain on the sale of $9.3 million in gain on sale of assets, net in our consolidated statements of operations during the year ended December 31, 2020. March 2020 Disposition In March 2020, we completed the sale of certain contract operations customer service agreements and approximately 200 compressors, comprising approximately 35,000 horsepower, used to provide compression services under those agreements as well as other assets used to support the operations. We allocated customer-related and contract-based intangible assets and goodwill based on a ratio of the horsepower sold relative to the total horsepower of the asset group. We recognized a gain on the sale of $3.2 million in gain on sale of assets, net in our consolidated statements of operations during the year ended December 31, 2020. Elite Acquisition In August 2019, we completed the Elite Acquisition whereby we acquired from Elite Compression substantially all of its assets, including a fleet of predominantly large compressors comprising approximately 430,000 horsepower, vehicles, real property and inventory, and certain liabilities for aggregate consideration consisting of $214.0 million in cash and 21.7 million shares of common stock with an acquisition date fair value of $225.9 million. The cash portion of the acquisition was funded with borrowings under the Credit Facility. The Elite Acquisition was accounted for using the acquisition method, which requires, among other things, assets acquired and liabilities assumed to be recorded at their fair value on the acquisition date. The excess of the consideration transferred over those fair values was recorded as goodwill. Our valuation methodology and significant inputs for fair value measurements are detailed by asset class below. The fair value measurements for property, plant and equipment and intangible assets were based on significant inputs that are not observable in the market and therefore represent Level 3 measurements. Goodwill The goodwill resulting from the acquisition was attributable to the expansion of our services in various regions in which we currently operate and was allocated to our contract operations segment. The goodwill had an indefinite life that was to be reviewed annually for impairment or more frequently if indicators of potential impairment existed. All of the goodwill recorded for this acquisition is expected to be deductible for U.S. federal income tax purposes. See Note 9 (“Goodwill”) for details on the 2020 impairment of our goodwill. F-15 Property, Plant and Equipment The property, plant and equipment is primarily comprised of compression equipment that will be depreciated on a straight- line basis over an estimated average remaining useful life of 15 years. The fair value of the property, plant and equipment was determined using the cost approach, whereby we estimated the replacement cost of the assets by evaluating recent purchases of similar assets or published data, and then adjusted replacement cost for physical deterioration and functional and economic obsolescence, as applicable. Intangible Assets The intangible assets consist of customer relationships that have an estimated useful life of 15 years. The amount of intangible assets and their associated useful life were determined based on the period over which the assets are expected to contribute directly or indirectly to our future cash flows. The fair value of the identifiable intangible assets was determined using the multi-period excess earnings method, which is a specific application of the discounted cash flow method, an income approach, whereby we estimated and then discounted the future cash flows of the intangible asset by adjusting overall business revenue for attrition, obsolescence, cost of sales, operating expenses, taxes and the required returns attributable to other contributory assets acquired. Significant estimates made in arriving at expected future cash flows included our expected customer attrition rate and the amount of earnings attributable to the assets. To discount the estimated future cash flows, we utilized a discount rate that was at a premium to our weighted average cost of capital to reflect the less liquid nature of the customer relationships relative to the tangible assets acquired. Unaudited Pro Forma Financial Information Unaudited pro forma financial information for the year ended December 31, 2019 was derived by adjusting our historical financial statements in order to give effect to the assets and liabilities acquired in the Elite Acquisition. The Elite Acquisition is presented in this unaudited pro forma financial information as though the acquisition occurred as of January 1, 2018, and reflects the following: • the acquisition of substantially all of Elite Compression’s assets, including a compression fleet of approximately 430,000 horsepower, vehicles, real property and inventory, and certain liabilities; • borrowings of $214.0 million under the Credit Facility for cash consideration exchanged in the acquisition; and • the exclusion of $7.8 million of financial advisory, legal and other professional fees incurred related to the acquisition and recorded to transaction-related costs in our consolidated statements of operations during the year ended December 31, 2019. The unaudited pro forma financial information below is presented for informational purposes only and is not necessarily indicative of our results of operations that would have occurred had the transaction been consummated at the beginning of the period presented, nor is it necessarily indicative of future results. (in thousands) Revenue Net income attributable to Archrock stockholders Year Ended December 31, 2019 1,009,763 106,521 $ The results of operations attributable to the assets and liabilities acquired in the Elite Acquisition have been included in our consolidated financial statements as part of our contract operations segment since the date of acquisition. Revenue attributable to the assets acquired from the date of acquisition, August 1, 2019, through December 31, 2019 was $33.2 million. We are unable to provide earnings attributable to the assets and liabilities acquired since the date of acquisition as we do not prepare full stand-alone earnings reports for those assets and liabilities. F-16 Harvest Sale In August 2019, we completed an asset sale in which Harvest acquired from us approximately 80,000 active and idle compression horsepower, vehicles and parts inventory for cash consideration of $30.0 million. We recorded a $6.6 million gain on this sale to gain on sale of assets, net in our consolidated statements of operations during the year ended December 31, 2019. The assets were previously reported under our contract operations segment. 5. Discontinued Operations We completed the Spin-off in 2015. In order to effect the Spin-off and govern our relationship with Exterran Corporation after the Spin-off, we entered into several agreements with Exterran Corporation, including a tax matters agreement, which governs the respective rights, responsibilities and obligations of Exterran Corporation and us with respect to certain tax matters. As of both December 31, 2021 and 2020, we had $7.9 million of unrecognized tax benefits (including interest and penalties) related to Exterran Corporation operations prior to the Spin-off recorded to noncurrent liabilities associated with discontinued operations in our consolidated balance sheets. We had an offsetting indemnification asset of $7.9 million related to these unrecognized tax benefits recorded to noncurrent assets associated with discontinued operations as of both December 31, 2021 and 2020. The following table presents the balance sheets for our discontinued operations: (in thousands) Other assets Deferred tax assets Total assets associated with discontinued operations Deferred tax liabilities Total liabilities associated with discontinued operations December 31, 2021 2020 7,868 1,943 9,811 7,868 7,868 $ $ $ $ 7,868 3,168 11,036 7,868 7,868 $ $ $ $ The following table presents the statements of operations for our discontinued operations: (in thousands) Other (income) expense, net Provision for (benefit from) income taxes Loss from discontinued operations, net of tax Year Ended December 31, 2020 2021 2019 $ $ — $ — — $ 640 $ (640) — $ (1,473) 1,746 (273) 6. Inventory (in thousands) Parts and supplies Work in progress Inventory December 31, 2021 2020 $ $ 63,628 9,241 72,869 $ $ 57,433 6,237 63,670 During the years ended December 31, 2021, 2020 and 2019, we recorded write-downs to inventory of $1.0 million, $1.3 million and $0.9 million, respectively, for inventory considered to be excess, obsolete or carried at an amount in excess of net realizable value. F-17 7. Property, Plant and Equipment, net (in thousands) Compression equipment, facilities and other fleet assets Land and buildings Transportation and shop equipment Computer hardware and software Other Property, plant and equipment Accumulated depreciation Property, plant and equipment, net December 31, 2021 3,273,770 43,540 92,490 76,908 6,229 3,492,937 (1,266,411) 2,226,526 $ $ 2020 3,439,432 45,167 106,868 84,680 14,457 3,690,604 (1,300,930) 2,389,674 $ $ Depreciation expense was $167.6 million, $177.5 million and $172.8 million during the years ended December 31, 2021, 2020 and 2019, respectively. Assets under construction of $30.1 million and $17.6 million at December 31, 2021 and 2020, respectively, primarily consisted of compression equipment, facilities and other fleet assets. 8. Leases We have operating leases and subleases for office space, temporary housing, storage and shops. Our leases have remaining lease terms of less than one year to approximately nine years and most include options to extend the lease term, at our discretion, for an additional six months to ten years. We are not, however, reasonably certain that we will exercise any of the options to extend and as such, they have not been included in the remaining lease terms. Financial and other supplemental information related to our operating leases follows. (in thousands) ROU assets Lease liabilities Current Noncurrent Total lease liabilities (in thousands) Operating lease cost Short-term lease cost Variable lease cost Total lease cost Classification Operating lease ROU assets December 31, 2021 2020 $ 17,491 $ 19,236 Accrued liabilities Operating lease liabilities $ $ 2,940 $ 15,940 18,880 $ 3,564 16,925 20,489 Year Ended December 31, 2020 2021 2019 $ $ 4,836 $ 169 2,123 7,128 $ 4,508 $ 52 1,652 6,212 $ 3,966 348 1,607 5,921 Year Ended December 31, 2020 2021 2019 $ 6,568 $ 5,885 $ 5,420 2,135 4,812 2,247 (in thousands) Operating cash flows - cash paid for amounts included in the measurement of operating lease liabilities Operating lease ROU assets obtained in exchange for lease liabilities, net (1) (1) Includes decreases to our ROU assets of $0.3 million and $0.1 million related to lease amendments and terminations during the years ended December 31, 2021 and 2020, respectively. F-18 Weighted average remaining lease term (in years) Weighted average discount rate 2021 7.2 4.6 % December 31, 2020 7.9 4.8 % 2019 8.2 5.3 % Remaining maturities of our lease liabilities as of December 31, 2021 were as follows: (in thousands) 2022 2023 2024 2025 2026 Thereafter Total lease payments Less: Interest Total lease liabilities 9. Goodwill $ $ 3,454 3,453 2,998 2,575 2,321 7,628 22,429 (3,549) 18,880 We recognized goodwill in connection with the Elite Acquisition, which represented the excess of consideration transferred over the fair value of the assets and liabilities acquired. All of the goodwill was allocated to our contract operations reporting unit. Beginning in the first quarter of 2020, the COVID-19 pandemic caused a significant deterioration in global macroeconomic conditions, which commenced substantial spending cuts by our customers and a decline in production. This global response to the pandemic significantly impacted our market capitalization and estimates of future revenues and cash flows, which triggered the need to perform a quantitative test of the fair value of our contract operations reporting unit as of March 31, 2020. The quantitative test determined that the carrying amount of our contract operations reporting unit exceeded its fair value and we recorded a goodwill impairment loss of $99.8 million during the first quarter of 2020. Determining the fair value of a reporting unit is judgmental in nature and involves the use of significant estimates and assumptions, which have a significant impact on the fair value determined. We determined the fair value of our reporting unit using an equal weighting of both the expected present value of future cash flows and a market approach. The present value of future cash flows was estimated using our most recent forecast and the weighted average cost of capital. The market approach used a market multiple on the earnings before interest expense, provision for income taxes and depreciation and amortization expense of comparable peer companies. Significant estimates for our reporting unit included in our impairment analysis were our cash flow forecasts, our estimate of the market’s weighted average cost of capital and market multiples. 10. Intangible Assets, net Intangible assets include customer relationships and contracts associated with various business and asset acquisitions. These acquired intangible assets were recorded at fair value determined as of the acquisition date and are being amortized over the period we expect to benefit from the assets. Intangible assets, net consisted of the following: December 31, 2021 December 31, 2020 Gross Gross (in thousands) Customer-related (15 ― 25 year life) Contract-based (5 ― 7 year life) Intangible assets Carrying Accumulated Carrying Accumulated Amortization Amount (86,512) $ (36,856) (123,368) Amortization Amount (96,435) $ — (96,435) $ 144,322 $ — 144,322 $ 147,169 $ 184,899 $ 37,730 $ F-19 Amortization expense of these intangible assets totaled $11.3 million, $15.6 million and $15.3 million during the years ended December 31, 2021, 2020 and 2019, respectively. Estimated future intangible assets amortization expense as of December 31, 2021 was as follows: (in thousands) 2022 2023 2024 2025 2026 Thereafter Total 11. Contract Costs $ $ 8,913 7,060 5,895 3,763 3,179 19,077 47,887 We capitalize incremental costs to obtain a contract with a customer if we expect to recover those costs. Capitalized costs include commissions paid to our sales force to obtain contract operations contracts. We expense commissions paid for sales of service contracts and OTC parts and components within our aftermarket services segment, as the amortization period is less than one year. We had contract costs of $2.6 million and $3.2 million associated with sales commissions recorded in our consolidated balance sheets at December 31, 2021 and 2020, respectively. We capitalize costs incurred to fulfill a contract if those costs relate directly to a contract, enhance resources that we will use in satisfying performance obligations and if we expect to recover those costs. Capitalized costs incurred to fulfill our customer contracts include freight charges to transport compression assets before transferring services to the customer and mobilization activities associated with our contract operations services. Aftermarket services fulfillment costs are recognized based on the percentage-of-completion method applicable to the customer contract and do not typically result in the recognition of contract costs. We had contract costs of $22.8 million and $26.0 million associated with freight and mobilization recorded in our consolidated balance sheets at December 31, 2021 and 2020, respectively. Contract operations obtainment and fulfillment costs are amortized based on the transfer of service to which the assets relate, which is estimated to be 38 months based on average contract term, including anticipated renewals. We assess periodically whether the 38-month estimate fairly represents the average contract term and adjust as appropriate. Contract costs associated with commissions are amortized to SG&A. Contract costs associated with freight and mobilization are amortized to cost of sales (excluding depreciation and amortization). During the years ended December 31, 2021, 2020 and 2019, we amortized $2.2 million, $3.0 million and $2.6 million, respectively, related to sales commissions and $17.8 million, $23.6 million and $20.7 million, respectively, related to freight and mobilization. 12. Hosting Arrangements In the fourth quarter of 2018, we began 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. Included in this project are hosting arrangements that are service contracts related to the cloud migration of our ERP system and cloud services for our new mobile workforce, telematics and inventory management tools. As of December 31, 2021 and 2020, we had $12.7 million and $7.7 million, respectively, of capitalized implementation costs related to our hosting arrangements that are service contracts included in other assets in our consolidated balance sheets. Accumulated amortization was $0.7 million and $0.3 million at December 31, 2021 and 2020, respectively. We recorded $0.3 million of amortization expense to SG&A in our consolidated statements of operations during each of the years ended December 31, 2021 and 2020. F-20 During the year ended December 31, 2020, we impaired $1.6 million of capitalized implementation costs related to the hosting arrangements of the mobile workforce component of our project due to the termination of the agreement, which was included in long-lived and other asset impairment in our consolidated statements of operations. 13. Accrued Liabilities (in thousands) Accrued salaries and other benefits Accrued income and other taxes Accrued interest Derivative liability - current Other accrued liabilities Accrued liabilities 14. Long-Term Debt (in thousands) Credit Facility 2028 Notes Principal Debt premium, net of amortization Deferred financing costs, net of amortization 2027 Notes Principal Deferred financing costs, net of amortization Long-term debt Credit Facility December 31, 2021 2020 $ $ 20,891 $ 9,957 22,368 1,250 28,051 82,517 $ 16,332 11,414 22,693 4,809 21,745 76,993 December 31, 2021 2020 $ 234,500 $ 393,000 800,000 12,536 (10,406) 802,130 500,000 (5,805) 494,195 800,000 14,541 (11,766) 802,775 500,000 (6,908) 493,092 $ 1,530,825 $ 1,688,867 As of December 31, 2021, there were $8.9 million letters of credit outstanding under the Credit Facility and the applicable margin on borrowings outstanding was 2.4%. The weighted average annual interest rate on the outstanding balance under the Credit Facility, excluding the effect of interest rate swaps, was 2.6% and 2.7% at December 31, 2021 and 2020, respectively. As a result of the facility’s ratio requirements (see below), $502.5 million of the $506.6 million of undrawn capacity was available for additional borrowings as of December 31, 2021. We were in compliance with all other covenants under our Credit Facility agreement. Amendments to the Credit Facility Amendment No. 3 In February 2021, we amended our Credit Facility to, among other things, reduce the aggregate revolving commitment from $1.25 billion to $750.0 million and adjust the maximum Senior Secured Debt to EBITDA and Total Debt to EBITDA ratios, as defined in the Credit Facility agreement, to those listed in the table below. F-21 We incurred $1.8 million in transaction costs related to Amendment No. 3, which were included in other assets in our consolidated balance sheets and are being amortized over the remaining term of the Credit Facility. In addition, we wrote off $4.9 million of unamortized deferred financing costs as a result of the amendment, which was recorded to interest expense in our consolidated statements of operations during the year ended December 31, 2021. Amendment No. 2 In November 2019, we amended the Credit Facility to, among other things, extend the maturity date of the Credit Facility from March 30, 2022 to November 8, 2024 and change the applicable margin for borrowings to those discussed in “Other Facility Terms” below. We incurred $6.4 million in transaction costs related to Amendment No. 2, which were included in other assets in our consolidated balance sheets and are being amortized over the remaining term of the Credit Facility. Other Facility Terms 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. Portions of the Credit Facility up to $50.0 million are available for the issuance of swing line loans and $50.0 million is available for the issuance of letters of credit. The Credit Facility bears interest at a base rate or LIBOR, at our option, plus an applicable margin. Depending on our leverage ratio, the applicable margin varies (i) in the case of LIBOR loans, from 2.00% to 2.75% and (ii) in the case of base rate loans, from 1.00% to 1.75%. The base rate is the highest of (i) the prime rate announced by JPMorgan Chase Bank, (ii) the Federal Funds Effective Rate plus 0.50% and (iii) one-month LIBOR plus 1.00%. Additionally, we are required to pay commitment fees based on the daily unused amount of the Credit Facility at a rate of 0.375%. We incurred $2.0 million, $2.0 million and $1.9 million in commitment fees during the years ended December 31, 2021, 2020 and 2019, respectively. The Credit Facility borrowing base consists of eligible accounts receivable, inventory and compressors, the largest of which is compressors. Borrowings under the Credit Facility are secured by substantially all of our personal property assets and our Significant Domestic Subsidiaries (as defined in the Credit Facility agreement), including all of the membership interests of our Domestic Subsidiaries (as defined in the Credit Facility agreement). The Credit Facility agreement contains various covenants including, but not limited to, 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. The Credit Facility agreement also contains various covenants requiring mandatory prepayments from the net cash proceeds of certain asset transfers. As of December 31, 2021, the following consolidated financial ratios, as defined in our Credit Facility agreement, were required: EBITDA to Interest Expense Senior Secured Debt to EBITDA Total Debt to EBITDA Through fiscal year 2022 January 1, 2023 through September 30, 2023 Thereafter (1) 2.5 to 1.0 3.0 to 1.0 5.75 to 1.0 5.50 to 1.0 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. F-22 2028 Notes and 2027 Notes In December 2020, we completed a private offering of $300.0 million aggregate principal amount of 6.25% senior notes due April 2028, which were issued pursuant to the indenture under which we completed a private offering of $500.0 million aggregate principal amount of 6.25% senior notes in December 2019. The notes of the two offerings have identical terms and are treated as a single class of securities. The $300.0 million of notes were issued at 104.875% of their face value and have an effective interest rate of 5.6%. The $500.0 million of notes were issued at 100% of their face value and have an effective interest rate of 6.8%. We received net proceeds of $309.9 million, after deducting issuance costs of $4.7 million, from our December 2020 offering and net proceeds of $491.8 million, after deducting issuance costs of $8.2 million, from our December 2019 offering. In March 2019, we completed a private offering of $500.0 million aggregate principal amount of 6.875% senior notes due April 2027 and received net proceeds of $491.2 million after deducting issuance costs of $8.8 million. The $500.0 million of notes were issued at 100% of their face value and have an effective interest rate of 7.9%. The net proceeds from the 2027 Notes and 2028 Notes were used to repay borrowings outstanding under our Credit Facility. Issuance costs related to the 2027 Notes and 2028 Notes are considered deferred financing costs, and together with the issue premium of the December 2020 offering of 2028 Notes, are recorded within long-term debt in our consolidated balance sheets and are being amortized to interest expense in our consolidated statements of operations over the terms of the notes. The 2027 Notes and 2028 Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by us and all of our existing subsidiaries, other than Archrock Partners, L.P. and Archrock Partners Finance Corp., which are co-issuers of both offerings, and certain of our future subsidiaries. The 2027 Notes and 2028 Notes and the guarantees rank equally in right of payment with all of our and the guarantors’ existing and future senior indebtedness. The 2027 Notes and 2028 Notes may be redeemed at any time, in whole or in part, at specified redemption prices and make-whole premiums, plus any accrued and unpaid interest. 2022 Notes In April 2020, the 2022 Notes were redeemed at 100% of their $350.0 million aggregate principal amount plus accrued and unpaid interest of $10.5 million with borrowings under the Credit Facility. A debt extinguishment loss of $4.0 million related to the redemption was recognized during the year ended December 31, 2020. 2021 Notes In April 2019, the 2021 Notes were redeemed at 100% of their $350.0 million aggregate principal amount plus accrued and unpaid interest of $0.2 million with borrowings under the Credit Facility. We recorded a debt extinguishment loss of $3.7 million related to the redemption during the year ended December 31, 2019. Long-Term Debt Maturity Contractual maturities of long-term debt over the next five years, excluding interest to be accrued, as of December 31, 2021, were as follows: (in thousands) 2022 2023 2024 2025 2026 Long-term debt maturities through 2026 F-23 $ $ — — 234,500 — — 234,500 15. Accumulated Other Comprehensive Income (Loss) Components of comprehensive income (loss) are net income (loss) and all changes in equity during a period except those resulting from transactions with owners. Our accumulated other comprehensive income (loss) consists of changes in the fair value of our interest rate swap derivative instruments, net of tax. (in thousands) Beginning accumulated other comprehensive income (loss) Other comprehensive income (loss), net of tax: Year Ended December 31, 2020 2021 2019 $ (5,006) $ (1,387) $ 5,773 Loss recognized in other comprehensive income (loss), net of tax benefit of $257, $1,776 and $1,425, respectively (Gain) loss reclassified from accumulated other comprehensive income (loss) to interest expense, net of tax provision (benefit) of $(1,324), $(814) and $478, respectively Total other comprehensive income (loss) Ending accumulated other comprehensive loss $ (962) (6,683) (5,360) 4,984 4,022 (984) $ 3,064 (3,619) (5,006) $ (1,800) (7,160) (1,387) See Note 22 (“Derivatives”) for further details on our interest rate swap derivative instruments. 16. Equity At-the-Market Continuous Equity Offering Program In February 2021, we entered into the ATM Agreement, pursuant to which we may offer and sell shares of our common stock from time to time for an aggregate offering price of up to $50.0 million. We use the net proceeds of these offerings, after deducting sales agent fees and offering expenses, for general corporate purposes. Offerings of common stock pursuant to the ATM Agreement will terminate upon the earlier of (i) the sale of all shares of common stock subject to the ATM Agreement or (ii) the termination of the ATM Agreement by us or by each of the sales agents. Any sales agent may also terminate the ATM Agreement but only with respect to itself. During the year ended December 31, 2021, we sold 357,148 shares of common stock for net proceeds of $3.4 million pursuant to the ATM Agreement. Elite Acquisition In August 2019, we completed the Elite Acquisition. A portion of the acquisition’s purchase price was funded through the issuance of 21.7 million shares of common stock with an acquisition date fair value of $225.9 million, which was recorded to common stock and additional paid-in capital in our consolidated statements of equity. See Note 4 (“Business Transactions”) for further details of this acquisition. F-24  Cash Dividends The following table summarizes our dividends declared and paid in each of the quarterly periods of 2021, 2020 and 2019: 2021 Q4 Q3 Q2 Q1 2020 Q4 Q3 Q2 Q1 2019 Q4 Q3 Q2 Q1 Declared Dividends Dividends Paid per Common Share (in thousands) $ $ $ $ $ $ 0.145 0.145 0.145 0.145 0.145 0.145 0.145 0.145 0.145 0.145 0.132 0.132 22,351 22,506 22,331 22,155 22,177 22,308 22,176 22,171 22,031 22,062 17,206 17,231 On January 27, 2022, our Board of Directors declared a quarterly dividend of $0.145 per share of common stock, or approximately $22.6 million, which was paid on February 15, 2022 to stockholders of record at the close of business on February 8, 2022. F-25 17. Revenue from Contracts with Customers The following table presents our revenue from contracts with customers by segment (see Note 22 (“Segments”)) and disaggregated by revenue source: (in thousands) Contract operations: 0 ― 1,000 horsepower per unit 1,001 ― 1,500 horsepower per unit Over 1,500 horsepower per unit Other (1) Total contract operations revenue (2) Aftermarket services: Services (3) OTC parts and components sales Total aftermarket services revenue (4) Year Ended December 31, 2020 2021 2019 $ 175,457 $ 267,191 204,893 770 648,311 224,702 $ 305,185 206,749 2,282 738,918 69,876 63,274 133,150 79,012 57,040 136,052 259,985 316,082 191,510 3,962 771,539 122,076 71,870 193,946 Total revenue $ 781,461 $ 874,970 $ 965,485 (1) Primarily relates to fees associated with owned non-compression equipment. (2) Includes $4.0 million, $5.6 million and $7.9 million during the years ended December 31, 2021, 2020 and 2019, respectively, related to billable maintenance on owned compressors that was recognized at a point in time. All other contract operations revenue is recognized over time. (3) Includes a reversal of $0.9 million of revenue during the year ended December 31, 2019 related to changes in estimates of performance obligations partially satisfied in prior periods. (4) Services revenue within aftermarket services is recognized over time. OTC parts and components sales revenue is recognized at a point in time. Performance Obligations As of December 31, 2021, we had $264.6 million of remaining performance obligations related to our contract operations segment, which will be recognized through 2026 as follows: (in thousands) Remaining performance obligations 2022 2023 $ 209,241 $ 42,367 $ 11,747 $ 2024 2025 2026 Total 771 $ 471 $ 264,597 We do not disclose the aggregate transaction price for the remaining performance obligations for aftermarket services as there are no contracts with customers with an original contract term that is greater than one year. Contract Assets and Liabilities Contract Assets As of December 31, 2021 and 2020, our receivables from contracts with customers, net of allowance for credit losses, were $84.7 million and $95.6 million, respectively. Contract Liabilities Freight billings to customers for the transport of compression assets, customer-specified modifications of compression assets and milestone billings on aftermarket services often result in a contract liability. Our contract liabilities were $4.4 million and $4.6 million as of December 31, 2021 and 2020, respectively, and were included in deferred revenue and other liabilities in our consolidated balance sheets. During the year ended December 31, 2021, we deferred revenue of $10.2 million and recognized $10.4 million as revenue. The revenue recognized and deferred during the period primarily related to freight billings and milestone billings on aftermarket services. F-26 18. Long-Lived and Other Asset Impairment We review long-lived assets, including property, plant and equipment and identifiable intangibles 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. In the first quarter of 2020, we determined that the impairment of our contract operations reporting unit’s goodwill was an indicator of potential impairment of the carrying amount of our long-lived assets, including our compressor fleet and associated customer and contract-based intangible assets. Accordingly, we performed a quantitative impairment test of our long-lived assets, by which we determined that they were not also impaired. No similar impairment has been indicated subsequent to the first quarter of 2020. Compression Fleet We periodically review the future deployment of our idle compression assets for units that are not of the type, configuration, condition, make or model that are cost efficient to maintain and operate. Based on these reviews, we determine that certain idle compressors should be retired from the active fleet. The retirement of these units from the active fleet triggers a review of these assets for impairment and as a result of our review, we may record an asset impairment to reduce the book value of each unit to its estimated fair value. The fair value of each unit is estimated based on the expected net sale proceeds compared to other 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. In connection with our review of our idle compression assets, we evaluate for impairment idle units that were culled from our fleet in prior years and are available for sale. Based on that review, we may reduce the expected proceeds from disposition and record additional impairment to reduce the book value of each unit to its estimated fair value. The following table presents the results of our compression fleet impairment review as recorded to our contract operations segment: (dollars in thousands) Idle compressors retired from the active fleet Horsepower of idle compressors retired from the active fleet Impairment recorded on idle compressors retired from the active fleet Year Ended December 31, 2020 2021 230 85,000 730 261,000 2019 975 170,000 $ 21,208 $ 77,590 $ 44,663 Other Impairment During the year ended December 31, 2020, $1.7 million of capitalized implementation and unamortized prepaid costs related to the mobile workforce component of our process and technology transformation project was impaired. See Note 12 (“Hosting Arrangements”) for further details. 19. Restructuring Charges During the first quarter of 2020, we completed restructuring activities to further streamline our organization and more fully align our teams to improve our customer service and profitability. We incurred severance costs of $1.7 million related to these activities during the first quarter of 2020. No additional costs will be incurred for this organizational restructuring. In response to the decreased activity level of our customers that resulted from the COVID-19 pandemic beginning in the second quarter of 2020, we incurred severance costs of $7.0 million to right-size our business. No additional costs will be incurred under this restructuring plan. F-27 During the third quarter of 2020, a plan to dispose of certain non-core properties was approved by management. We have incurred $1.5 million of costs as a result of these property disposals. No additional costs will be incurred under this restructuring plan. During the third quarter of 2021, management approved and initiated a plan to exit a facility no longer deemed economical for our business, and in the fourth quarter, we incurred $0.9 million of costs to complete the exit of this facility. We do not expect to incur additional material costs under this restructuring plan. The severance and property disposal costs incurred under the above restructuring plans were recorded to restructuring charges in our consolidated statements of operations. The following table presents the changes to our accrued liability balance related to restructuring charges during the year ended December 31, 2021: Pandemic 2020 Property 2021 Property Other (in thousands) Balance at December 31, 2020 Charges incurred Payments Balance at December 31, 2021 201 $ Restructuring Restructuring Restructuring Restructuring — $ $ 35 (35) — $ 1,717 (1,918) 929 (929) 222 (222) — $ — $ — $ $ Total 201 2,903 (3,104) — — $ — $ The following table presents restructuring charges incurred by segment: (in thousands) Year ended December 31, 2021 Pandemic restructuring 2020 Property restructuring - other exit costs 2021 Property restructuring - other exit costs Other restructuring Total restructuring charges Year ended December 31, 2020 Organizational restructuring Pandemic restructuring 2020 Property restructuring Loss on sale Impairment loss Total 2020 Property restructuring Total restructuring charges Contract Aftermarket Operations Services Other (1) Total $ $ $ $ 616 — 929 — 1,545 $ $ 145 — — — 145 $ $ 956 35 — 222 1,213 $ $ 1,717 35 929 222 2,903 $ 458 2,505 $ 625 1,218 $ 612 1,534 1,695 5,257 — — — 2,963 $ — — — 1,843 $ 915 583 1,498 3,644 $ 915 583 1,498 8,450 (1) Represents expense incurred within our corporate function and not directly attributable to our segments. F-28 The following table presents restructuring charges incurred by cost type: (in thousands) Severance costs Organizational restructuring Pandemic restructuring Total severance costs Property disposal costs Loss on sale Impairment loss Other exit costs Total property disposal costs Other restructuring costs Total restructuring charges 20. Income Taxes Years Ended December 31, 2020 2021 $ $ — 1,717 1,717 — — 964 964 222 2,903 $ $ 1,695 5,257 6,952 915 583 — 1,498 — 8,450 Current and Deferred Tax Provision Our provision for (benefit from) income taxes consisted of the following: (in thousands) Current tax provision (benefit): U.S. federal State Total current Deferred tax provision (benefit): U.S. federal State Total deferred Provision for (benefit from) income taxes Year Ended December 31, 2020 2019 2021 $ $ $ (1) 366 365 $ (99) 326 227 8,800 1,579 10,379 10,744 $ (17,246) (518) (17,764) (17,537) $ 75 377 452 (35,597) (4,000) (39,597) (39,145) The provision for (benefit from) income taxes for the years ended December 31, 2021, 2020 and 2019 resulted in effective tax rates on continuing operations of 28%, 20% and (67)%, respectively. The following table reconciles these effective tax rates to the U.S. statutory rate of 21%, the rate in effect during the years ended December 31, 2021, 2020 and 2019: (in thousands) Income taxes at U.S. federal statutory rate Net state income taxes Tax credits Unrecognized tax benefits (1) Valuation allowances and write off of tax attributes (2) Executive compensation limitation Stock Other Provision for (benefit from) income taxes Year Ended December 31, 2020 2019 2021 8,182 $ 1,374 (720) 598 (167) 1,559 162 (244) 10,744 $ (18,056) $ (817) (1,256) 772 236 1,159 538 (113) (17,537) $ 12,276 1,634 (1,757) (1,958) (50,219) 1,102 66 (289) (39,145) $ $ (1) Includes the expiration of statute of limitations and in 2019, also reflects a decrease in our uncertain tax benefit, net of federal benefit, due to settlements of tax audits. See “Unrecognized Tax Benefits” below for further details. (2) See “Tax Attributes and Valuation Allowances” below for further details. F-29 Deferred income tax balances are the direct effect of temporary differences between the financial statement carrying amounts and the tax basis of assets and liabilities at the enacted tax rates expected to be in effect when the taxes are actually paid or recovered. The tax effects of temporary differences that gave rise to deferred tax assets and deferred tax liabilities were as follows: (in thousands) Deferred tax assets: Net operating loss carryforwards Accrued liabilities Other Valuation allowances (1) Total deferred tax assets Deferred tax liabilities: Property, plant and equipment Basis difference in the Partnership Other Total deferred tax liabilities Net deferred tax asset (2) December 31, 2021 2020 $ 196,654 4,527 12,503 213,684 (735) 212,949 158,916 3,133 12,124 174,173 (1,027) 173,146 (7,762) (151,469) (6,975) (166,206) 46,743 $ (6,066) (103,721) (7,150) (116,937) 56,209 $ $ (1) See “Tax Attributes and Valuation Allowances” below for further details. (2) The 2021 and 2020 net deferred tax assets are reflected in our consolidated balance sheets as deferred tax assets of $47.9 million and $56.9 million, respectively, and deferred tax liabilities of $1.1 million and $0.7 million, respectively. Both the 2021 and 2020 balances are based on a U.S. federal tax rate of 21%. Tax Attributes and Valuation Allowances (in thousands) Balance at beginning of period (1) Additions to valuation allowance Reductions to valuation allowance (1) Balance at end of period (1) In 2019, excludes $5.6 million related to discontinued operations. Year Ended December 31, 2020 2019 2021 $ $ (1,027) $ - 292 (735) $ (822) $ (205) - (1,027) $ (45,439) (580) 45,197 (822) Pursuant to Sections 382 and 383 of the Code, utilization of loss and credit carryforwards are subject to annual limitations due to any ownership changes of 5% stockholders. In general, an ownership change, as defined by Section 382, results from transactions increasing the ownership of certain stockholders or public groups in the stock of a corporation by more than 50% over a rolling three-year period. We do not currently expect that any loss carryforwards or credit carryforwards will expire as a result of any 382 or 383 limitations. Our ability to utilize loss carryforwards and credit carryforwards against future U.S. federal taxable income and future U.S. federal income tax may be limited in the future if we have a 50% or more ownership change in our 5% stockholders. We record valuation allowances when it is more likely than not that some portion or all of our deferred tax assets will not be realized. The ultimate realization of the deferred tax assets depends on the ability to generate sufficient taxable income of the appropriate character and in the appropriate taxing jurisdictions in the future. If we do not meet our expectations with respect to taxable income, we may not realize the full benefit from our deferred tax assets, which would require us to record a valuation allowance in our tax provision in future years. As of each reporting date, we consider new evidence to evaluate the realizability of our net deferred tax asset position by assessing the available positive and negative evidence. Changes to the valuation allowance are reflected in the statement of operations. F-30 As of December 31, 2019, we achieved a three-year cumulative book income, and together with other positive and negative evidence, we concluded that there was sufficient positive evidence of projected future taxable income to release the $50.8 million valuation allowance previously required for our overall net deferred tax asset position. This release was offset by a $0.6 million increase in the valuation allowance on our state NOL deferred tax asset. The overall impact of the change in the valuation allowance was recorded as a $50.2 million benefit from income taxes in our consolidated statements of operations and a $50.2 million increase in deferred tax assets in our consolidated balance sheets, of which $44.6 million and $5.6 million were recorded to continuing operations and discontinued operations, respectively. The amount of our deferred tax assets considered realizable could be adjusted if projections of future taxable income are reduced or objective negative evidence in the form of a three-year cumulative loss is present or both. Should we no longer have a level of sustained profitability, excluding nonrecurring charges, we will have to rely more on our future projections of taxable income to determine if we have an adequate source of taxable income for the realization of our deferred tax assets, namely NOL carryforwards and tax credit carryforwards. This may result in the need to record a valuation allowance against all or a portion of our deferred tax assets. At December 31, 2021, we had U.S. federal and state NOL carryforwards of $868.5 million and $317.1 million, respectively, included in our NOL deferred tax asset that are available to offset future taxable income. If not used, the federal and state NOL carryforwards will begin to expire in 2025 and 2022, respectively, though $629.5 million of the U.S. federal and $167.7 million of the state NOL carryforwards have no expiration date. In connection with the state NOL deferred tax asset, we recorded a valuation allowance of $0.7 million and $1.0 million as of December 31, 2021 and 2020, respectively. At December 31, 2021, we had U.S. federal and state tax credit carryforwards of $3.0 million and $0.1 million, respectively. If not used, the federal and state tax credit carryforwards will begin to expire in 2037 and 2041, respectively. Unrecognized Tax Benefits A reconciliation of the unrecognized tax benefit (including discontinued operations) activity is shown below: (in thousands) Beginning balance Additions based on tax positions related to current year Additions based on tax positions related to prior years Reductions based on settlement refunds from government authorities Reductions based on tax positions related to prior years Reductions based on lapse of statute of limitations Ending balance Year Ended December 31, 2020 2021 2019 18,892 $ 2,246 632 — (138) (2,038) 19,594 $ 18,453 $ 2,397 — — (73) (1,885) 18,892 $ 19,560 2,227 2,047 (4,414) (51) (916) 18,453 $ $ We had $19.6 million, $18.9 million and $18.5 million of unrecognized tax benefits at December 31, 2021, 2020 and 2019, respectively, of which $2.1 million, $2.9 million and $3.2 million, respectively, would affect the effective tax rate if recognized and $7.9 million, $7.9 million and $8.3 million, respectively, would be reflected in income from discontinued operations, net of tax if recognized. We recorded $2.2 million, $2.1 million and $2.1 million of potential interest expense and penalties related to unrecognized tax benefits associated with uncertain tax positions (including discontinued operations) in our consolidated balance sheets as of the years ended December 31, 2021, 2020 and 2019, respectively. To the extent interest and penalties are not assessed with respect to uncertain tax positions, amounts accrued will be reduced and reflected as reductions in income tax expense. We recorded $0.1 million of potential interest expense and penalties in our consolidated statements of operations during the year ended December 31, 2021, and releases of $0.1 million during each of the years ended December 31, 2020 and 2019. F-31 Subject to the provisions of our tax matters agreement with Exterran Corporation, both parties agreed to indemnify the primary obligor of any return for tax periods beginning before and ending before or after the Spin-off (including any ongoing or future amendments and audits for these returns) for the portion of the tax liability (including interest and penalties) that relates to their respective operations reported in the filing. As of both December 31, 2021 and 2020, we recorded an indemnification asset (including penalties and interest) of $7.9 million, which is related to unrecognized tax benefits in our consolidated balance sheets. We and our subsidiaries file consolidated and separate income tax returns in the U.S. federal jurisdiction and in numerous state jurisdictions. U.S. federal income tax returns are generally subject to examination for up to three years after filing the returns. Due to our NOL carryforwards, our U.S. federal income tax returns can be examined back to the inception of our NOL carryforwards; therefore, expanding our examination period beyond 20 years. In 2020, the IRS completed their examination of our 2014 and 2015 tax years. Due to this audit being related to tax periods that commenced prior to the Spin-off, Exterran Corporation was also involved in the audit. The tax adjustments recorded from this audit did not have a material impact on our consolidated financial position or results of operations. State income tax returns are generally subject to examination for a period of three to five years after filing the returns. However, the state impact of any U.S. federal audit adjustments and amendments remains subject to examination by various states for up to one year after formal notification to the states. We are not currently involved in any state audits. During the year ended December 31, 2019, we settled certain state audits, which resulted in a refund of $2.4 million and a reduction in previously-accrued uncertain tax benefits of $4.4 million. As of December 31, 2021, we believe it is reasonably possible that $2.6 million of our unrecognized tax benefits, including penalties, interest and discontinued operations, will be reduced prior to December 31, 2022 due to the settlement of audits or the expiration of statutes of limitations or both. However, due to the uncertain and complex application of the tax regulations, it is possible that the ultimate resolution of these matters may result in liabilities that could materially differ from this estimate. CARES Act In March 2020, President Trump signed into law the CARES Act, which includes, among other things, refundable payroll tax credits, deferment of employer-side social security payments, NOL carryback periods, alternative minimum tax credit refunds, modifications to the net interest deduction limitations and technical corrections to tax depreciation methods for qualified improvement property. The CARES Act provisions did not have a material impact on our consolidated financial statements. Future regulatory guidance under the CARES Act or additional legislation enacted by Congress in connection with the COVID-19 pandemic could impact our tax provision in future periods. 21. Earnings per Share Basic net income (loss) per common share is computed using the two-class method, which is an earnings allocation formula that determines net income (loss) per share for each class of common stock and participating security according to dividends declared and participation rights in undistributed earnings. Under the two-class method, basic net income (loss) per common share is determined by dividing net income (loss), after deducting amounts allocated to participating securities, by the weighted average number of common shares outstanding for the period. Participating securities include unvested restricted stock and stock-settled restricted stock units that have nonforfeitable rights to receive dividends or dividend equivalents, whether paid or unpaid. During periods of net loss, only distributed earnings (dividends) are allocated to participating securities, as participating securities do not have a contractual obligation to participate in our undistributed losses. Diluted net income (loss) per common share is computed using the weighted average number of shares outstanding adjusted for the incremental common stock equivalents attributed to outstanding options, performance-based restricted stock units and stock to be issued pursuant to our ESPP unless their effect would be anti-dilutive. F-32 The following table shows the calculation for net income (loss) attributable to common stockholders, which is used in the calculation of basic and diluted net income (loss) per common share: (in thousands) Income (loss) from continuing operations Loss from discontinued operations, net of tax Net income (loss) Less: Earnings attributable to participating securities Net income (loss) attributable to common stockholders Year Ended December 31, 2020 2021 2019 28,217 $ — 28,217 (1,172) 27,045 $ (68,445) $ — (68,445) (1,338) (69,783) $ 97,603 (273) 97,330 (1,348) 95,982 $ $ The following table shows the potential shares of common stock that were included in computing diluted net income (loss) per common share: (in thousands) Weighted average common shares outstanding including participating securities Less: Weighted average participating securities outstanding Weighted average common shares outstanding used in basic net income (loss) per common share Net dilutive potential common shares issuable: On exercise of options and vesting of performance-based restricted stock units On settlement of ESPP shares Weighted average common shares outstanding used in diluted net income (loss) per common share Year Ended December 31, 2020 2021 2019 153,484 (1,800) 152,827 (1,999) 139,317 (1,825) 151,684 150,828 137,492 144 2 — — 34 2 151,830 150,828 137,528 The following table shows the potential shares of common stock issuable that were excluded from computing diluted net income (loss) per common share as their inclusion would have been anti-dilutive: (in thousands) On exercise of options where exercise price is greater than average market value for the period On exercise of options and vesting of performance-based restricted stock units On settlement of ESPP shares Net dilutive potential common shares issuable 22. Derivatives Year Ended December 31, 2020 2021 2019 31 — — 31 96 54 17 167 154 — — 154 We use derivative instruments to manage our exposure to fluctuations in the variable interest rate of our Credit Facility. As of December 31, 2021, we had $300.0 million notional value of interest rate swaps outstanding, which expire in March 2022. We entered into these swaps to offset changes in expected cash flows due to fluctuations in the associated variable interest rates and designated them as cash flow hedges. The counterparties to these derivative agreements are major financial institutions. We monitor the credit quality of these financial institutions and do not expect nonperformance by any counterparty, although such nonperformance could have an adverse effect on us. We have no collateral posted for our derivative instruments. F-33 During the year ended December 31, 2021, we dedesignated $125.0 million notional value of our interest rate swaps. The fair value of this interest rate swap immediately prior to dedesignation was a liability of $1.6 million. The associated amount in accumulated other comprehensive loss related to this interest rate swap is being amortized into interest expense over the remaining term of the swap through March 2022. Changes in the fair value of the dedesignated interest rate swap subsequent to dedesignation are recorded in interest expense. The remaining $175.0 million notional value of our interest rate swaps continue to be designated as cash flow hedging instruments. We expect the hedging relationship to be highly effective as the interest rate swap terms substantially coincide with the hedged item and are expected to offset changes in expected cash flows due to fluctuations in the variable rate. We estimate that $1.2 million of the deferred pre-tax loss attributable to interest rate swaps included in accumulated other comprehensive loss at December 31, 2021 will be reclassified into earnings as interest expense at then-current values during the next 12 months as the underlying hedged transactions occur. As of December 31, 2021, the weighted average effective fixed interest rate of our interest rate swaps was 1.8%. The following table presents the effect of our derivative instruments on our consolidated balance sheets: (in thousands) Interest rate swaps designated as cash flow hedging instruments Accrued liabilities Other liabilities Total derivatives designated as cash flow hedging instruments December 31, 2021 2020 $ $ 727 — 727 4,810 1,527 6,337 Interest rate swaps not designated as hedging instruments Accrued liabilities 523 — Total derivative liabilities $ 1,250 $ 6,337 The following table presents the effect of our derivative instruments on our consolidated statements of operations: (in thousands) Total amount of interest expense in which the effects of cash flow hedges and undesignated interest rate swaps are recorded $ Year Ended December 31, 2020 2021 2019 108,135 $ 105,716 $ 104,681 Interest rate swaps designated as cash flow hedging instruments Pre-tax loss recognized in other comprehensive income (loss) Pre-tax gain (loss) reclassified from accumulated other comprehensive income (loss) into interest expense $ (1,219) $ (6,308) (8,459) $ (3,878) (6,785) 2,278 Interest rate swaps not designated as hedging instruments Gain recognized in interest expense $ 1,088 $ — $ — See Note 2 (“Basis of Presentation and Significant Accounting Policies”), Note 15 (“Accumulated Other Comprehensive Income (Loss)”) and Note 23 (“Fair Value Measurements”) for further details on our derivative instruments. F-34 23. Fair Value Measurements The accounting standard for fair value measurements and disclosures establishes a fair value hierarchy that prioritizes the inputs of valuation techniques used to measure fair value into the following three categories: • Level 1 — Quoted unadjusted prices for identical instruments in active markets to which we have access at the date of measurement. • Level 2 — Quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations in which all significant inputs and significant value drivers are observable in active markets. Level 2 inputs are those in markets for which there are few transactions, the prices are not current, little public information exists or prices vary substantially over time or among brokered market makers. • Level 3 — Model-derived valuations in which one or more significant inputs or significant value drivers are unobservable. Unobservable inputs are those inputs that reflect our own assumptions regarding how market participants would price the asset or liability based on the best available information. Assets and Liabilities Measured at Fair Value on a Recurring Basis On a quarterly basis, our interest rate swap derivative instruments are valued based on the income approach (discounted cash flow) using market observable inputs, including LIBOR forward curves. These fair value measurements are classified as Level 2. The following table presents our derivative position measured at fair value on a recurring basis, with pricing levels as of the date of valuation: (in thousands) Derivative liabilities December 31, 2021 2020 $ 1,250 $ 6,337 Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis Goodwill In the first quarter of 2020, we determined that the significant deterioration in global macroeconomic conditions caused by the COVID-19 pandemic was an indicator of potential impairment of our goodwill, and we performed a quantitative impairment test as of March 31, 2020 that resulted in a $99.8 million impairment of our goodwill. Significant estimates used in our impairment analysis included cash flow forecasts, our estimate of the market’s weighted average cost of capital and market multiples, which are Level 3 inputs. See Note 9 (“Goodwill”) for further details of the valuation methodology used in connection with the goodwill impairment. F-35 Compressors During the years ended December 31, 2021 and 2020, we recorded nonrecurring fair value measurements related to our idle compressors. Our estimate of the compressors’ fair value was primarily based on the expected net sale proceeds compared to other fleet units we recently sold and/or a review of other units recently offered for sale by third parties, or the estimated component value of the equipment we plan to use. We discounted the expected proceeds, net of selling and other carrying costs, using a weighted average disposal period of four years. These fair value measurements are classified as Level 3. The fair value of our compressors impaired during the years ended December 31, 2021 and 2020 was as follows: (in thousands) Impaired compressors December 31, 2021 2020 $ 4,380 $ 19,046 The significant unobservable inputs used to develop the above fair value measurements were weighted by the relative fair value of the compressors being measured. Additional quantitative information related to our significant unobservable inputs follows: Estimated net sale proceeds: As of December 31, 2021 As of December 31, 2020 Range Weighted Average (1) $0 - $621 per horsepower $0 - $289 per horsepower $35 per horsepower $20 per horsepower (1) Calculated based on an estimated discount for market liquidity of 64% and 81% as of December 31, 2021 and 2020, respectively. See Note 18 (“Long-Lived and Other Asset Impairment”) for further details. Other Financial Instruments The carrying amounts of our cash, receivables and payables approximate fair value due to the short-term nature of those instruments. The carrying amount of borrowings outstanding under our Credit Facility approximates fair value due to its variable interest rate. The fair value of these outstanding borrowings is a Level 3 measurement. The fair value of our fixed rate debt is estimated using yields observable in active markets, which are Level 2 inputs, and was as follows: (in thousands) Carrying amount of fixed rate debt (1) Fair value of fixed rate debt December 31, $ 2021 1,296,325 1,361,000 $ 2020 1,295,867 1,371,000 (1) Carrying amounts are shown net of unamortized debt premium and deferred financing costs. See Note 14 (“Long-Term Debt”). F-36 24. Stock-Based Compensation We recognize stock-based compensation expense related to restricted stock awards, restricted stock units, performance- based restricted stock units and shares issued under our ESPP. We account for forfeitures as they occur. (in thousands) Equity award expense Liability award (benefit) expense (1) Total stock-based compensation expense Year Ended December 31, 2020 2021 2019 $ $ 11,336 $ (816) 10,520 $ 10,551 $ 1,521 12,072 $ 8,105 2,336 10,441 (1) In 2021, includes a reversal of prior period expense of $2.1 million during the fourth quarter as the result of revised estimates of performance achievement of our 2019 and 2020 cash-settled performance-based restricted stock units. Stock Incentive Plans The 2020 Plan was adopted in April 2020 and provides for the granting of stock options, restricted stock, restricted stock units, stock appreciation rights, performance awards, other stock-based awards and dividend equivalent rights to employees, directors and consultants of Archrock. The 2020 Plan is administered by the compensation committee of our Board of Directors. Under the 2020 Plan, the maximum number of shares of common stock available for issuance is 8,500,000. Each stock-settled award granted under the 2020 Plan reduces the number of shares available for issuance by one share. Cash-settled awards are not counted against the aggregate share limit. Shares subject to awards granted under the 2020 Plan that are subsequently canceled, terminated, settled in cash or forfeited, excluding shares withheld to satisfy tax withholding obligations or to pay the exercise price of an option, are available for future grant under the 2020 Plan. No additional grants may be made under the 2013 Plan following the adoption of the 2020 Plan. Previous grants made under the 2013 Plan continue to be governed by that plan and the applicable award agreements. The 2020 Plan and 2013 Plan allow us to withhold shares upon vesting of restricted stock at the then-current market price to cover taxes required to be withheld on the vesting date. During the years ended December 31, 2021, 2020 and 2019, we withheld 283,972 shares valued at $2.5 million, 236,752 shares valued at $1.8 million and 212,080 shares valued at $2.0 million, respectively, to cover tax withholding. The compensation committee of our Board of Directors generally establishes its schedule for making annual long-term incentive awards, consisting of a combination of restricted shares and performance units vesting over multiple years, several months in advance and does not make such awards based on knowledge of material nonpublic information. Although the compensation committee of our Board of Directors has historically granted awards on a regular, predictable cycle, such awards may be granted at other times during the year, as determined in the sole discretion of the compensation committee. Restricted Stock Our outstanding restricted stock generally consists of stock-settled restricted stock awards and performance-based restricted stock units, and cash-settled performance-based restricted stock units. For grants of restricted stock, we recognize compensation expense over the vesting period equal to the fair value of our common stock at the grant date. Our restricted stock includes rights to receive dividends or dividend equivalents. We periodically remeasure the fair value of our cash-settled units and record a cumulative adjustment of the expense previously recognized. Our obligation related to the cash-settled units is reflected as a liability in our consolidated balance sheets. Restricted stock awards generally vest one-third per year, subject to continued service through the applicable vesting date. Performance-based restricted stock units generally vest in their entirety at the end of a three-year vesting period, also subject to continued service through the applicable vesting date. F-37 Some of our performance-based restricted stock units have a market-based condition that determines the number of restricted stock units and dividend equivalents earned. The market condition is based on our total shareholder return ranked against that of a predetermined peer group over a three-year performance period. The awards vest in their entirety on the date specified in the award agreement following the conclusion of the performance period. The fair value of the performance-based restricted stock units, incorporating the market condition, is estimated on the grant date using a Monte Carlo simulation model. Expected volatilities for us and each peer company utilized in the model are estimated using a historical period consistent with the awards’ remaining performance period as of the grant date. The risk-free interest rate is based on the yield on U.S. Treasury Separate Trading of Registered Interest and Principal Securities for a term consistent with the remaining performance period. The dividend yield used is 0.0% to approximate accumulation of earnings. The following table presents the inputs used and the grant date fair value calculated in the Monte Carlo simulation model for the performance-based restricted stock units awarded during the years ended December 31, 2021, 2020 and 2019: Remaining performance period as of grant date (in years) Risk-free interest rate used Grant-date fair value Year Ended December 31, 2020 2019 2021 2.8 0.3 % 2.9 1.4 % 2.9 2.6 % $ 14.30 $ 11.33 $ 12.91 The following table presents our restricted stock activity during the year ended December 31, 2021: Non-vested restricted stock, December 31, 2020 Granted (1) Vested (2) Canceled Non-vested restricted stock, December 31, 2021 (3) Weighted Average Grant Date Fair Value Per Share Shares (in thousands) $ 2,446 1,288 (1,075) (81) 2,578 9.69 11.20 9.91 9.85 10.35 (1) The weighted average grant date fair value of shares granted during the years ended December 31, 2021, 2020 and 2019 was $11.20, $9.37 and $10.01, respectively. (2) The total fair value of all awards vested during the years ended December 31, 2021, 2020 and 2019 was $9.1 million, $7.1 million and $9.0 million, respectively. (3) Non-vested awards as of December 31, 2021 were comprised of 523 cash-settled units and 2,055 stock-settled awards and units. As of December 31, 2021, we expect $12.6 million of unrecognized compensation cost related to our non-vested awards and units to be recognized over the weighted-average period of 1.8 years. Cash paid upon vesting of cash-settled restricted stock units during the years ended December 31, 2021, 2020 and 2019 was $0.6 million, $0.5 million and $1.3 million, respectively. F-38 Employee Stock Purchase Plan Adopted in 2017, our ESPP provides employees with an opportunity to participate in our long-term performance and success through the purchase of shares of common stock at a price that may be less than fair market value. Each quarter, eligible employees may elect to withhold a portion of their salary up to the lesser of $25,000 per year or 10% of their eligible pay to purchase shares of our common stock at a price equal to 85% to 100% of the fair market value of the stock as defined by the plan. The ESPP will terminate on the date that all shares of common stock authorized for sale under the ESPP have been purchased, unless it is extended. The maximum number of shares of common stock available for purchase under the ESPP is 1,000,000. As of December 31, 2021, 521,719 shares remained available for purchase under the ESPP. Our ESPP is compensatory and, as a result, we record an expense in our consolidated statements of operations related to the ESPP. The purchase discount under the ESPP is 5% of the fair market value of our common stock on the first or last trading day of the quarter, whichever is lower. Directors’ Stock and Deferral Plan Adopted in 2007, our DSDP provides non-employee members of the Board of Directors with an opportunity to elect to receive our common stock as payment for a portion or all of their retainer. The number of shares paid each quarter is determined by dividing the dollar amount of fees elected to be paid in common stock by the closing sales price per share of the common stock on the last day of the quarter. In addition, directors who elect to receive a portion or all of their fees in the form of common stock may also elect to defer, until a later date, the receipt of a portion or all of their fees to be received in common stock. There are 100,000 shares reserved under the DSDP and, as of December 31, 2021, 37,771 shares remained available to be issued under the plan. 25. Retirement Benefit Plan Our 401(k) retirement plan provides for optional employee contributions up to the applicable IRS annual limit and discretionary employer matching contributions. We make discretionary matching contributions to each participant’s account at a rate of 100% of each participant’s contributions up to 5% of eligible compensation. We recorded matching contributions of $4.4 million, $5.6 million and $6.8 million during the years ended December 31, 2021, 2020 and 2019, respectively. 26. Commitments and Contingencies Insurance Our business can be hazardous, involving unforeseen circumstances such as uncontrollable flows of natural gas or well fluids and fires or explosions. As is customary in our industry, we review our safety equipment and procedures and carry insurance against some, but not all, risks of our business. Our insurance coverage includes property damage, general liability and commercial automobile liability and other coverage we believe is appropriate. We believe that our insurance coverage is customary for the industry and adequate for our business, however, losses and liabilities not covered by insurance would increase our costs. 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. Losses up to the deductible amounts are estimated and accrued based upon known facts, historical trends and industry averages. We are also self-insured for property damage to our offshore assets. F-39 Tax Matters We are subject to a number of state and local taxes that are not income-based. As many of these taxes are subject to audit by the taxing authorities, it is possible that an audit could result in additional taxes due. We accrue for such additional taxes when we determine that it is probable that we have incurred a liability and we can reasonably estimate the amount of the liability. As of December 31, 2021 and 2020, we accrued $5.8 million and $5.6 million, respectively, for the outcomes of non-income-based tax audits. We do not expect that the ultimate resolutions of these audits will result in a material variance from the amounts accrued. We do not accrue for unasserted claims for tax audits unless we believe the assertion of a claim is probable, it is probable that it will be determined that the claim is owed and we can reasonably estimate the claim or range of the claim. We believe the likelihood is remote that the impact of potential unasserted claims from non-income-based tax audits could be material to our consolidated financial position, but it is possible that the resolution of future audits could be material to our consolidated results of operations or cash flows. In 2021, one of our sales and use tax audits advanced from the audit review phase to the contested hearing phase. We accrued $0.6 million and $0.9 million for this audit as of December 31, 2021 and 2020, respectively. In 2020, we settled a certain sales and use tax audit for which we recorded a $12.4 million net benefit in our consolidated statements of operations. This net benefit was primarily reflected as decreases of $4.4 million and $7.9 million to cost of sales (excluding depreciation and amortization) and SG&A, respectively. We received a cash refund of $17.3 million in the fourth quarter of 2020 related to this settlement and have a $2.0 million accrued liability recorded as of December 31, 2021, which is included in our accrual for non-income-based tax audits discussed above. Subject to the provisions of the tax matters agreement between Exterran Corporation and us, both parties agreed to indemnify the primary obligor of any return for tax periods beginning before and ending before or after the Spin-off (including any ongoing or future amendments and audits for these returns) for the portion of the tax liability (including interest and penalties) that relates to their respective operations reported in the filing. The tax contingencies mentioned above relate to tax matters for which we are responsible in managing the audit. As of December 31, 2020, we had an indemnification liability (including penalties and interest), in addition to the tax contingency above, of $1.6 million for our share of non-income-based tax contingencies related to audits being managed by Exterran Corporation. During the year ended December 31, 2021, these audits were settled and our indemnification liability was reduced to zero. Litigation and Claims 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. 27. Related Party Transactions In connection with the closing of the Elite Acquisition, we issued 21.7 million shares of our common stock to JDH Capital, an affiliate of our customer Hilcorp. As long as JDH Capital, together with affiliates of Hilcorp, owns at least 7.5% of our outstanding common stock, it will have the right to designate one director to our Board of Directors. As of December 31, 2021, JDH Capital owned 11.1% of our outstanding common stock. Jeffery D. Hildebrand, founder and executive chairman of Hilcorp, was appointed Director in August 2019 and served until his resignation on July 29, 2020, at which time Jason C. Rebrook, President of Hilcorp, was appointed Director to fill the resulting vacancy. Mr. Hildebrand did not receive compensation in his role as Director and Mr. Rebrook received no compensation in his role as Director in 2020. In December 2020, the Board of Directors voted to approve the payment of Director cash and equity compensation to Mr. Rebrook beginning in 2021. F-40 Revenue from Hilcorp and affiliates was $38.2 million, $40.3 million and $31.4 million during the years ended December 31, 2021, 2020 and 2019, respectively. Accounts receivable, net due from Hilcorp and affiliates was $3.7 million and $3.9 million as of December 31, 2021 and 2020, respectively. 28. Segments We manage our business segments primarily based on the type of product or service provided. We have two segments which we operate within the U.S.: contract operations and aftermarket services. The contract operations segment primarily provides natural gas compression services to meet specific customer requirements. The aftermarket services segment provides a full range of services to support the compression needs of customers, from parts sales and normal maintenance services to full operation of a customer’s owned assets. We evaluate the performance of our segments based on gross margin for each segment. Revenue includes only sales to external customers. No single customer accounted for 10% or more of our revenue during the years ended December 31, 2021, 2020 and 2019. (in thousands) 2021 Revenue Gross margin Capital expenditures 2020 Revenue Gross margin Capital expenditures 2019 Revenue Gross margin Capital expenditures (1) Corporate-related items. Contract Operations Aftermarket Services Other (1) $ $ $ $ $ $ 648,311 403,825 94,863 738,918 477,831 133,492 771,539 474,279 374,650 $ $ $ 133,150 18,719 2,675 136,052 19,946 5,308 193,946 34,968 8,714 $ $ $ — — 347 — — 1,502 — — 1,834 Total 781,461 422,544 97,885 874,970 497,777 140,302 965,485 509,247 385,198 The following table presents assets by segment reconciled to total assets per the consolidated balance sheets: (in thousands) Contract operations assets Aftermarket services assets Segment assets Other assets (1) Assets associated with discontinued operations Total assets (1) Corporate-related items. December 31, 2021 2,429,805 $ 49,420 2,479,225 100,930 9,811 2,589,966 $ 2020 2,593,864 45,985 2,639,849 128,837 11,036 2,779,722 $ $ F-41 The following table reconciles total gross margin to income (loss) before income taxes: (in thousands) Total gross margin Less: Selling, general and administrative Depreciation and amortization Long-lived and other asset impairment Goodwill impairment Restatement and other charges Restructuring charges Interest expense Debt extinguishment loss Transaction-related costs Gain on sale of assets, net Other income, net Income (loss) before income taxes 29. Impact of Hurricane Year Ended December 31, 2020 497,777 $ 2021 422,544 $ 2019 509,247 $ 107,167 178,946 21,397 — — 2,903 108,135 — — (30,258) (4,707) 38,961 $ 105,100 193,138 79,556 99,830 — 8,450 105,716 3,971 — (10,643) (1,359) (85,982) $ 117,727 188,084 44,663 — 445 — 104,681 3,653 8,213 (16,016) (661) 58,458 $ Hurricane Ida made landfall in Louisiana on August 29, 2021, causing operational disruptions, damage to compressors and a temporary shutdown of facilities in Louisiana that negatively impacted our financial performance in the quarter. In the third quarter of 2021, we recorded $2.0 million in depreciation expense associated with the damaged assets, and in the fourth quarter, we recognized an insurance recovery of $2.8 million related to the facility and compressor damages in other income, net in our consolidated statements of operations, after a deductible of $0.9 million. A corresponding receivable for $2.8 million was recorded to our consolidated balance sheet as of December 31, 2021. The remaining portion of our insurance claim pertaining to business interruption is in process. We are currently unable to estimate the expected amount to be recovered, however, any amount recovered will not be subject to an additional deductible. F-42 BOARD OF DIRECTORS Gordon T. Hall Chairman of the Board Anne-Marie N. Ainsworth D. Bradley Childers LEADERSHIP TEAM D. Bradley Childers President and Chief Executive Officer Doug S. Aron Senior Vice President and Chief Financial Officer CORPORATE INFORMATION Annual Meeting The 2022 Annual Meeting of Stockholders will be held April 28, 2022, at 9:00 a.m. central time, at Archrock’s Corporate Office. Stock Trading New York Stock Exchange symbol: AROC Stockholder Information Website Additional information on Archrock, including securities filings, press releases, Code of Business Conduct, Corporate Governance Principles and Board Committee Charters, is available on our website at www.archrock.com. Transfer Agent-Registrar American Stock Transfer and Trust Company, LLC 6201 15th Avenue Brooklyn, New York 11219 USA (800) 937-5449 or (718) 921-8124 help@astfinancial.com Independent Registered Public Accounting Firm Deloitte & Touche LLP, Houston, Texas USA Frances Powell Hawes J.W.G. “Will” Honeybourne James H. Lytal Leonard W. Mallett Jason C. Rebrook Edmund P. Segner, III Stephanie C. Hildebrandt Senior Vice President, General Counsel and Secretary Elspeth A. Inglis Senior Vice President and Chief Human Resources Officer Jason G. Ingersoll Senior Vice President, Sales and Operations Support Eric W. Thode Senior Vice President, Operations Corporate Office 9807 Katy Freeway, Ste. 100 Houston, Texas 77024 USA (281) 836-8000 10-K/Investor Contact Stockholders may obtain a copy, without charge, of Archrock’s 2021 Form 10-K, filed with the Securities and Exchange Commission, by visiting our website at www.archrock.com or by requesting a copy in writing to investor.relations@archrock.com or Archrock’s Corporate Office, Attention: Investor Relations. The certifications by our Chief Executive Officer and Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 are filed as exhibits to our 2021 Form 10-K. We have also filed with the New York Stock Exchange the written affirmation certifying that we are not aware of any violations by Archrock of NYSE Corporate Governance Listing Standards. Contact Board of Directors To report a concern about Archrock’s accounting, internal controls or auditing matters, or any other matter, to the Audit Committee or non-management members of the Board of Directors, send a detailed note, with relevant documents, to Archrock’s Corporate Office, Attention: Gordon T. Hall, Chairman of the Board, or leave a message at 1-844-809-1630. Forward-Looking Statements Certain statements contained in this Annual Report may constitute forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These statements involve a number of risks, uncertainties and other factors that could cause actual results to be materially different, as discussed more fully elsewhere in this Annual Report and in our filings with the Securities and Exchange Commission, including our 2021 Form 10-K filed on February 23, 2022. Except as required by law, we expressly disclaim any intention or obligation to revise or update any forward-looking statements whether as a result of new information, future events or otherwise. Archrock is an energy infrastructure company with a pure-play focus on midstream natural gas compression. Archrock is the leading provider of natural gas compression services to customers in the oil and natural gas industry throughout the U.S. and a leading supplier of aftermarket services to customers that own compression equipment in the U.S. Archrock is headquartered in Houston, Texas. For more information, please visit www.archrock.com. AROC_2021_ANNUAL.indd 4 AROC_2021_ANNUAL.indd 4 3/9/22 1:37 PM 3/9/22 1:37 PM  archrock.com 9807 Katy Freeway, Ste. 100 Houston, Texas 77024 © 2022 Archrock. All Rights Reserved. AROC_2021_ANNUAL.indd 1 AROC_2021_ANNUAL.indd 1 3/9/22 1:37 PM 3/9/22 1:37 PM 

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