Exterran Corporation
Annual Report 2018

Plain-text annual report

To our Stockholders, Exterran had a strong 2018, despite the oil and gas industry demonstrating a tale of two halves as industry takeaway capacity, oil price volatility and numerous macro-economic concerns weighed heavily on the industry during the second half of the year. In spite of these factors, we delivered solid financial results, set a second quarter record in product sales orders, grew our contract operations backlog and enhanced our liquidity by extending our revolving credit facility. In addition we delivered on the following initiatives that set the foundation for our future.  Continuation of our strong focus on safety, resulting in best in class safety metrics;  Began a repositioning of the organization as a systems and process company;  Adopted a regional organization structure with a focus on driving a customer centric culture, enabled through tools and processes; and  Relaunched our Exterran Water Solutions (EWS) business resulting in promising customer reaction. The accomplishments were the result of the hard work and dedication of our approximately 4,300 global associates. Our 2018 revenue was $1.36 billion, a 12% increase from 2017, while our EBITDA, as adjusted grew to $205 million, up 19% from the prior year. Our contract operations segment revenue was $361 million while gross margin was 66%, up from 64% in 2017. Although our revenue declined 4% year over year, we were able to cover foreign currency impacts in Latin America by our team’s ability to secure new contracts and renew expiring contracts. Backlog for the segment ended at $1.4 billion, providing strong visibility for the coming years. We had significant wins in Latin America and the Middle East and Africa regions during the year and began the initial startup of a long-term project in the Middle East. For our aftermarket services segment, our team was focused on growing this profitable business. We had key wins globally, which set a strong foundation for future expansion. Revenue was $121 million, up 13% year over year with margins at 26%. Our product sales segment had a book to bill of 1.3x on orders of $1.14 billion, up 28% from 2017 levels, including a significant win in the Middle East. Revenue for the segment was $879 million, up 20% year over year. We continue to focus on driving efficiencies and pricing which led Product margin improvement in 2018 to 13%, up from 10% in 2017. Our focus on cash was evident as net cash from operating activities excluding discontinued operations for the year was $153 million, with part of this being driven by our emphasis on working capital, which was at 8% of revenue as of December 31. This past year truly felt like the year of transition for Exterran as we broadened our internal systems and processes, expanded our product portfolio in integrated systems and water and completed our transition to a regional based, customer centric organization. While uncertainty remains around how 2019 will play out within the oil and gas space, the backlog that we have built in our contract operations and products sales segments sets us up well to weather any near-term bumps that might arise. The orders we booked in 2018 provide visibility through the first half of 2019 and to a lesser degree the second half, but we are cognizant that the volatility in commodity prices could cause a pause in certain of our markets. That said, we are still positive about the demand for our products as many of the bids and orders are for equipment to be delivered late in 2019 and into 2020. Takeaway capacity issues in the Permian should begin to alleviate in the middle of the year and allow producers the ability to move greater volumes, driving additional associated gas. The EWS business is gaining traction around the globe given the extreme focus on water and waste water solutions, but as with most oilfield technologies adoption takes time, even for the strong solution set we offer. Latin America remains our largest international region. After over a year of significant press about the Vaca Muerta shale play in Argentina, we are now seeing the bid and order activity beginning as we booked our first contract operations deal for the play during the year, with additional opportunities to come. Additionally, outside investment in Brazil from international oil companies and majors has created opportunities for additional processing and treating plants onshore for offshore projects. Near-term opportunities continue to exist around the globe for Exterran, as demand for natural gas grows. We had a large product sales order in the Middle East and Africa region and we see ample opportunities looking ahead, not only for contract operations services but also products and services within the region. The biggest challenge we face is timing, as these projects are typically larger in scale and can create lumpiness in awards. Our Asia Pacific region is driven largely by aftermarket services. We are beginning to see markets come back to life in the region, albeit slower than we would have anticipated. Our longstanding relationships will serve us well as we look to grow the business in the region. We have spent this year talking about our transition to a systems and process company focused on oil, gas, water and power. We have had nice momentum in furthering our abilities in these segments and will look to further differentiate ourselves in 2019. Additionally, we have watched energy investing transition the past several years from EBITDA, as adjusted growth to improving cash flow and increasing returns. We are keenly focused on improving both of these metrics to drive shareholder value in the coming years. In conjunction with our focus on driving shareholder value, our board authorized a $100 million three-year buyback program in February 2019. In summary, 2018 was a great year operationally. We have built a strong foundation with our contract operations and product sales backlog and are excited about the opportunities to drive improved metrics and ultimately shareholder value. We want to thank our employees for their contributions in 2018 and recognize all of our stakeholders, including customers, shareholders and lenders, for their ongoing support and interest in Exterran. Andrew J. Way President and Chief Executive Officer Mark R. Sotir Executive Chairman UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 Form 10-K (Mark One) x       ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the fiscal year ended December 31, 2018 or ¨   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. 001-36875 Exterran Corporation (Exact name of registrant as specified in its charter) Delaware (State or other jurisdiction of incorporation or organization) 47-3282259 (I.R.S. Employer Identification No.) 4444 Brittmoore Road, Houston, Texas 77041 (Address of principal executive offices, zip code) (281) 836-7000 (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 Name of Each 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 x  No ¨ Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.  Yes ¨  No x 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 x  No ¨ Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).  Yes x  No ¨ 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.  x 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 x o Accelerated filer Smaller reporting company Emerging growth company o o o 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. o Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes o  No x The aggregate market value of the common stock of the registrant held by non-affiliates, based on the closing price on the New York Stock Exchange, as of June 30, 2018 was $791,626,980. Number of shares of the common stock of the registrant outstanding as of February 19, 2019: 36,142,190 shares. Portions of the registrant’s definitive proxy statement for the 2019 Meeting of Stockholders, which is expected to be filed with the Securities and Exchange Commission within 120 days after December 31, 2018, are incorporated by reference into Part III of this Form 10-K. DOCUMENTS INCORPORATED BY REFERENCE  TABLE OF CONTENTS  PART I Business Risk Factors Unresolved Staff Comments Properties Legal Proceedings Mine Safety Disclosures PART II Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities Selected Financial Data Management’s Discussion and Analysis of Financial Condition and Results of Operations Quantitative and Qualitative Disclosures About Market Risk Financial Statements and Supplementary Data Changes in and Disagreements with Accountants on Accounting and Financial Disclosure Controls and Procedures Other Information PART III Directors, Executive Officers and Corporate Governance Executive Compensation Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters Certain Relationships and Related Transactions and Director Independence Principal Accountant Fees and Services Item 1. Item 1A. Item 1B. Item 2. Item 3. Item 4. Item 5. Item 6. Item 7. Item 7A. Item 8. Item 9. Item 9A. Item 9B. Item 10. Item 11. Item 12. Item 13. Item 14. Item 15. Item 16. SIGNATURES Exhibits and Financial Statement Schedules Form 10-K Summary PART IV Page 2 10 22 22 23 23 23 26 31 53 53 53 53 56 56 56 56 56 57 58 60 61 This page intentionally left blank PART I DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS This report 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 report are forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), including, without limitation, statements regarding our business growth strategy and projected costs; future financial position; the sufficiency of available cash flows to fund continuing operations; the expected amount of our capital expenditures; expenditures related to the current governmental investigation; anticipated cost savings, future revenue, gross margin and other financial or operational measures related to our business and our primary business segments; 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 looking for 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 report. 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 the expectations reflected in these forward-looking statements include those described below, 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 report. Important factors that could cause our actual results to differ materially from the expectations reflected in these forward-looking statements include, among other things: • • • • • • • • • • • • • • • conditions in the oil and natural gas industry, including a sustained imbalance in the level of supply or demand for oil or natural gas or a sustained low price of oil or natural gas, which could depress or reduce the demand or pricing for our natural gas compression and oil and natural gas production and processing equipment and services; reduced profit margins or the loss of market share resulting from competition or the introduction of competing technologies by other companies; economic or political conditions in the countries in which we do business, including civil developments such as uprisings, riots, terrorism, kidnappings, violence associated with drug cartels, legislative changes and the expropriation, confiscation or nationalization of property without fair compensation; changes in currency exchange rates, including the risk of currency devaluations by foreign governments, and restrictions on currency repatriation; risks associated with cyber-based attacks or network security breaches; changes in international trade relationships, including the imposition of trade restrictions or tariffs relating to any materials or products (such as aluminum and steel) used in the operation of our business; risks associated with our operations, such as equipment defects, equipment malfunctions and natural disasters; the risk that counterparties will not perform their obligations under their contracts with us; the financial condition of our customers; our ability to timely and cost-effectively obtain components necessary to conduct our business;  employment and workforce factors, including our ability to hire, train and retain key employees; our ability to implement our business and financial objectives, including: • • • • • • winning profitable new business; timely and cost-effective execution of projects; enhancing our asset utilization, particularly with respect to our fleet of compressors; integrating acquired businesses; generating sufficient cash to satisfy our operating needs, existing capital commitments and other contractual cash obligations, including our debt obligations; and accessing the financial markets at an acceptable cost; our ability to accurately estimate our costs and time required under our fixed price contracts; liability related to the use of our products and services; changes in governmental safety, health, environmental or other regulations, which could require us to make significant expenditures; 1     • • the results of governmental actions relating to the current investigation; and our level of indebtedness and ability to fund our business. All forward-looking statements included in this report are based on information available to us on the date of this report. 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 report. Item 1.  Business Exterran Corporation (together with its subsidiaries, “Exterran Corporation,” “our,” “we” or “us”), a Delaware corporation formed in March 2015, is a global systems and process company offering solutions in the oil, gas, water and power markets. We are a leader in natural gas processing and treatment and compression products and services, providing critical midstream infrastructure solutions to customers throughout the world. Outside the United States of America (“U.S.”), we are a leading provider of full-service natural gas contract compression and a supplier of aftermarket parts and services. Our manufacturing facilities are located in the U.S., Singapore and the United Arab Emirates. On November 3, 2015, Archrock, Inc. (named Exterran Holdings, Inc. prior to November 3, 2015) (“Archrock”) completed the spin-off (the ‘‘Spin-off”) of its international contract operations, international aftermarket services and global fabrication businesses into an independent, publicly traded company named Exterran Corporation. Following the completion of the Spin- off, we and Archrock became and continue to be independent, publicly traded companies with separate boards of directors and management. General We provide our products and services to a global customer base consisting of companies engaged in all aspects of the oil and natural gas industry, including large integrated oil and natural gas companies, national oil and natural gas companies, independent oil and natural gas producers and oil and natural gas processors, gatherers and pipeline operators. We operate in three primary business lines: contract operations, aftermarket services and product sales. The nature and inherent interactions between and among our business lines provide us with opportunities to cross-sell and offer integrated product and service solutions to our customers. For financial data relating to our reportable business segments or countries that accounted for 10% or more of our revenue in any of the last three fiscal years or 10% or more of our property, plant and equipment, net, as of December 31, 2018, 2017 or 2016, see Part II, Item 7 (“Management’s Discussion and Analysis of Financial Condition and Results of Operations”) and Note 22 to our Consolidated Financial Statements included in Part IV, Item 15 (collectively referred to as “Financial Statements,” and individually referred to as “balance sheets,” “statements of operations,” “statements of comprehensive income (loss),” “statements of stockholders’ equity” and “statements of cash flows” herein). Contract Operations In our contract operations business, we provide compression and processing and treating services through the operation of our natural gas compression equipment and crude oil and natural gas production and process equipment for our customers. In addition to these services, we also offer water treatment and power solutions to our customers on a stand-alone basis or integrated into our natural gas compression or crude oil production and processing solutions. Our services include the provision of personnel, equipment, tools, materials and supplies to meet our customers’ natural gas compression and oil and natural gas production and processing service needs. Activities we may perform in meeting our customers’ needs include engineering, designing, sourcing, constructing, installing, operating, servicing, repairing, maintaining and demobilizing equipment owned by us necessary to provide these services. 2 We generally enter into contracts with our contract operations customers with initial terms ranging between three to 12 years. In many instances, we are able to renew those contracts prior to the expiration of the initial term and in other instances, we may sell the underlying assets to our customers pursuant to purchase options or negotiated sale agreements. If a contract is not renewed or a customer does not purchase the underlying assets, our equipment is generally returned to our premises for future redeployment. Our contracts may include several compressor units on one site or entire facilities designed to process and treat produced oil or natural gas to make them suitable for end use, which may require us to make significant investments in equipment, facilities and related installation costs. Our commercial contracts generally require customers to pay a monthly service fee even during periods of limited or disrupted oil or natural gas feed flows, which we believe provide us with relatively stable and predictable cash flows. Additionally, because we typically do not take title to the oil or natural gas that we compress, process or treat, and because the natural gas we use as fuel for our equipment is supplied by our customers, we have limited direct exposure to short-term commodity price fluctuations. Our equipment is operated and maintained in accordance with established operational procedures and maintenance schedules. These operations and maintenance procedures are updated as technology changes and as our operations team develops new techniques and procedures. In addition, because our field technicians regularly operate and maintain our contract operations equipment, they are familiar with the condition of our equipment and can readily identify potential problems. In our experience, this in-house expertise and these maintenance procedures maximize equipment life and unit availability, minimize avoidable downtime and lower the overall maintenance expenditures over the equipment life. We believe our contract operations services generally allow our customers to achieve higher production rates and lower unit costs of operation than they would otherwise achieve with their own operations, resulting in increased revenue and margin for our customers. In addition, outsourcing these services allows our customers flexibility for their compression and production and processing needs while limiting their upfront capital requirements. During the year ended December 31, 2018, approximately 26% of our revenue and 62% of our gross margin was generated from contract operations. As of December 31, 2018, we had approximately $1.4 billion of unsatisfied performance obligations (commonly referred to as backlog), of which approximately $292 million is expected to be recognized as revenue before December 31, 2019. Our contract operations backlog consists of unfilled orders based on signed contracts and does not include potential sales pursuant to letters of intent received from customers. Our contract operations business is capital intensive. As of December 31, 2018, the net book value of property, plant and equipment associated with our contract operations business was $823.4 million. Aftermarket Services In our aftermarket services business, we sell parts and components and provide operations, maintenance, repair, overhaul, upgrade, startup and commissioning and reconfiguration services to customers who own their own oil and natural gas compression, production, processing, treating and related equipment. Our services range from routine maintenance services and parts sales done on a transactional basis to the full operation and maintenance of customer-owned equipment under long-term agreements. We generally enter into contracts with our operation and maintenance customers with initial terms ranging between one to four years, and in some cases, in excess of five years. In many instances, we are able to renew those contracts prior to the expiration of the initial term. We believe that we are particularly well qualified to provide these services because of our highly experienced operating personnel and technical and engineering expertise gained through providing similar services as part of our contract operations business. In addition, our aftermarket services business complements our strategy to provide integrated infrastructure solutions to our customers because it enables us to continue to serve our customers after the sale of any products or facilities manufactured through our product sales business. Our business approach is designed to leverage our aftermarket services with our product sales business to provide full life-cycle services to customers who buy equipment from us and we also seek to sell those same aftermarket services to customers who have bought similar equipment from other companies based on our existing experience and infrastructure available to support them. During the year ended December 31, 2018, approximately 9% of our revenue and 8% of our gross margin was generated from aftermarket services. 3 Product Sales In our product sales business, we design, engineer, manufacture, install and sell natural gas compression packages as well as equipment used in the treating and processing of crude oil and natural gas primarily to major and independent oil and natural gas producers as well as national oil and natural gas companies around the world. We offer a broad range of equipment designed to process crude oil and natural gas into hydrocarbon commodities suitable for end use. Our products include wellhead, gathering, residue and high pressure natural gas compression equipment, cryogenic plants, mechanical refrigeration and dew point control plants, condensate stabilizers, water treatment equipment, integrated power generation and skid-mounted production packages designed for both onshore and offshore production facilities. We believe the broad range of products we sell through our global operating structure enables us to take advantage of the ongoing, worldwide energy infrastructure build- out. We design, engineer, manufacture, sell and, in certain cases, install, skid-mounted natural gas compression equipment to meet standard or unique customer specifications. Generally, we manufacture compressors sold to third parties according to each customer’s specifications. We purchase components for these compressors from third party suppliers including several major engine and compressor original equipment manufacturers in the industry. We also sell pre-engineered compressor units designed to maximize value and fast delivery to our customers. Typically, we expect our compressor equipment backlog to be manufactured and delivered within a three to 12 month period. We also sell custom-engineered, built-to-specification natural gas and oil processing and treating equipment, including designing facilities comprised of a combination of our products integrated into a solution that meets our customers’ needs. Some of these projects are located in remote areas and in developing countries with limited oil and natural gas industry infrastructure. To meet most customers’ rapid schedule requirements and minimize customer downtime, we maintain an inventory of standard products and longer lead-time components used to manufacture our products to our customers’ specifications. Typically, we expect our processing and treating equipment backlog to be produced within a six to 24 month period. During the year ended December 31, 2018, approximately 65% of our revenue and 30% of our gross margin was generated from product sales. As of December 31, 2018, our backlog in product sales was approximately $706 million, of which approximately $690 million is expected to be recognized as revenue before December 31, 2019. Our product sales backlog consists of unfilled orders based on signed contracts and does not include potential product sales pursuant to letters of intent received from customers. Competitive Strengths We believe we have the following key competitive strengths: • Global footprint and expansive service and product offerings positioned to capitalize on the global energy infrastructure build-out.  The global oil and natural gas production and processing infrastructure build out provides us with opportunities for growth. We are well positioned to capitalize on increased opportunities in both the U.S. and international markets. We believe our global customer base will continue to invest in infrastructure projects based on longer-term fundamentals that are less tied to near-term commodity prices and that our size and geographic presence provide us with a unique advantage in meeting our customers’ needs. We provide our customers with a broad variety of products and services in approximately 25 countries worldwide, including compression, production and processing services, natural gas compression, oil and natural gas processing and treating equipment, water treatment solutions, installation services and integrated power generation. By offering a broad range of products and services that leverage our core strengths, we believe we provide unique integrated solutions that meet our customers’ needs. We believe the breadth and quality of our products and services, the depth of our customer relationships and our presence in many major oil and natural gas producing regions place us in a position to capture additional business on a global basis. 4 • Complementary businesses enable us to offer customers integrated infrastructure solutions.  We aim to provide our customers with a single source to meet their energy infrastructure needs and we believe we have the ability to serve our customers’ changing needs in a variety of ways. For customers that seek to manage their capital spending on energy infrastructure projects, we offer our full project and operations services through our contract operations business. For customers that prefer to develop and acquire their own infrastructure assets, we are able to sell equipment and facilities to support their operations and, following the sale of our equipment, we can also provide commissioning, start-up, operations, maintenance, overhaul, upgrade and reconfiguration services through our aftermarket services business. Furthermore, we can combine our products into an integrated solution where we can design, engineer, procure and, in some cases, construct assets on-site for sale to our customers. Because of the breadth of our products and our unique ability to deliver those products through our different commercial models, we believe we are able to provide the right solution that is most suitable to our customers in the markets in which they operate. We believe this ability to provide our customers with a variety of products and services provides us with more business opportunities, as we are able to adjust the products and services we provide to reflect our customers’ changing needs. • High-quality products and services.  We have built a network of high-quality energy infrastructure assets that are strategically deployed across our global platform. Through our history of operating a wide variety of products in many energy-producing markets around the world, we have developed the technical expertise and experience that we believe is required to understand the needs of our customers and to meet those needs through a range of products and services. These products and services include highly customized compression, production, processing and treating solutions as well as standard products based on our expertise, in support of a range of projects, from those requiring quick completion to those that may take several years to fully develop. Additionally, our experience has enabled us to develop efficient systems and work processes and a skilled workforce that allow us to provide high-quality services. We seek to continually improve our products and services to enable us to provide our customers with high-quality, comprehensive oil and natural gas infrastructure support worldwide. • • Cash flows from our contract operations business are supported by long-term contracts.  We provide contract operations services to customers located in 12 countries. Within our contract operations business, we seek to enter into long-term contracts with a diverse collection of customers, including large integrated oil and natural gas companies and national energy companies. These contracts generally involve initial terms ranging from three to 12 years, and typically require our customers to pay a monthly service fee even during periods of limited or disrupted oil or natural gas flows. Furthermore, our customer base includes companies that are among the largest and most well-known companies within their respective regions and countries. Experienced management team.  We have an experienced and skilled management team with a long track record of driving growth through organic expansion and selective acquisitions. The members of our management team have strong relationships in the oil and gas industry and have operated through numerous commodity price cycles throughout our areas of operations. Members of our management team have spent a significant portion of their respective careers at highly regarded energy and manufacturing companies serving the upstream, midstream and downstream segments of the oil and natural gas market. • Well-balanced capital structure with sufficient liquidity.  We intend to maintain a capital structure with an appropriate amount of leverage and the financial flexibility to invest in our operations and pursue attractive growth opportunities which we believe will increase overall earnings and cash flow generated by our business. As of December 31, 2018, taking into account guarantees through outstanding letters of credit, we had undrawn capacity of $608.3 million under our revolving credit facility, of which $578.4 million was available for additional borrowings as a result of a covenant restriction included in our credit agreement. In addition, as of December 31, 2018, we had $19.3 million of cash and cash equivalents on hand. 5 Business Strategies We intend to continue to capitalize on our competitive strengths to meet our customers’ needs through the following key strategies: • • • • Strategically grow our business.  Our primary strategic focus involves the targeted growth of our core business by expanding our product and services offerings and by leveraging our existing, proven portfolio of products and services. We intend to infuse new technology and innovation into our existing midstream products and services while developing new product and service offerings in water treatment and integrated power generation. Additionally, our strategic focus includes targeting development opportunities in the U.S. energy market and expansion into new international markets benefiting from the global energy infrastructure build-out. We believe our diverse product and service portfolio allows us to readily respond to changes in industry and economic conditions and that our global footprint allows us to provide the prompt product availability our customers require. We have the ability to undertake projects in new locations as needed to meet customer demand and to readily deploy our capital to construct new or supplemental projects that we can build, own, operate and maintain on behalf of our customers through our contract operations business. In addition, we seek to provide our customers with integrated energy infrastructure solutions by combining product and service offerings across our businesses. We plan to supplement our organic growth with select acquisitions, partnerships and other commercial arrangements in key markets to further enhance our geographic reach, product offerings and other capabilities. We believe these arrangements will allow us to generate incremental revenues from existing and new customers and increase market share. Expand customer base and deepen relationships with existing customers.  We believe the unique, broad range of products and services we offer, the quality of our products and services and our diverse geographic footprint position us to attract new customers and cross-sell our products and services to existing customers. In addition, we have a long history of providing our products and services to our customers which, coupled with the technical expertise of our experienced personnel, enables us to understand and meet our customers’ needs, particularly as those needs develop and change over time. We intend to continue to devote significant business development resources to market our products and services, leverage existing relationships and expedite our growth potential. Additionally, we seek to evolve our products and services offerings by developing new technologies that will allow us to provide differentiated solutions to the critical midstream infrastructure needs of our customers. Enhance our safety performance.  We believe our safety performance and reputation help us to attract and retain customers and employees. We have adopted rigorous processes and procedures to facilitate our compliance with safety regulations and policies on a global basis. We work diligently to meet or exceed applicable safety regulations, and continue to focus on our safety as our business grows and operating conditions change. Continue to optimize our global platform, products and services and enhance our profitability.  We regularly review and evaluate the quality of our operations, products and services and portfolio of our product and service offerings. This evaluation process includes assessing the quality of our performance and potential opportunities to create value for our customers. We believe the development and introduction of new technology into our existing products and services offerings will create more value for our customers and us in the market place, which we believe will further differentiate us from our competitors. Additionally, we believe our ongoing focus on improving the quality of our operations, products and services results in greater satisfaction among our customers, which we believe results in greater profitability and value for our shareholders. Industry Overview Natural Gas Compression Natural gas compression is a mechanical process whereby the pressure of a given volume of natural gas is increased to a desired pressure for movement from one point to another and is essential to the production and transportation of natural gas. Compression is typically required several times during the natural gas production and transportation cycle, including (i) at the wellhead, (ii) throughout gathering and distribution systems, (iii) into and out of processing and storage facilities and (iv) along pipelines. Natural gas compression can also be used to re-inject associated gas into producing wells to provide enhanced oil recovery. 6 Our contract operations business is comprised primarily of large horsepower internal combustion engine or electric motor- driven reciprocating compressors that are typically deployed in facilities comprised of several compressors on one site. A significant portion of this business involves comprehensive projects that require the design, engineering, manufacture, delivery and installation of several compressors on one site coupled with related natural gas treating and processing equipment. We are able to serve our customers’ needs for such projects through our product sales business and with follow-on services from our aftermarket services business, or through the provision of our contract operations services. Processing and Treating Crude oil and natural gas are generally not marketable products as produced raw at the wellhead and must be processed or treated to meet hydrocarbon commodity specifications before they can be transported to market. Processing and treating equipment is used to separate and treat oil and natural gas as they are produced to achieve a marketable quality of product. Production processing typically involves the separation of oil and natural gas and the removal of contaminants or the separation of marketable liquids from the gas stream prior to transportation. The end result is “pipeline” or “sales” quality crude oil and natural gas. Further processing or refining is almost always required before oil or natural gas is suitable for use as fuel or feedstock for petrochemical production. Production processing normally takes place in the “upstream” and “midstream” sectors, while refining and petrochemical processing is referred to as the “downstream” sector. Wellhead or upstream processing and treating equipment include a wide and diverse range of products. We manufacture custom-engineered, built-to-specification natural gas and oil processing and treating equipment. We also provide integrated solutions comprised of a combination of our products into a single offering, which typically consist of much larger equipment packages than standard equipment and are generally used in much larger scale production operations. The custom equipment sector is primarily driven by global economic trends, and the specifications for purchased equipment can vary significantly. Technology, engineering capabilities, project management, available manufacturing space and quality control standards are the key drivers in the custom equipment sector. Outsourcing Natural gas producers, transporters and processors choose to outsource their operations due to the benefits and flexibility of contract operations services. In particular, we believe outsourcing compression, production and processing operations to experienced operators like us offers customers: • • • access to our specialized personnel and technical skills, including engineers, operators and field service and maintenance employees, which we believe generally leads to improved production rates and increased throughput and therefore higher revenues and margins; the ability to increase their profitability by transporting or producing a higher volume of natural gas through decreased equipment downtime and reduced operating, maintenance and equipment costs by allowing us, as the service provider, to efficiently manage their operations; and the flexibility to deploy their capital on projects more directly related to their primary business of hydrocarbon exploration and production by reducing their investment in compression, production and processing equipment and related maintenance capital requirements. Oil and Natural Gas Industry Cyclicality and Volatility Changes in oil and natural gas exploration and production spending normally result in changes in demand for our products and services. However, we believe our contract operations business is less impacted by commodity prices than certain other energy service products and services because compression, production and processing services are necessary for oil and natural gas to be delivered from the wellhead to end users. Furthermore, our contract operations business is tied primarily to global oil and natural gas production and consumption trends, which are generally less cyclical in nature than exploration activities. Demand for oil and natural gas is cyclical and subject to fluctuations. This is primarily because the industry is driven by commodity demand and corresponding price movements. When oil and natural gas price increases occur, producers typically increase their capital expenditures, which generally results in greater activity levels and revenues for equipment providers to the oil and gas industry. During periods of lower oil or natural gas prices, producers typically decrease their capital expenditures, which generally results in lower activity levels and revenues for equipment providers to the oil and gas industry. 7 Seasonal Fluctuations Our results of operations have not historically reflected material seasonal tendencies and we do not believe that seasonal fluctuations will have a material impact on us in the foreseeable future. Markets, Customers and Competition Our global customer base consists primarily of companies engaged in all aspects of the oil and natural gas industry, including large integrated oil and natural gas companies, national energy companies, independent producers and natural gas processors, gatherers and pipeline operators. During the year ended December 31, 2018, MPLX LP (“MPLX”) accounted for approximately 15% of our total revenue. During the year ended December 31, 2017, Archrock accounted for approximately 12% of our total revenue and during the year ended December 31, 2016, Petroleo Brasileiro S.A. (“Petrobras”) accounted for approximately 10% of our total revenue. No other customer accounted for more than 10% of our revenue in 2018, 2017 and 2016. The loss of our business with MPLX, Archrock or Petrobras, unless offset by additional sales to other customers, or the inability or failure of MPLX, Archrock or Petrobras to meet its payment obligations could have an adverse effect on our business, results of operations and financial condition. We currently operate in approximately 25 countries. We have manufacturing facilities in the U.S., Singapore and the United Arab Emirates and offices in most of the major oil and gas regions around the world. The markets in which we operate are highly competitive. Overall, we experience considerable competition from companies that may be able to more quickly adapt to changes within our industry and changes in economic conditions as a whole and to more readily take advantage of available opportunities. We believe we are competitive with respect to price, equipment availability, customer service, flexibility in meeting customer needs, technical expertise, quality and reliability of our compression, processing and treating equipment and related services. We face vigorous competition throughout our businesses, with some companies competing with us in multiple business segments. In our product sales business, we have different competitors in the standard and custom-engineered equipment sectors. Competitors in the standard equipment sector include several large companies and a large number of small, regional fabricators. Our competition in the custom-engineered sector consists mainly of larger companies with the ability to provide integrated projects and product support after the sale. We expect to face increased competition as we seek to diversify our customer base and increase utilization of our service offerings. The separation and distribution agreement from the Spin-off contained certain noncompetition provisions addressing restrictions on our ability to provide compression contract operations and aftermarket services in the U.S. and on Archrock’s ability to provide compression contract operations and aftermarket services outside the U.S. and product sales to customers worldwide which expired on November 3, 2018. Sources and Availability of Raw Materials We manufacture natural gas compression and oil and natural gas processing and treating equipment to provide contract operations services and to sell to third parties from components which we acquire from a wide range of suppliers. These components represent a significant portion of the cost of our compression and processing and treating equipment products. Increases in raw material costs cannot always be offset by increases in our products’ sales prices. While many of our materials and components are available from multiple suppliers at competitive prices, we obtain some of the components, including compressors and engines, used in our products from a limited group of suppliers. We occasionally experience long lead times for components, including compressors and engines, from our suppliers and, therefore, we may at times make purchases in anticipation of future orders. 8 Environmental and Other Regulations Government Regulation Our operations are subject to stringent and complex U.S. federal, state, local and international laws and regulations that could have a material impact on our operations or financial condition. Our operations are regulated under a number of laws governing, among other things, discharges of substances into the air, ground and regulated waters, the generation, transportation, treatment, storage and disposal of hazardous and non-hazardous substances, disclosure of information about hazardous materials used or produced in our operations, and occupational health and safety. 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. In certain circumstances, laws may impose strict, 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 hazardous substances into the environment. In addition, it is not uncommon for 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 by us, leased by us or 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 were not under our control. These properties and the materials released or disposed thereon may be subject to various laws that could require us to remove or remediate historical property contamination, or to perform certain operations to prevent future contamination. 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. We believe the global trend in environmental regulation is 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. Employees As of December 31, 2018, we had approximately 4,300 employees. Many of our employees outside of the U.S. are covered by collective bargaining agreements. We generally consider our relationships with our employees to be satisfactory. Available Information Our website address is www.exterran.com. Our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports are available on our website, without charge, as soon as reasonably practicable after they are filed electronically with the Securities and Exchange Commission (the “SEC”). Information on our website is not incorporated by reference in this report or any of our other securities filings. Paper copies of our filings are also available, without charge, from Exterran Corporation, 4444 Brittmoore Road, Houston, Texas 77041, 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 Conduct; our Corporate Governance Principles; and the charters of our audit, compensation and nominating and corporate governance committees. 9 Item 1A.  Risk Factors As described in Part I (“Disclosure Regarding Forward-Looking Statements”), this report 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. The risk factors described below are not the only risks we face. Our business could also be affected by additional risks and uncertainties not currently known to us or that we currently consider to be immaterial. If any of the following risks or any other risks actually occurs, our business, financial condition, results of operations and cash flows could be negatively impacted. Risks Related to Our Business and Industry Low oil and natural gas prices could depress or reduce demand or pricing for our natural gas compression and oil and natural gas processing and treating equipment and services and, as a result, adversely affect our business. Our results of operations depend upon the level of activity in the global energy market, including oil and natural gas development, production, processing and transportation. Oil and natural gas exploration and development activity and the number of well completions typically decline when there is a sustained reduction in oil or natural gas prices or significant instability in energy markets. Even the perception of longer-term lower oil or natural gas prices by oil and natural gas exploration, development and production companies can result in their decision to cancel, reduce or postpone major expenditures or to reduce or shut in well production. Oil and natural gas prices and the level of drilling and exploration activity can be volatile. In periods of volatile commodity prices, the timing of any change in activity levels by our customers is difficult to predict. As a result, our ability to project the anticipated activity level for our business, and particularly our product sales segment may be limited. During periods of lower oil or natural gas prices, our customers typically decrease their capital expenditures, which generally results in lower activity levels. A reduction in demand for our products and services could force us to reduce our pricing substantially, which could have a material adverse effect on our business, financial condition, results of operations and cash flows. For example, due to the low oil and natural gas price environment during 2015 and the majority of 2016, our customers sought to reduce their capital and operating expenditure requirements, and as a result, the demand and pricing for the equipment we manufacture was adversely impacted. Recently, oil and natural gas prices have declined again, reversing a recent upward trend. We do not know whether this will be a prolonged decline and, if so, whether and to what degree it will impact the demand and pricing for the equipment we manufacture. Any reduction in demand for our products and services could result in our customers seeking to preserve capital by canceling contracts, canceling or delaying scheduled maintenance of their existing natural gas compression and oil and natural gas processing and treating equipment, ceasing commitments for new contract operations services contracts or new compression and oil and natural gas processing and treating equipment, or canceling or delaying orders for our products and services, any of which could have a material adverse effect on our business, financial condition, results of operations and cash flows. The erosion of the financial condition of our customers could adversely affect our business. Many of our customers finance their exploration and development activities through cash flows 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. 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 our customers seeking to preserve capital by reducing prices under existing contracts or cancelling contracts with us, determining not to renew contracts with us, cancelling or delaying scheduled maintenance of their existing natural gas compression and oil and natural gas processing and treating equipment, determining not to enter into contract operations agreements or not to purchase new compression and oil and natural gas processing and treating equipment, or determining to cancel or delay orders for our products and services. Any such action by our customers would reduce demand for our products and services. Reduced demand for our products and services could adversely affect our business, financial condition, results of operations 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. 10 Failure to timely and cost-effectively execute on larger projects could adversely affect our business. Some of our projects have a relatively larger size and scope than the majority of our projects, which can translate into more technically challenging conditions or performance specifications for our products and services. Contracts with our customers for these projects typically specify delivery dates, performance criteria and penalties for our failure to perform. Any failure to estimate the cost of and execute these larger projects in a timely and cost effective manner could have a material adverse effect on our business, financial condition, results of operations and cash flows. We may incur losses on fixed-price contracts, which constitute a significant portion of our business. In connection with projects and services performed under fixed-price contracts, we generally bear the risk of cost over-runs, operating cost inflation, labor availability and productivity, and supplier and subcontractor pricing and performance, unless additional costs result from customer-requested change orders. Under both our fixed-price contracts and our cost-reimbursable contracts, we may rely on third parties for many support services, and we could be subject to liability for their failures. Any failure to accurately estimate our costs and the time required for a fixed-price project at the time we enter into a contract could have a material adverse effect on our business, financial condition, results of operations and cash flows. Our operations in international markets are subject to many risks. The majority of our contract operations and aftermarket services businesses, and a portion of our product sales business, are conducted in countries outside the U.S. We currently operate in approximately 25 countries. With respect to any particular country in which we operate, the risks inherent in our activities may include the following, the occurrence of any of which could have a material adverse effect on our business, financial condition, results of operations and cash flows: • • • • • • • • • • • • • • • • • • • difficulties in managing international operations, including our ability to timely and cost effectively execute projects; unexpected changes in regulatory requirements, laws or policies by foreign agencies or governments; work stoppages; training and retaining qualified personnel in international markets; the burden of complying with multiple and potentially conflicting laws and regulations; tariffs and other trade barriers; actions by governments or national oil companies that result in the nullification or renegotiation on less than favorable terms of existing contracts, or otherwise result in the deprivation of contractual rights, and other difficulties in enforcing contractual obligations; governmental actions that: result in restricting the movement of property or that impede our ability to import or export parts or equipment; require a certain percentage of equipment to contain local or domestic content; or require certain local or domestic ownership, control or employee ratios in order to do business in or obtain special incentives or treatment in certain jurisdictions; potentially longer payment cycles; changes in political and economic conditions in the countries in which we operate, including general political unrest, the nationalization of energy related assets, civil uprisings, community protests, blockades, riots, kidnappings, violence associated with drug cartels and terrorist acts; potentially adverse tax consequences or tax law changes; currency controls or restrictions on repatriation of earnings; expropriation, confiscation or nationalization of property without fair compensation; the risk that our international customers may have reduced access to credit because of higher interest rates, reduced bank lending or a deterioration in our customers’ or their lenders’ financial condition; complications associated with installing, operating and repairing equipment in remote locations; limitations on insurance coverage; inflation; the geographic, time zone, language and cultural differences among personnel in different areas of the world; and difficulties in establishing new international offices and the risks inherent in establishing new relationships in foreign countries. 11 In addition, we may expand our business in international markets where we have not previously conducted business. The risks inherent in establishing new business ventures, especially in international markets where local customs, laws and business procedures present special challenges, may affect our ability to be successful in these ventures or avoid losses that could have a material adverse effect on our business, financial condition, results of operations and cash flows. The results of the United Kingdom’s referendum on withdrawal from the European Union may have a negative effect on global economic conditions, financial markets and our business. We have subsidiaries in the United Kingdom and elsewhere in Europe more generally; although these subsidiaries do not have significant active operations in the United Kingdom or Europe. In June 2016, a majority of voters in the United Kingdom elected to withdraw from the European Union (“E.U.”) in a national referendum (“Brexit”). The referendum was advisory, but the United Kingdom initiated its withdrawal process on March 29, 2017. As a result, the United Kingdom has until March 29, 2019 to negotiate the terms of its withdrawal from the E.U. After extensive negotiations, a deal was reached between the United Kingdom and the E.U., but this deal was recently rejected by the House of Commons in the United Kingdom. It is unclear whether a revised agreement will be approved by the House of Commons or whether the United Kingdom could be forced to leave the E.U. without an agreement in place regarding the various trade, immigration and other laws currently negotiated by the E.U. on behalf of its member states. As a result, Brexit has created significant uncertainty about the future relationship between the United Kingdom and the E.U. and has given rise to calls for certain regions within the United Kingdom to preserve their place in the E.U. by separating from the United Kingdom, as well as for the governments of other E.U. member states to consider withdrawal. The uncertainty surrounding the exact terms of any Brexit, or whether there will be a negotiated agreement at all, has rippled through the global economy and may in the future have a material and adverse effect on global economic conditions and the stability of the global financial markets, and significantly reduce global market liquidity and restrict the ability of key market participants to operate in certain financial markets. Asset valuations, currency exchange rates and credit ratings may be especially subject to increased market volatility as a result. Lack of clarity about applicable future laws, regulations or treaties as the United Kingdom finalizes its withdrawal, including financial laws and regulations, tax and free trade agreements, intellectual property rights, supply chain logistics, environmental, health and safety laws and regulations, immigration laws, employment laws and other rules that would apply to us and our subsidiaries could increase our costs, restrict our access to capital within the United Kingdom and the E.U., depress economic activity globally and decrease foreign direct investment in the United Kingdom. If the United Kingdom and the E.U. are unable to negotiate acceptable withdrawal terms or if other E.U. member states pursue withdrawal, barrier-free access between the United Kingdom and other E.U. member states or within the European Economic Area overall could be diminished or eliminated. This could affect, amongst other items, the ability to move cash between our United Kingdom and E.U. subsidiaries. Any of these factors could have a material adverse effect on our business, financial condition and results of operations. Our contract operations segment is dependent on companies that are controlled by the government in which it operates. The countries with our largest contract operations businesses include Argentina, Brazil and Mexico. We generate a significant portion of our revenue in these countries from national oil companies, including Yacimientos Petroliferos Fiscales in Argentina, Petrobras in Brazil and Petroleos Mexicanos in Mexico. Contracts with national oil companies may expose us to greater commercial, political and operational risks than we assume in other contracts. Our ability to resolve disputes or enforce contractual provisions may be negatively impacted by the significant bargaining leverage that national oil companies have over us. If our national oil company customers cancel some of our contracts and we are unable to secure new contracts on a timely basis and on substantially similar terms, or if a number of our contracts are renegotiated, it could adversely affect our business, financial position, results of operations or cash flows. 12 We are exposed to exchange rate fluctuations in the international markets in which we operate. We operate in many international countries and anticipate that there will be instances in which costs and revenues will not be exactly matched with respect to currency denomination. Gains and losses from the remeasurement of assets and liabilities that are receivable or payable in currencies other than our subsidiaries’ functional currency are included in our statements of operations. In addition, currency fluctuations cause the U.S. dollar value of our international results of operations and net assets to vary with exchange rate fluctuations. A decrease in the value of any of these currencies relative to the U.S. dollar could have a negative impact on our business, financial condition, results of operations or cash flows. As we expand geographically, we may experience economic loss and a negative impact on earnings or net assets solely as a result of foreign currency exchange rate fluctuations. In the future, we may utilize derivative instruments to manage the risk of fluctuations in foreign currency exchange rates that could potentially impact our future earnings and forecasted cash flows. However, the markets in which we operate could restrict the removal or conversion of the local or foreign currency, resulting in our inability to hedge against some or all of these risks. See further discussion of foreign exchange risks under Item 7A “Quantitative and Qualitative Disclosures about Market Risk” included elsewhere in this Annual Report. We are involved in governmental investigations, which may result in substantial financial and other penalties, and could adversely affect our business, financial condition and results of operations. Contemporaneously with filing the Form 8-K on April 26, 2016, we self-reported the errors and possible irregularities related to our Belleli EPC business to the SEC. Since then, we have been cooperating with the SEC in its investigation of this matter. The SEC’s investigation related to the circumstances giving rise to the restatement is continuing, and we are presently unable to predict the duration, scope or results or whether the SEC will commence any legal action. If we are found to have violated securities laws or other federal statutes, we may be subject to criminal and civil penalties and other remedial measures, including, but not limited to injunctive relief, disgorgement, civil and criminal fines and penalties, modifications to business practices including the termination or modification of existing business relationships, modifications of compliance programs and the retention of a monitor to oversee compliance. The imposition of any of these sanctions or remedial measures could have a material adverse impact on our reputation, business, results of operations, financial condition, liquidity and stock price. The termination of or any price reductions under certain of our contract operations services contracts could have a material impact on our business. The termination of or a demand by our customers to reduce prices under certain of our contract operations services contracts may lead to a reduction in our revenues and net income, which could have a material adverse effect upon our business, financial condition, results of operations and cash flows. In addition, we may be unable to renew, or enter into new, contracts with customers on favorable commercial terms, if at all. To the extent we are unable to renew our existing contracts or enter into new contracts on terms that are favorable to us or to successfully manage our overall contract mix over time, our business, results of operations and cash flows may be adversely impacted. Product sales backlog may be subject to unexpected adjustments and cancellations. The expected future revenues reflected in our product sales backlog may not be realized or, if realized, may not result in profits. Due to potential project cancellations or changes in project scope and schedule, we cannot predict with certainty when or if backlog will be performed. In addition, even where a project proceeds as scheduled, it is possible that contracted parties may default and fail to pay amounts owed to us or poor project performance could increase the cost associated with a project. Delays, suspensions, cancellations, payment defaults, scope changes and poor project execution could materially reduce the revenues and reduce or eliminate profits that we actually realize from projects in backlog. We may be at greater risk of delays, suspensions and cancellations during periods of low oil and natural gas prices. Reductions in our product sales backlog due to cancellation or modification by a customer or for other reasons may adversely affect, potentially to a material extent, the revenues and earnings we actually receive from contracts included in our backlog. Contracts in our product sales backlog provide for cancellation fees in the event customers cancel projects. These cancellation fees usually provide for reimbursement of our out-of-pocket costs, revenues for work performed prior to cancellation and a varying percentage of the profits we would have realized had the contract been completed. However, we typically have no contractual right upon cancellation to the total revenue reflected in our backlog. Projects may remain in our backlog for extended periods of time. If we experience significant project terminations, suspensions or scope adjustments to contracts reflected in our backlog, our financial condition, results of operations and cash flows may be adversely impacted. 13 From time to time, we are subject to various claims, litigation and other proceedings that could ultimately be resolved against us, requiring 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, both in 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. 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. We depend on particular suppliers and may be vulnerable to product shortages and price increases. Some of the components used in our products are obtained from a single source or a limited group of suppliers. Our reliance on these suppliers involves several risks, including price increases, quality and a potential inability to obtain an adequate supply of required components in a timely manner. Additionally, we occasionally experience long lead times from our sources for major components and may at times make purchases in anticipation of future business. We do not have long-term contracts with some of these sources, and the partial or complete loss of certain of these sources could have a negative impact on our results of operations and could damage our customer relationships. Further, a significant increase in the price of one or more of these components could have a negative impact on our results of operations. We face significant competitive pressures that may cause us to lose market share and harm our financial performance. Our businesses face intense competition and have low barriers to entry. Our competitors may be able to adapt more quickly to technological changes within our industry and changes in economic and market conditions and more readily take advantage of acquisitions and other opportunities. Our ability to renew or replace existing contract operations services contracts with our customers at rates sufficient to maintain current revenue and cash flows could be adversely affected by the activities of our competitors. If our competitors substantially increase the resources they devote to the development and marketing of competitive products, equipment or services or substantially decrease the price at which they offer their products, equipment or services, we may not be able to compete effectively. In addition, we could face significant competition from new entrants into the compression services and product sales businesses. Some of our existing competitors or new entrants may expand or develop new processing, treating and compression equipment that would create additional competition for the products, equipment or services we provide to our customers. 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 and manufacturing 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. Our employees work on projects that are inherently dangerous. If we fail to maintain safe work sites, we can be exposed to significant financial losses and reputational harm. Safety is a leading focus of our business, and our safety record is critical to our reputation and is of paramount importance to our employees, customers and stockholders. However, we often work on large-scale and complex projects which can place our employees and others near large mechanized equipment, moving vehicles, dangerous processes and in challenging environments. Although we have a functional group whose primary purpose is to implement effective quality, health, safety, environmental and security procedures throughout our company, if we fail to implement effective safety procedures, our employees and others may become injured, disabled or lose their lives, our projects may be delayed and we may be exposed to litigation or investigations. Unsafe conditions at project work sites also have the potential to increase employee turnover, increase project costs and raise our operating costs. Additionally, many of our customers require that we meet certain safety criteria to be eligible to bid for contracts and our failure to maintain adequate safety standards could result in reduced profitability, or lost project awards or customers. Any of the foregoing could result in financial losses or reputational harm, which could have a material adverse impact on our business, financial condition and results of operations. 14 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 and developer, 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. In addition, we are substantially self-insured for workers’ compensation, employer’s liability, property, auto liability, general liability and employee group health claims in view of the relatively high per-incident deductibles we absorb under our insurance arrangements for these risks. 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, financial condition and results of operations could be negatively impacted. We may be subject to risks arising from changes in technology. The supply chains in which we operate are subject to technological changes and changes in customer requirements. We may not successfully develop or implement new or modified types of products or technologies that may be required by our customers in the future. Further, the development of new technologies by competitors that may compete with our technologies could reduce demand for our products and affect our financial performance. Should we not be able to maintain or enhance the competitive values of our products or develop and introduce new products or technologies successfully, or if new products or technologies fail to generate sufficient revenues to offset research and development costs, our business, financial condition and operating results could be materially adversely affected. Our information technology infrastructure could be subject to service interruptions, data corruption, cyber-based attacks or network security breaches, which could result in the disruption of operations or the loss of data confidentiality. We rely on information technology networks and systems, including the internet and third-party service providers, to process, transmit and store electronic information, and to manage or support a variety of business processes and activities, including procurement, manufacturing, distribution, invoicing, collection, communication with our employees, customers, suppliers, dealers and suppliers, business acquisitions and other corporate transactions, compliance with regulatory, legal and tax requirements, and research and development. These information technology networks and systems may be susceptible to damage, disruptions or shutdowns due to failures during the process of upgrading or replacing software, databases or components, power outages, hardware failures or computer viruses. While we have business continuity plans and other safeguards in place, if these information technology systems suffer severe damage, disruption or shutdown and business continuity plans do not effectively resolve the issues in a timely manner, our business, financial condition, results of operations, and liquidity could be materially adversely affected. Further, we cannot ensure we have insurance coverages to cover these issues. In addition, information technology security threats and sophisticated cyber-based attacks, including, but not limited to, denial- of-service attacks, hacking, worms, “phishing” attacks, computer viruses, ransomware, malware, employee or insider error, malfeasance, social engineering, or physical breaches, may cause deliberate or unintentional damage, destruction or misuse, manipulation, denial of access to or disclosure of confidential or important information by our employees, suppliers or third- party service providers. Additionally, advanced persistent attempts to gain unauthorized access to our systems and those of third-party service providers we rely on are increasing in sophistication and frequency. We have experienced attacks on our information technology systems and networks, and we expect to continue to confront attempts by hackers and other third parties to disrupt or gain unauthorized access to our information technology systems and networks. These attacks to date have not resulted in unauthorized access to confidential information regarding our customers, suppliers or employees and have not had a material impact on our business. However, we could in the future experience attacks that materially disrupt our business or result in access to such confidential information about our customers, suppliers and employees or material information about our operations that could have a material adverse effect on our business, financial condition, results of operations or liquidity. We are continuously developing and enhancing our controls, processes, and practices designed to protect our systems, computers, software, data, and networks from attack, damage, or unauthorized access. This continued development and enhancement will require us to expend additional resources, including to investigate and remediate any information security vulnerabilities that may be detected. Despite our ongoing investments in security resources, talent, and business practices, we are unable to assure that these enhanced security measures will be effective. 15 We can provide no assurance that our efforts to actively manage technology risks potentially affecting our systems and networks will be successful in eliminating or mitigating risks to our systems, networks and data or in effectively resolving such risks when they materialize. A failure of or breach in information technology security of our own systems, or those of our third- party suppliers, could expose us and our employees, customers, dealers and suppliers to risks of misuse of information or systems, the compromise of confidential information, manipulation and destruction of data, defective products, production downtimes and operations disruptions. Any of these events in turn could adversely affect our reputation, competitive position, including loss of customers and revenue, business, results of operations and liquidity. In addition, such breaches in security could result in litigation, regulatory action and potential liability, as well as the costs and operational consequences of implementing further data protection measures. To conduct our operations, we regularly move data across national and state borders, and consequently we are subject to a variety of continuously evolving and developing laws and regulations in the U.S. and abroad regarding privacy, data protection and data security. The scope of the laws that may be applicable to us is often uncertain and may be conflicting, particularly with respect to foreign laws. For example, the European Union’s General Data Protection Regulation, which greatly increases the jurisdictional reach of E.U. law and adds a broad array of requirements for handling personal data, including the public disclosure of significant data breaches, became effective in May 2018. Other countries have enacted or are enacting data localization laws that require data to stay within their borders and various states are enacting additional data laws that may impact us. All of these evolving compliance and operational requirements impose significant costs that are likely to increase over time. 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, local and international laws and regulations relating to, for example, export controls, currency exchange, 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. From time to time, as part of our operations we may be subject to compliance audits by regulatory authorities in the various countries in which we operate. Our 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, any of which may have a negative impact on our financial condition, profitability and results of operations. Our international operations require us to comply with U.S. and international laws and regulations, including those involving anti-bribery and anti-corruption. For example, the U.S. Foreign Corrupt Practices Act and similar laws and regulations prohibit improper payments to foreign officials for the purpose of obtaining or retaining business or gaining any business advantage. We operate in many parts of the world that experience high levels of corruption, and our business brings us in frequent contact with foreign officials. Our compliance policies and programs mandate compliance with all applicable anti-corruption laws but may not be completely effective in ensuring our compliance. Our training and compliance program and our internal control policies and procedures may not always protect us from violations committed by our employees or agents. If we undergo an investigation of potential violations of anti-corruption laws or if we fail to comply with these laws, we may incur significant legal expenses or be subject to criminal and civil penalties and other sanctions and remedial measures, which could have a material adverse impact on our reputation, business, financial condition, results of operations and liquidity. We also are subject to other laws and regulations governing our operations, including regulations administered by the U.S. Department of Treasury’s Office of Foreign Asset Control and various non-U.S. government entities, including applicable export control regulations, economic sanctions on countries and persons and customs requirements. Trade control laws are complex and constantly changing. Our compliance policies and programs increase our cost of doing business and may not work effectively to ensure our compliance with trade control laws. If we undergo an investigation of potential violations of trade control laws by U.S. or foreign authorities or if we fail to comply with these laws, we may incur significant legal expenses or be subject to criminal and civil penalties and other sanctions and remedial measures, which could have a material adverse impact on our reputation, business, financial condition and results of operations. 16 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 internationally and, as a result, we are subject to the tax laws and regulations of U.S. federal, state, local and foreign governments. From time to time, various legislative or administrative initiatives may be proposed that could adversely affect our tax positions. In addition, U.S. federal, state, local and foreign tax laws and regulations are extremely complex and subject to varying interpretations. Moreover, economic and political pressures to increase tax revenue in various jurisdictions may make resolving tax disputes favorably more difficult. 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. Changes to our tax positions resulting from tax legislation and administrative initiatives or challenges from taxing authorities could adversely affect our results of operations and financial condition. U.S. federal, state, local and foreign 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 products. 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. For example, at the U.S. federal level, the U. S. Environmental Protection Agency (“EPA”) issued an Advance Notice of Proposed Rulemaking to collect data on chemicals used in hydraulic fracturing operations under Section 8 of the Toxic Substances Control Act, and proposed regulations under the CWA governing wastewater discharges from hydraulic fracturing and certain other natural gas operations. On March 26, 2015, the Bureau of Land Management (“BLM”) released a final rule that updates existing regulation of hydraulic fracturing activities on U.S. federal lands, including requirements for chemical disclosure, wellbore integrity and handling of flowback water. The final rule never went into effect due to pending litigation and on December 28, 2017, the BLM announced that it had rescinded the 2015 final rule, in part citing a review that found that each of the 32 states with federal oil and gas leases has regulations that already address hydraulic fracturing. 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, or prohibiting the performance of, drilling activities in general or hydraulic fracturing activities in particular. In addition, certain interest groups have also proposed ballot initiatives and constitutional amendments designed to restrict oil and natural-gas development generally and hydraulic fracturing in particular. For example, in 2018, Colorado voters ultimately rejected Proposition 112, a Colorado ballot initiative that would have drastically limited the use of hydraulic fracturing in Colorado. If new or more stringent 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. In countries outside of the U.S., including provincial, regional, tribal or local jurisdictions therein where we conduct operations, there may exist similar governmental restrictions or controls on our customers’ hydraulic fracturing activities, which, if such restrictions or controls exist or are adopted in the future, our foreign customers may face the same challenges as our U.S. customers. Any such restrictions, domestically or foreign, could reduce demand for our products, and as a result could have a material adverse effect on our business, financial condition, results of operations and cash flows. 17 Our customers’ inability to acquire adequate supplies of water or dispose of or recycle the water used in operations, could result in operating restrictions or delays in the completion of oil and natural gas wells, and adversely affect demand for our products. Oil and gas development activities require the use of water. For example, the hydraulic fracturing process to produce commercial quantities of oil and natural gas from many reservoirs requires the use and disposal of significant quantities of water. In certain areas, there may be a scarcity of water for drilling activities due to various factors, including insufficient local aquifer capacity or government regulations restricting the use of water. Our customers’ inability to secure sufficient amounts of water or dispose of or recycle the water used in operations, could adversely impact our or our customers’ operations in certain areas. The imposition of new environmental initiatives and regulations, could further restrict our customers’ ability to conduct certain operations disposal of waste, including, but not limited to, produced water, drilling fluids and other materials associated with the exploration, development or production of oil and natural gas. Any such restrictions could reduce demand for our products, and as a result could have a material adverse effect on our business, financial condition, results of operations and cash flows. We are subject to a variety of environmental, health and safety 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, local and international laws and regulations relating to the environment, and worker health and safety. 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 administrative, civil and criminal enforcement measures, including assessment of monetary penalties, imposition of remedial requirements and issuance of injunctions as to future compliance. Certain of these laws also may impose joint and several and 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 may have been 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. 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. These permits and authorizations may contain numerous compliance requirements, including monitoring and reporting obligations and operational restrictions, such as emission limits, which may be onerous or costly to comply with. 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. The modification or interpretation of existing environmental, health and safety laws or regulations, the more vigorous enforcement of existing laws or regulations, or the adoption of new 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. 18 Global climate change is an increased international concern and could increase operating costs or reduce the demand for our products and services. Continuing political and social attention to the issue of global climate change has resulted in both existing and pending international agreements and national, regional or local legislation and regulatory measures to limit greenhouse gas emissions, such as cap and trade regimes, carbon taxes, restrictive permitting, increased fuel efficiency standards and incentives or mandates for renewable energy. For example, in December 2015, 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 that prepared an agreement requiring member countries to review and represent a progression in their intended greenhouse gas emission reduction goals every five years beginning in 2020. While the U.S. announced its intention to withdraw from the Paris Agreement, several U.S. state and local governments and major corporations headquartered in the U.S. announced an intent to honor the U.S.’s commitments. Several U.S. cities, counties and state governments have also filed lawsuits against certain oil and gas companies seeking compensatory damages and equitable relief to abate alleged climate change impacts. To date, none of these suits has been successful, and we are not a party to these proceedings. In the U.S., the EPA has also begun to regulate greenhouse gas emissions under the federal Clean Air Act and regulatory agencies and legislative bodies in other countries where we operate have adopted greenhouse gas emission reduction programs. The adoption of new or more stringent legislation or regulatory programs restricting greenhouse gas emissions in any of the jurisdictions where we or our customers operate could require us to incur higher operating costs or increase the cost of, and thus reduce the demand for, the hydrocarbon products of our customers. These increased costs or reduced demand could have an adverse effect on our business, profitability or results of operations. Further, some scientists have concluded that increasing greenhouse gas concentrations in the atmosphere may produce physical effects, such as increased severity and frequency of storms, droughts, floods and other climate events. To the extent there are significant changes in the Earth’s climate in the markets we serve or the areas where our assets reside, we could incur increased expenses, our operations could be materially impacted, and demand for our products and services could fall. Demand for our products and services may also be adversely affected by conservation plans and efforts undertaken in response to global climate change. Many governments also provide, or may in the future provide, tax advantages and other subsidies to support the use and development of alternative energy technologies. Our operations and the demand for our products and services or our customers’ products could be materially impacted by the development and adoption of these technologies. Recently, activists concerned about the potential effects of climate change have directed their attention at sources of funding for companies engaged in business involving fossil fuels, which has resulted in certain financial institutions, investment funds and other sources of capital restricting or eliminating their investment in oil and natural gas activities. This could make it more difficult for our customers to secure funding for exploration and production or midstream energy business activities. Risks Related to Our Level of Indebtedness Our outstanding debt obligations could limit our ability to fund future growth and operations and increase our exposure to risk during adverse economic conditions. At December 31, 2018, we had a long-term debt balance of $403.8 million. 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 and those listed in the Disclosure Regarding Forward-Looking Statements section included in Part I of this Annual report. Our debt and associated commitments could have important adverse consequences. 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, investments, acquisitions or other corporate requirements; increase our vulnerability to interest rate fluctuations because the interest payments on borrowings under our revolving credit facility are based upon variable interest rates and can adjust based upon certain financial covenant ratios; 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 borrow additional funds in the future. 19 Covenants in our debt agreements may restrict our ability to operate our business. Our credit agreement, consisting of a $700.0 million revolving credit facility expiring in October 2023, contains various covenants with which we, Exterran Energy Solutions, L.P. (“EESLP”), our wholly owned subsidiary, and our respective restricted subsidiaries must comply, including, but not limited to, limitations on the incurrence of indebtedness, investments, liens on assets, repurchasing equity, making distributions, transactions with affiliates, mergers, consolidations, dispositions of assets and other provisions customary in similar types of agreements. Additionally, we are required to maintain certain financial covenant ratios. If we fail to remain in compliance with these restrictions and financial covenants, we would be in default under our credit agreement. In addition, if we experience a material adverse effect on our assets, liabilities, financial condition, business or operations that, taken as a whole, impact our ability to perform our obligations under our credit agreement, this could lead to a default. A default under one of our debt agreements might trigger cross-default provisions under our other debt agreement, which would accelerate our obligation to repay our indebtedness under those agreements. If the repayment obligations on any of our indebtedness 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. As of December 31, 2018, we were in compliance with all financial covenants under our credit agreement. As a result of a covenant restriction included in our credit agreement, $578.4 million of the $608.3 million of undrawn capacity under our revolving credit facility was available for additional borrowings as of December 31, 2018. Changes in the method pursuant to which the LIBOR rates are determined and potential phasing out of LIBOR after 2021 may adversely affect our results of operations. LIBOR and certain other “benchmarks” are the subject of recent national, international and other regulatory guidance and proposals for reform. These reforms may cause such benchmarks to perform differently than in the past or have other consequences which cannot be predicted. In particular, on July 27, 2017, the United Kingdom’s Financial Conduct Authority, which regulates LIBOR, publicly announced that it intends to stop persuading or compelling banks to submit LIBOR rates after 2021. It is unclear whether, at that time, LIBOR will cease to exist or if new methods of calculating LIBOR will be established. As of December 31, 2018, $35.0 million of the borrowings under our revolving credit facility had interest rate payments determined directly or indirectly based on LIBOR. Any uncertainty regarding the continued use and reliability of LIBOR as a benchmark interest rate could adversely affect the performance of LIBOR relative to its historic values. If the methods of calculating LIBOR change from current methods for any reason, or if LIBOR ceases to perform as it has historically, our interest expense associated with our outstanding indebtedness or any future indebtedness we incur may increase. Further, if LIBOR ceases to exist, we may be forced to substitute an alternative reference rate under our revolving credit facility or rely on base rate borrowings in lieu of LIBOR-based borrowings. At this point, it is not clear what, if any, alternative reference rate may replace LIBOR, however, any such alternative reference rate may increase the interest expense associated with our existing or future indebtedness. Any of these occurrences could materially and adversely affect our borrowing costs, business and results of operations. We may increase our debt or raise additional capital in the future, which could affect our financial condition, may decrease our profitability or could dilute our shareholders. We may increase our debt or raise additional capital in the future, subject to restrictions in our debt agreements. If our cash flow from operations is less than we anticipate, or if our cash requirements are more than we expect, we may require more financing. However, debt or equity financing may not be available to us on terms acceptable to us, if at all. If we incur additional debt or raise equity through the issuance of preferred stock, the terms of the debt or preferred stock issued may give the holders rights, preferences and privileges senior to those of holders of our common stock, particularly in the event of liquidation. The terms of the debt may also impose additional and more stringent restrictions on our operations than we currently have. If we raise funds through the issuance of additional equity, our shareholders’ ownership in us would be diluted. If we are unable to raise additional capital when needed, it could affect our financial health, which could negatively affect our shareholders. 20 Risks Related to the Spin-off We are subject to continuing contingent tax liabilities of Archrock. Certain tax liabilities of Archrock may become our obligations. Pursuant to the U.S. Internal Revenue Code and the related rules and regulations, each corporation that was a member of the Archrock consolidated U.S. federal income tax reporting group during any taxable period or portion of any taxable period ending on or before the effective time of the Spin-off is jointly and severally liable for the U.S. federal income tax liability of the entire Archrock consolidated tax reporting group for that taxable period. In connection with the Spin-off, we entered into a tax matters agreement with Archrock that allocates the responsibility for prior period taxes of the Archrock consolidated tax reporting group between us and Archrock. If Archrock is unable to pay any prior period taxes for which it is responsible, we could be required to pay the entire amount of such taxes. Our prior and continuing relationship with Archrock exposes us to risks attributable to businesses of Archrock. Archrock is obligated to indemnify us for losses that third parties may seek to impose upon us or our affiliates for liabilities relating to the business of Archrock that are incurred through a breach of the separation and distribution agreement or any ancillary agreement by Archrock or its affiliates other than us, or losses that are attributable to Archrock in connection with the Spin-off or are not expressly assumed by us under our agreements with Archrock. Any claims made against us that are properly attributable to Archrock in accordance with these arrangements would require us to exercise our rights under our agreements with Archrock to obtain payment from Archrock. We are exposed to the risk that, in these circumstances, Archrock cannot, or will not, make the required payment. In connection with our separation from Archrock, Archrock will indemnify us for certain liabilities, and we will indemnify Archrock for certain liabilities. If we are required to act on these indemnities to Archrock, we may need to divert cash to meet those obligations, and our financial results could be negatively impacted. In the case of Archrock’s indemnity, there can be no assurance that the indemnity will be sufficient to insure us against the full amount of such liabilities, or as to Archrock’s ability to satisfy its indemnification obligations. Pursuant to the separation and distribution agreement and other agreements with Archrock, Archrock has agreed to indemnify us for certain liabilities, and we have agreed to indemnify Archrock for certain liabilities, in each case for uncapped amounts. Under the separation and distribution agreement, we and Archrock will generally release the other party from all claims arising prior to the Spin-off that relate to the other party’s business, subject to certain exceptions. Also pursuant to the separation and distribution agreement, we have agreed to use our commercially reasonable efforts to remove Archrock as a party to certain of our contracts with third parties. In the event that Archrock remains as a party, we expect to indemnify Archrock for any liabilities relating to such contracts. Indemnities that we may be required to provide Archrock will not be subject to any cap, may be significant and could negatively impact our business, particularly indemnities relating to our actions that could impact the tax-free nature of the Spin-off. With respect to Archrock’s agreement to indemnify us, there can be no assurance that the indemnity from Archrock will be sufficient to protect us against the full amount of such liabilities, or that Archrock will be able to fully satisfy its indemnification obligations. Moreover, even if we ultimately succeed in recovering from Archrock any amounts for which we are held liable, we may be temporarily required to bear these losses ourselves. Each of these risks could negatively affect our business, cash flows, results of operations and financial condition. Risks Related to Our Common Stock The market price and trading volume of our common stock may be volatile. The market price of our stock may be influenced by many factors, some of which are beyond our control, including the following: • • • • • • the inability to meet the financial estimates of analysts who follow our common stock; strategic actions by us or our competitors; announcements by us or our competitors of significant contracts, acquisitions, joint marketing relationships, joint ventures or capital commitments; variations in our quarterly operating results and those of our competitors; general economic and stock market conditions; risks relating to our business and our industry, including those discussed above; 21 • • • changes in conditions or trends in our industry, markets or customers; cyber-attacks or terrorist acts; future sales of our common stock or other securities; • material weaknesses in our internal control over financial reporting; and • investor perceptions of the investment opportunity associated with our common stock relative to other investment alternatives. These broad market and industry factors may materially reduce the market price of our common stock, regardless of our operating performance. In addition, price volatility may be greater if the public float and trading volume of our common stock is low. Our amended and restated certificate of incorporation designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our stockholders, which could limit our stockholders’ ability to choose the judicial forum for disputes with us or our directors, officers or other employees. Our amended and restated certificate of incorporation provides that, unless we consent in writing to the selection of an alternate forum, the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any director, officer or other employee to us or our stockholders, (iii) any action asserting a claim arising pursuant to any provision of the Delaware General Corporation Law, our amended and restated certificate of incorporation or our bylaws, in each case, as amended from time to time, or (iv) any action asserting a claim governed by the internal affairs doctrine, shall be the Court of Chancery of the State of Delaware, in all cases subject to the court’s having personal jurisdiction over the indispensable parties named as defendants. Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock is deemed to have received notice of and consented to the foregoing provision. This forum selection provision may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable or cost-effective for disputes with us or our directors, officers or other employees, which may discourage such lawsuits against us and our directors, officers and employees. Item 1B.  Unresolved Staff Comments None. Item 2.  Properties The following table describes the material facilities we owned or leased as of December 31, 2018: Location Houston, Texas Camacari, Brazil Port Harcourt, Nigeria Neuquen, Argentina Reynosa, Mexico Santa Cruz, Bolivia Bangkok, Thailand Houston, Texas Hamriyah Free Zone, UAE Broken Arrow, Oklahoma Singapore, Singapore Status Owned Owned Leased Owned Owned Leased Leased Owned Leased Owned Leased Uses Corporate office and product sales 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 Aftermarket services Product sales Product sales Product sales Product sales Square Feet 261,609 86,112 47,333 43,233 28,912 22,017 51,667 301,127 212,742 145,755 111,693 22 Item 3.  Legal Proceedings In the ordinary course of business, we are involved in various pending or threatened legal actions. While management is unable to predict the ultimate outcome of these actions, it believes that any ultimate liability arising from any of these actions will not have a material adverse effect on our financial position, results of operations or cash flows. 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 financial position, results of operations or cash flows. Contemporaneously with filing the Form 8-K on April 26, 2016, we self-reported the errors and possible irregularities at Belleli EPC to the SEC. Since then, we have been cooperating with the SEC in its investigation of this matter. The SEC’s investigation related to the circumstances giving rise to the restatement is continuing, and we are presently unable to predict the duration, scope or results or whether the SEC will commence any legal action. 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 Our common stock is listed and traded on the New York Stock Exchange under the stock symbol “EXTN.” As of February 19, 2019, there were approximately 987 holders of record of our common stock. We have not paid, and we do not currently anticipate paying cash dividends on our common stock. Instead, we intend to retain our future earnings to support the growth and development of our business. The declaration of any future cash dividends and, if declared, the amount of any such dividends, will be subject to our financial condition, earnings, capital requirements, financial covenants, applicable law and other factors our board of directors deems relevant. Therefore, there can be no assurance as to what level of dividends, if any, will be paid in the future. For disclosures regarding securities authorized for issuance under our equity compensation plans, see Part III, Item 12 (“Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters”) of this report. 23   Comparison of Cumulative Total Return The performance graph below shows the cumulative total stockholder return on our common stock, compared with the S&P 500 Composite Stock Price Index (the “S&P 500 Index”) and the Oilfield Service Index (the “OSX Index”) over the period from November 4, 2015, the first day of trading volume, to December 31, 2018. The results are based on an investment of $100 in each of our common stock, the S&P 500 Index and the OSX Index. The graph assumes the reinvestment of dividends and adjusts all closing prices and dividends for stock splits. Comparison of Cumulative Total Return $250 $200 $150 $100 $50 $0 11/04/15 12/31/15 12/31/16 12/31/17 12/31/18 Exterran Corporation S&P 500 Index OSX Index The performance graph shall not be deemed incorporated by reference by any general statement incorporating by reference this Annual Report on 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. Unregistered Sales of Equity Securities and Use of Proceeds None. 24 Repurchase of Equity Securities The following table summarizes our repurchases of equity securities during the three months ended December 31, 2018: Period October 1, 2018 - October 31, 2018 November 1, 2018 - November 30, 2018 December 1, 2018 - December 31, 2018 Total Total Number of Shares Repurchased (1) Average Price Paid Per Unit Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Maximum Number of Shares yet to be Purchased Under  the Publicly Announced  Plans or Programs — $ 42,231 1,029 — 21.61 19.83 43,260 $ 21.57 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 vesting of restricted stock awards during the period. Share Repurchase Program On February 20, 2019, our board of directors approved a share repurchase program, under which the Company is authorized to purchase up to $100.0 million of its outstanding common stock through February 2022. The share repurchase program may be effected through a variety of methods, including open-market purchases and Rule 10b5-1 trading plans among others. The amount and timing of any repurchases will depend on general market conditions, among other factors, and may be discontinued at any time. 25  Item 6.  Selected Financial Data The table below presents certain selected historical consolidated and combined financial information as of and for each of the years in the five-year period ended December 31, 2018. The selected historical consolidated financial data as of December 31, 2018 and 2017 and the selected historical consolidated financial data for the years ended December 31, 2018, 2017 and 2016 has been derived from our audited Financial Statements included elsewhere in this report. The selected historical consolidated and combined financial data as of December 31, 2016, 2015 and 2014 and for the years ended December 31, 2015 and 2014 has been derived from our financial statements not included in this report. Our Spin-off from Archrock was completed on November 3, 2015. Selected financial data for periods prior to the Spin-off represent the combined results of Archrock’s international services and product sales businesses. The combined financial data may not be indicative of our future performance and does not necessarily reflect the financial condition and results of operations we would have realized had we operated as a separate, stand-alone entity during the periods presented, including changes in our operations as a result of our Spin-off from Archrock. As discussed in Note 4 to our Financial Statements, the results from continuing operations for all periods presented exclude the results of our Venezuelan contract operations business, Canadian contract operations and aftermarket services businesses (“Canadian Operations”), Belleli CPE business (the manufacture of critical process equipment for refinery and petrochemical facilities) and Belleli EPC business (the manufacture of tanks for tank farms and the manufacture of evaporators and brine heaters for desalination plants). Those results are reflected in discontinued operations for all periods presented. The selected financial data presented below should be read together with Management’s Discussion and Analysis of Financial Condition and Results of Operations and the Financial Statements contained in this report. 26 (in thousands, except per share data) 2018 2017 2016 2015 2014 Years Ended December 31, Statement of Operations Data: Revenues Cost of sales (excluding depreciation and amortization expense) Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges (recoveries), net Restructuring and other charges Interest expense Equity in income of non-consolidated affiliates Other (income) expense, net Income (loss) before income taxes Provision for income taxes Income (loss) from continuing operations Income (loss) from discontinued operations, net of tax Net income (loss) Income (loss) from continuing operations per common share: (1) $ 1,360,856 $ 1,215,294 $ 905,397 $ 1,687,264 $ 1,986,184 977,428 178,401 123,922 3,858 (276) 1,997 29,217 — 6,484 39,825 39,433 392 24,462 24,854 868,154 176,318 107,824 5,700 3,419 3,189 34,826 — (975) 16,839 22,695 (5,856) 39,736 33,880 596,406 157,485 132,886 14,495 18,879 22,038 34,181 (10,403) (13,046) (47,524) 124,242 (171,766) (56,171) (227,937) 1,189,361 1,395,007 210,483 146,318 20,788 — 31,315 7,272 (15,152) 35,516 61,363 39,438 21,925 4,723 26,648 252,130 163,538 3,851 — — 1,878 (14,553) 5,572 178,761 79,210 99,551 15,741 115,292 Basic Diluted $ $ 0.01 0.01 (0.17) $ (0.17) (4.97) $ (4.97) $ 0.64 0.64 2.90 2.90 Weighted average common shares outstanding used in income (loss) from continuing operations per common share: (1) Basic Diluted Other Financial Data: Total gross margin (2) EBITDA, as adjusted (2) Capital expenditures: Contract Operations Equipment: Growth (3) Maintenance (4) Other Balance Sheet Data: Cash and cash equivalents Working capital (5) (6) Property, plant and equipment, net Total assets (6) Long-term debt (7) Total stockholders’ equity (6) (7) 35,433 35,489 34,959 34,959 34,568 34,568 34,288 34,304 34,286 34,286 $ 383,428 $ 347,140 $ 308,991 $ 497,903 $ 591,177 205,498 173,155 155,993 282,031 338,050 $ 186,240 $ 104,909 $ 53,005 $ 105,169 $ 6,616 22,252 15,691 11,073 14,440 6,225 27,282 22,893 97,931 24,377 24,164 $ 19,300 $ 49,145 $ 35,678 $ 29,032 $ 39,361 108,746 901,577 134,048 822,279 177,824 790,922 408,488 846,977 366,135 890,627 1,567,054 1,460,807 1,374,778 1,788,396 1,999,303 403,810 552,821 368,472 554,786 348,970 556,771 525,593 805,936 1,107 1,364,335 (1) For the periods prior to November 3, 2015, the average number of common shares outstanding used to calculate basic and diluted net income (loss) from continuing operations per common share was based on 34,286,267 shares of our common stock that were distributed by Archrock in the Spin-off on November 3, 2015. 27 (2) (3) Total gross margin and EBITDA, as adjusted, are non-GAAP financial measures. Total gross margin and EBITDA, as adjusted, are defined, reconciled to income (loss) before income taxes and net income (loss), respectively, and discussed further below under “Non-GAAP Financial Measures.” Growth capital expenditures are made to expand or to replace partially or fully depreciated assets or to expand the operating capacity or revenue generating capabilities of existing or new assets, whether through construction, acquisition or modification. The majority of our growth capital expenditures are related to installation costs on contract operations projects and acquisition costs of new compressor units and processing and treating equipment that we add to our contract operations fleet. In addition, growth capital expenditures can include the upgrading of major components on an existing compressor unit where the current configuration of the compressor unit is no longer in demand and the compressor unit is not likely to return to an operating status without the capital expenditures. These latter expenditures substantially modify the operating parameters of the compressor unit such that it can be used in applications for which it previously was not suited. (4) Maintenance capital expenditures are made to maintain the existing operating capacity of our assets and related cash flows further extending the useful lives of the assets. Maintenance capital expenditures are related to major overhauls of significant components of a compressor unit, such as the engine, compressor and cooler, that return the components to a “like new” condition, but do not modify the applications for which the compressor unit was designed. (5) Working capital is defined as current assets minus current liabilities. (6) Amounts include balance sheet data for discontinued operations. (7) Pursuant to the separation and distribution agreement with Archrock and certain of our and Archrock’s respective affiliates, on November 3, 2015, we transferred $532.6 million of net proceeds from borrowings under our credit facility to Archrock to allow it to repay a portion of its indebtedness in connection with the Spin-off. Non-GAAP Financial Measures We define gross margin as total revenue less cost of sales (excluding depreciation and amortization expense). We evaluate the performance of each of our segments based on gross margin. Total 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 expense), 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 selling, general and administrative (“SG&A”) activities, the impact of our financing methods and income taxes. Depreciation and amortization expense may not accurately reflect the costs required to maintain and replenish the operational usage of our assets and therefore may not portray the costs from current operating activity. As an indicator of our operating performance, total gross margin should not be considered an alternative to, or more meaningful than, income (loss) before income taxes as determined in accordance with generally accepted accounting principles in the U.S. (“GAAP”). Our gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate gross margin in the same manner. Total gross margin has certain material limitations associated with its use as compared to income (loss) before income taxes. These limitations are primarily due to the exclusion of interest expense, depreciation and amortization expense, SG&A expense, impairments and restructuring and other charges. Each of these excluded expenses is material to our statements of operations. 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 expenses are necessary to support our operations and required corporate activities. To compensate for these limitations, management uses total gross margin, a non-GAAP measure, as a supplemental measure to other GAAP results to provide a more complete understanding of our performance. 28 The following table reconciles our net income (loss) before income taxes to total gross margin (in thousands): Years Ended December 31, Income (loss) before income taxes Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges (recoveries), net Restructuring and other charges Interest expense Equity in income of non-consolidated affiliates Other (income) expense, net Total gross margin $ $ 2018 39,825 178,401 123,922 3,858 (276) 1,997 29,217 — 6,484 $ 383,428 $ 2017 16,839 176,318 107,824 5,700 3,419 3,189 34,826 — (975) 347,140 $ 2016 (47,524) $ 157,485 132,886 14,495 18,879 22,038 34,181 (10,403) (13,046) 308,991 $ $ 2015 61,363 210,483 146,318 20,788 — 31,315 7,272 (15,152) 35,516 2014 178,761 252,130 163,538 3,851 — — 1,878 (14,553) 5,572 $ 497,903 $ 591,177 We define EBITDA, as adjusted, as net income (loss) excluding income (loss) from discontinued operations (net of tax), cumulative effect of accounting changes (net of tax), income taxes, interest expense (including debt extinguishment costs), depreciation and amortization expense, impairment charges, restructuring and other charges, non-cash gains or losses from foreign currency exchange rate changes recorded on intercompany obligations, expensed acquisition costs and other items. We believe EBITDA, as adjusted, is an important measure of operating performance because it allows management, investors and others to evaluate and compare our core operating results from period to period by removing the impact of our capital structure (interest expense from our outstanding debt), asset base (depreciation and amortization), our subsidiaries’ capital structure (non-cash gains or losses from foreign currency exchange rate changes on intercompany obligations), tax consequences, impairment charges, restructuring and other charges, expensed acquisition costs and other items. Management uses EBITDA, as adjusted, as a supplemental measure to review current period operating performance, comparability measures and performance measures for period to period comparisons. In addition, the compensation committee has used EBITDA, as adjusted, in evaluating the performance of the Company and management and in evaluating certain components of executive compensation, including performance-based annual incentive programs. Our EBITDA, as adjusted, may not be comparable to a similarly titled measure of another company because other entities may not calculate EBITDA in the same manner. EBITDA, as adjusted, is not a measure of financial performance under GAAP and should not be considered in isolation or as an alternative to net income (loss), cash flows from operating activities or any other measure determined in accordance with GAAP. Items excluded from EBITDA, as adjusted, are significant and necessary components to the operation of our business and therefore, EBITDA, as adjusted, should only be used as a supplemental measure of our operating performance. 29 The following table reconciles our net income (loss) to EBITDA, as adjusted (in thousands): Net income (loss) (Income) loss from discontinued operations, net of tax Depreciation and amortization Long-lived asset impairment Restatement related charges (recoveries), net Restructuring and other charges Investment in non-consolidated affiliates impairment Proceeds from sale of joint venture assets Interest expense (Gain) loss on currency exchange rate remeasurement of intercompany balances Loss on sale of businesses Penalties from Brazilian tax programs Provision for income taxes EBITDA, as adjusted Off-Balance Sheet Arrangements We have no material off-balance sheet arrangements. Years Ended December 31, $ $ 2018 24,854 (24,462) 123,922 2017 33,880 (39,736) 107,824 3,858 (276) 1,997 — — 5,700 3,419 3,189 — — 29,217 34,826 5,241 1,714 — (516) 111 1,763 2016 $ (227,937) $ 56,171 132,886 14,495 18,879 22,038 — (10,403) 34,181 (8,559) — — 2015 26,648 (4,723) 146,318 20,788 — 31,315 33 (15,185) 7,272 30,127 — — 2014 $ 115,292 (15,741) 163,538 3,851 — — 197 (14,750) 1,878 3,614 961 — 39,433 $ 205,498 22,695 $ 173,155 124,242 $ 155,993 39,438 $ 282,031 79,210 $ 338,050 30   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 report. The following discussion includes forward-looking statements that involve certain risks and uncertainties. See Part I (“Disclosure Regarding Forward-Looking Statements”) and Part I, Item 1A (“Risk Factors”) in this report.  Overview We are a global systems and process company offering solutions in the oil, gas, water and power markets. We are a leader in natural gas processing and treatment and compression products and services, providing critical midstream infrastructure solutions to customers throughout the world. Outside the U.S., we are a leading provider of full-service natural gas contract compression and a supplier of aftermarket parts and services. We provide our products and services to a global customer base consisting of companies engaged in all aspects of the oil and natural gas industry, including large integrated oil and natural gas companies, national oil and natural gas companies, independent oil and natural gas producers and oil and natural gas processors, gatherers and pipeline operators. We operate in three primary business lines: contract operations, aftermarket services and product sales. The nature and inherent interactions between and among our business lines provide us with opportunities to cross-sell and offer integrated product and service solutions to our customers. In our contract operations business line, we provide compression and processing and treating services through the operation of our natural gas compression equipment and crude oil and natural gas production and process equipment for our customers. In our aftermarket services business line, we sell parts and components and provide operations, maintenance, repair, overhaul, upgrade, startup and commissioning and reconfiguration services to customers who own their own oil and natural gas compression, production, processing, treating and related equipment. In our product sales business line, we design, engineer, manufacture, install and sell natural gas compression packages as well as equipment used in the treating and processing of crude oil and natural gas to our customers throughout the world and for use in our contract operations business line. We also offer our customers, on either a contract operations basis or a sale basis, the engineering, design, project management, procurement and construction services necessary to incorporate our products into production, processing and compression facilities, which we refer to as integrated projects. Our chief operating decision maker manages business operations, evaluates performance and allocates resources based on the Company’s three primary business lines, which are also referred to as our segments. In order to more efficiently and effectively identify and serve our customer needs, we classify our worldwide operations into four geographic regions. The North America region is primarily comprised of our operations in Mexico and the U.S. The Latin America region is primarily comprised of our operations in Argentina, Bolivia and Brazil. The Middle East and Africa region is primarily comprised of our operations in Bahrain, Iraq, Oman, Nigeria and the United Arab Emirates. The Asia Pacific region is primarily comprised of our operations in China, Indonesia, Thailand and Singapore. Industry Conditions and Trends Our business environment and corresponding operating results are affected by the level of energy industry spending for the exploration, development and production of oil and natural gas reserves. Spending by oil and natural gas exploration and production companies is dependent upon these companies’ forecasts regarding the expected future supply, demand and pricing of oil and natural gas products as well as their estimates of risk-adjusted costs to find, develop and produce reserves. Although we believe our contract operations business, and to a lesser extent our product sales business, is typically less impacted by short-term commodity prices than certain other energy products and service providers, changes in oil and natural gas exploration and production spending normally result in changes in demand for our products and services. Industry observers anticipate strong continued global demand for hydrocarbons, including demand for liquefied natural gas. However, customer cash flows and returns on capital could drive customer investment priorities. Industry observers believe shareholders are encouraging management teams of energy producers to focus operational and compensation strategies on returns and cash flow generation rather than solely on production growth. To accomplish these strategies, energy producers may need to better prioritize capital spending, which could impact resource allocation and ultimately the amount of new projects and capital spending by our customers. 31   Our Performance Trends and Outlook Our revenue, earnings and financial position are affected by, among other things, market conditions that impact demand and pricing for natural gas compression and oil and natural gas production and processing and our customers’ decisions to use our products and services, use our competitors’ products and services or own and operate the equipment themselves. Historically, oil, natural gas and natural gas liquids and the level of drilling and exploration activity in North America have been volatile. The Henry Hub spot price for natural gas was $3.25 per MMBtu at December 31, 2018, which was 12% lower than prices at both December 31, 2017 and 2016, and the U.S. natural gas liquid composite price was $6.98 per MMBtu for the month of November 2018, which was 11% lower than prices for the month of December 2017 and 5% higher than prices for the month of December 31, 2016, respectively. In addition, the West Texas Intermediate crude oil spot price as of December 31, 2018 was 25% and 16% lower than prices at December 31, 2017 and 2016, respectively. Increased stability of oil, natural gas and natural gas liquids prices in 2017 and most of 2018 encouraged increased customer spending and investments in equipment that have led to increased activity and bookings in North America. Booking activity levels for our manufactured products in North America during the year ended December 31, 2018 were $916.2 million, which represents increases of 10% and 177% compared to the years ended December 31, 2017 and 2016, respectively, and our North America product sales backlog as of December 31, 2018 was $542.3 million, which represents increases of 29% and 128% compared to December 31, 2017 and 2016, respectively. Additionally, our North America contract operations services backlog as of December 31, 2018 was approximately $70 million. Longer-term fundamentals in our international markets partially depend on international oil and gas infrastructure projects, many of which are based on the longer-term plans of our customers that can be driven by their local market demand and local pricing for natural gas. As a result, we believe our international customers make decisions based on longer-term fundamentals that may be less tied to near term commodity prices than our North American customers. Over the long term, we believe the demand for our products and services in international markets will continue, and we expect to have opportunities to grow our international businesses. Booking activity levels for our manufactured products in international markets during the year ended December 31, 2018 were $219.5 million, which represents increases of 278% and 118% compared to the years ended December 31, 2017 and 2016, respectively, and our international product sales backlog as of December 31, 2018 was $163.5 million, which represents increases of 312% and 139% compared to December 31, 2017 and 2016, respectively. Additionally, our international contract operations services backlog as of December 31, 2018 was approximately $1.3 billion. Aggregate booking activity levels for our manufactured products in North America and international markets during the year ended December 31, 2018 was approximately $1.1 billion, which represents increases of 28% and 163% compared to the years ended December 31, 2017 and 2016, respectively. Fluctuations in the size and timing of customers’ requests for bid proposals and awards of new contracts tend to create variability in booking activity levels from period to period. The timing of any change in activity levels by our customers is difficult to predict. As a result, our ability to project the anticipated activity level for our business, and particularly our product sales segment, is limited. We experienced increases in product sales bookings in 2018 and 2017. However, volatility in commodity prices could delay investments by our customers in significant projects, which could result in a material adverse effect on our business, financial condition, results of operations and cash flows. Our level of capital spending largely depends on the demand for our contract operations services and the equipment required to provide such services to our customers. We have invested more capital in our contract operations business in 2018 than we did in 2017. The increased investment during 2018 was driven by several large multi-year projects contracted in 2017 and 2018 that have started earning revenue or are scheduled to start earning revenue in 2019. 32   Certain Key Challenges and Uncertainties Market conditions and competition in the oil and natural gas industry and the risks inherent in international markets continue to represent key challenges and uncertainties. In addition to these challenges, we believe the following represent some of the key challenges and uncertainties we will face in the future: Global Energy Markets and Oil and Natural Gas Pricing. Our results of operations depend upon the level of activity in the global energy markets, including oil and natural gas development, production, processing and transportation. Oil and natural gas prices and the level of drilling and exploration activity can be volatile. If oil and natural gas exploration and development activity and the number of well completions decline due to the reduction in oil and natural gas prices or significant instability in energy markets, we would anticipate a decrease in demand and pricing for our natural gas compression and oil and natural gas production and processing equipment and services. For example, unfavorable market conditions or financial difficulties experienced by our customers may result in cancellation of contracts or the delay or abandonment of projects, which could cause our cash flows generated by our product sales and services to decline and have a material adverse effect on our results of operations and financial condition. Execution on Larger Contract Operations and Product Sales Projects. Some of our projects are significant in size and scope, which can translate into more technically challenging conditions or performance specifications for our products and services. Contracts with our customers generally specify delivery dates, performance criteria and penalties for our failure to perform. Any failure to execute such larger projects in a timely and cost effective manner could have a material adverse effect on our business, financial condition, results of operations and cash flows. Personnel, Hiring, Training and Retention. We believe our ability to grow may be challenged by our ability to hire, train and retain qualified personnel. Although we have been able to satisfy our personnel needs thus far, retaining employees in our industry continues to be a challenge. Our ability to continue our growth will depend in part on our success in hiring, training and retaining these employees. Summary of Results As discussed in Note 4 to the Financial Statements, the results from continuing operations for all periods presented exclude the results of our Venezuelan contract operations, Belleli CPE and Belleli EPC businesses. Those results are reflected in discontinued operations for all periods presented. Revenue. Revenue during the years ended December 31, 2018, 2017 and 2016 was $1,360.9 million, $1,215.3 million and $905.4 million, respectively. The increase in revenue during the year ended December 31, 2018 compared to the year ended December 31, 2017 was due to revenue increases in our product sales and aftermarket services segments, partially offset by a decrease in revenue in our contract operations segment. The increase in revenue during the year ended December 31, 2017 compared to the year ended December 31, 2016 was due to a significant increase in revenue in our product sales segment, partially offset by decreases in revenue in our contract operations and aftermarket services segments. 33 Net income (loss). We generated net income of $24.9 million during the year ended December 31, 2018, net income of $33.9 million during the year ended December 31, 2017 and net loss of $227.9 million during the year ended December 31, 2016. The decrease in net income during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to an increase in income taxes, an increase in depreciation and amortization expense, a decrease in income from discontinued operations, net of tax, and an increase in foreign currency losses of $7.8 million. These activities were partially offset by an increase in gross margin for our product sales segment and a decrease in interest expense. Net income during the years ended December 31, 2018 and 2017 included income from discontinued operations, net of tax, of $24.5 million and $39.7 million, respectively. Income for discontinued operations, net of tax, was positively impacted by installment payments received of $19.8 million and $19.7 million associated with our Venezuelan subsidiary’s sale of its previously nationalized assets during the years ended December 31, 2018 and 2017, respectively, and recoveries from liquidated damages releases and customer approved change orders related to Belleli EPC during the year ended December 31, 2017. The increase in net income during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to non-cash valuation allowances of $119.8 million recorded against U.S. net deferred tax assets during 2016, an increase in income from discontinued operations, net of tax, an increase in gross margin for our product sales segment, a decrease in depreciation and amortization expense and a decrease in restructuring and other charges. These activities were partially offset by an increase in SG&A expense. Net income (loss) during the years ended December 31, 2017 and 2016 included income from discontinued operations, net of tax, of $39.7 million and loss from discontinued operations, net of tax, of $56.2 million, respectively. Income from discontinued operations, net of tax, for 2017 was positively impacted by recoveries from liquidated damages releases and customer approved change orders related to Belleli EPC. Loss from discontinued operations, net of tax, for 2016 included impairment charges of $68.8 million related to Belleli CPE. EBITDA, as adjusted. Our EBITDA, as adjusted, was $205.5 million, $173.2 million and $156.0 million during the years ended December 31, 2018, 2017 and 2016, respectively. EBITDA, as adjusted, during the year ended December 31, 2018 compared to the year ended December 31, 2017 increased primarily due to an increase in gross margin for our product sales segment. EBITDA, as adjusted, during the year ended December 31, 2017 compared to the year ended December 31, 2016 increased primarily due to an increase in gross margin for our product sales segment, partially offset by an increase in SG&A expense and decreases in gross margin for our aftermarket services and contract operations segments. EBITDA, as adjusted, is a non-GAAP financial measure. For a reconciliation of EBITDA, as adjusted, to net income (loss), its most directly comparable financial measure calculated and presented in accordance with GAAP, please read Part II, Item 6 (“Selected Financial Data — Non-GAAP Financial Measures”) of this report. Results by Business Segment. The following table summarizes revenue, gross margin and gross margin percentages for each of our business segments (dollars in thousands): Revenue: Contract Operations Aftermarket Services Product Sales Gross Margin: (1) Contract Operations Aftermarket Services Product Sales Gross Margin Percentage: (2) Contract Operations Aftermarket Services Product Sales Years Ended December 31, 2018 2017 2016 $ 360,973 $ 375,269 $ 392,463 120,676 107,063 879,207 $ 1,360,856 732,962 $ 1,215,294 $ 238,835 $ 241,889 31,010 113,583 28,842 76,409 $ $ 120,550 392,384 905,397 248,793 33,208 26,990 $ 383,428 $ 347,140 $ 308,991 66% 26% 13% 64% 27% 10% 63% 28% 7% (1) (2) Gross margin is defined as revenue less cost of sales (excluding depreciation and amortization expense). We evaluate the performance of each of our segments based on gross margin. Gross margin percentage is defined as gross margin divided by revenue. 34 Operating Highlights The following table summarizes the expected timing of revenue recognition from our contract operations backlog (in thousands): Contract Operations Backlog: (1) 2019 2020 2021 2022 2023 Thereafter December 31, 2018 $ 292,002 197,036 202,837 164,551 147,709 394,509 Total contract operations backlog $ 1,398,644 (1) At December 31, 2018, three contracts, each of which were signed in 2018 and in aggregate represent approximately 10% of the total value of our backlog, are accounted for as operating leases. For these contracts, revenues are recognized on a straight line basis and represent approximately 18% of total backlog expected to be recognized in 2019 and thereafter represent no more than 14% for each subsequent periods. Revenues recognized during the year ended December 31, 2018 and assets assigned to these contracts at December 31, 2018 were not material to our statements of operation and balance sheets, respectively. The following table summarizes our product sales backlog (in thousands): Product Sales Backlog: (1) Compression equipment Processing and treating equipment Production equipment (2) Other product sales Total product sales backlog December 31, 2018 2017 2016 $ 471,827 $ 254,745 $ 160,006 229,258 2,438 2,246 178,814 14,138 13,349 85,044 36,119 25,053 $ 705,769 $ 461,046 $ 306,222 (1) We expect that approximately $690 million of our product sales backlog as of December 31, 2018 will be recognized as revenue before December 31, 2019. (2) In June 2018, we completed the sale of our North America production equipment assets (“PEQ assets”), which included $12.0 million in backlog. 35 Results of Operations The Year Ended December 31, 2018 Compared to the Year Ended December 31, 2017 Contract Operations (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2018 $ 360,973 122,138 $ 238,835 2017 $ 375,269 133,380 $ 241,889 Change $ (14,296) (11,242) (3,054) $ 66% 64% 2% % change (4)% (8)% (1)% 3 % The decrease in revenue during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to decreases in revenue of $17.1 million and $12.6 million in the Latin America region and North America region, respectively, partially offset by increases in revenue of $13.1 million and $2.3 million in the Middle East and Africa region and Asia Pacific region, respectively. The revenue decrease in the Latin America region was primarily driven by an $18.2 million decrease in Argentina primarily due to a devaluation of the Argentine Peso during the current year period. The revenue decrease in the North America region was primarily due to a project that terminated operations in the first quarter of 2018 and renegotiations on a contract extension that resulted in lower revenue in the current year period. The revenue increase in the Middle East and Africa region was primarily driven by the start-up of projects in Oman and Iraq that were not operating or began operating in the prior year period. The revenue increase in the Asia Pacific region was primarily driven by a $2.8 million recovery of an early termination fee for a contract that terminated in January 2016. Gross margin decreased during the year ended December 31, 2018 compared to the year ended December 31, 2017 primarily due to the revenue decrease explained above. Gross margin percentage during the year ended December 31, 2018 compared to the year ended December 31, 2017 increased primarily due to customer approved contract changes during the current year period that resulted in a reduction of $3.3 million in costs of sales and a recovery of an early termination fee discussed above. Aftermarket Services (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2018 $ 120,676 89,666 2017 $ 107,063 78,221 Change $ 13,613 11,445 $ 31,010 $ 28,842 $ 2,168 26% 27% (1)% % change 13 % 15 % 8 % (4)%   The increase in revenue during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to increases in revenue of $10.5 million, $3.5 million and $1.1 million in the Middle East and Africa, North America and Latin America regions, respectively, partially offset by a decrease in revenue of $1.5 million in the Asia Pacific region. The revenue increase in the Middle East and Africa region was primarily driven by an increase in part sales. The revenue increase in the North America region was primarily driven by increases in commissioning services and part sales. Gross margin increased during the year ended December 31, 2018 compared to the year ended December 31, 2017 primarily due to the revenue increase explained above. Gross margin percentage during the year ended December 31, 2018 compared to the year ended December 31, 2017 remained relatively flat. 36 Product Sales (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2018 $ 879,207 765,624 $ 113,583 2017 $ 732,962 656,553 Change $ 146,245 109,071 $ 76,409 $ 37,174 13% 10% 3% % change 20% 17% 49% 30%   The increase in revenue during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to increases in revenue of $137.3 million in the North America region and $12.9 million in the Asia Pacific region, partially offset by decreases in revenue of $2.2 million in the Latin America region and $1.8 million in the Middle East and Africa region. The revenue increase in the North America region was primarily due to increases of $94.9 million and $92.3 million in processing and treating equipment revenue and compression equipment revenue, respectively, partially offset by a decrease of $49.7 million in production equipment revenue. In June 2018, we completed the sale of our North America PEQ assets. The revenue increase in the Asia Pacific region was primarily due to an increase in compression equipment revenue. The revenue decrease in the Latin America region was primarily due to a decrease of $4.5 million in compression equipment revenue, partially offset by an increase of $3.1 million in production equipment revenue. The revenue decrease in the Middle East and Africa region was primarily due to decreases of $20.0 million and $5.6 million in compression equipment revenue and production equipment revenue, respectively, partially offset by a $24.8 million increase in processing and treating equipment revenue. Gross margin and gross margin percentage increased during the year ended December 31, 2018 compared to the year ended December 31, 2017 due to the revenue increase explained above, a shift in product mix in the North America region during the current year period and increased productivity relating to the manufacture of compression equipment. Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges (recoveries), net Restructuring and other charges Interest expense Other (income) expense, net Costs and Expenses (dollars in thousands) Years Ended December 31, $ 2018 178,401 123,922 $ 2017 176,318 107,824 3,858 (276) 1,997 29,217 6,484 5,700 3,419 3,189 34,826 (975) Change % change $ 2,083 16,098 (1,842) (3,695) (1,192) (5,609) 7,459 1 % 15 % (32)% (108)% (37)% (16)% (765)% Selling, general and administrative SG&A expense during the year ended December 31, 2018 compared to the year ended December 31, 2017 remained relatively flat. During the years ended December 31, 2018 and 2017, SG&A expense as a percentage of revenue was 13% and 15%, respectively. Depreciation and amortization Depreciation and amortization expense during the year ended December 31, 2018 compared to the year ended December 31, 2017 increased primarily due to an increase in depreciation expense of $8.9 million for our compression equipment driven by changes in estimates relating to the useful lives and salvage values made in the fourth quarter of 2017. Additionally, depreciation expense of capitalized installation costs increased by $5.9 million primarily due to additional depreciation on projects that were not operating in the prior year period. Capitalized installation costs, included, among other things, civil engineering, piping, electrical instrumentation and project management costs. 37 Long-lived asset impairment We regularly review the future deployment of our idle compression assets used in our contract operations segment for units that are not the type, configuration, condition, make or model that are cost efficient to maintain and operate. During the year ended December 31, 2018, we evaluated for impairment idle units that had been previously culled from our fleet and are available for sale. Based upon that review, we reduced the expected proceeds from disposition for certain units. This resulted in an additional impairment of $2.1 million to reduce the book value of each unit to its estimated fair value during the year ended December 31, 2018. During the year ended December 31, 2017, we determined that one idle compressor unit would be retired from the active fleet. The retirement of this unit from the active fleet triggered a review of the active fleet for impairment, and as a result, we recorded an asset impairment of $0.6 million, to reduce the book value of the unit to its estimated fair value. In the fourth quarter of 2017, we classified certain PEQ assets primarily related to inventory and property, plant and equipment, net, within our product sales business as assets held for sale in our balance sheets. In June 2018, we completed the sale of our PEQ assets. During the years ended December 31, 2018 and 2017, we recorded impairments of $1.8 million and $2.1 million, respectively, to reduce these assets to their approximate fair values based on the expected net proceeds. For further details, see Note 8 to the financial statements. Additionally, in the fourth quarter of 2017, we determined that certain other assets within our product sales business were assessed to have no future benefit to our ongoing operations. In conjunction with the assessment of these other assets, we recorded an impairment charge of $3.0 million to write-down these assets. Restatement related charges As discussed in Note 14 to the Financial Statements, during the first quarter of 2016, our senior management identified errors relating to the application of percentage-of-completion accounting principles to specific Belleli EPC product sales projects. During the years ended December 31, 2018 and 2017, we incurred $0.9 million and $6.2 million, respectively, of external costs associated with an SEC investigation and remediation activities related to the restatement of our financial statements. During the years ended December 31, 2018 and 2017, we recorded recoveries from Archrock pursuant to the separation and distribution agreement of $1.2 million and $2.8 million, respectively, for previously incurred restatement related costs. Restructuring and other charges In the second quarter of 2018, we initiated a relocation plan in the North America region to better align our contract operations business with our customers. As a result of this plan, during the year ended December 31, 2018, we incurred restructuring and other charges of $2.0 million primarily related to relocation costs and employee termination benefits. In the second quarter of 2015, we announced a cost reduction plan primarily focused on workforce reductions and the reorganization of certain facilities. As a result of this plan, during the year ended December 31, 2017, we incurred restructuring and other charges of $2.6 million primarily related to employee termination benefits. Additionally, during the year ended December 31, 2017, we incurred $0.6 million of costs associated with the Spin-off related to retention awards to certain employees. The charges incurred in conjunction with the relocation plan, cost reduction plan and Spin-off are included in restructuring and other charges in our statements of operations. See Note 15 to the Financial Statements for further discussion of these charges. Interest expense The decrease in interest expense during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to an increase in capitalized interest resulting from increased construction activities during the current year period and interest expense of $2.4 million recorded for the settling of non-income-based tax debt during the prior year period in connection with two Brazilian tax programs we entered into, partially offset by a higher average balance of long-term debt. During the years ended December 31, 2018 and 2017, the average daily outstanding borrowings of long-term debt were $428.6 million and $374.3 million, respectively. For further discussion on the Brazilian tax programs, see Note 16 to the Financial Statements. Other (income) expense, net The change in other (income) expense, net, was primarily due to foreign currency losses of $8.5 million and $0.7 million during the years ended December 31, 2018 and 2017, respectively. Foreign currency losses included translation losses of $5.2 million and translation gains of $0.5 million during the years ended December 31, 2018 and 2017, respectively, related to the currency remeasurement of our foreign subsidiaries’ non-functional currency denominated intercompany obligations. Other (income) expense, net, also included a loss of $1.7 million on the sale of our PEQ assets during the year ended December 31, 2018 and penalties of $1.8 million incurred for the settling of non-income-based tax debt during the year ended December 31, 2017 in connection with the two Brazilian tax programs discussed above. For further discussion on the sale of our PEQ assets, see Note 8 to the Financial Statements. 38 Provision for income taxes Effective tax rate Income Taxes (dollars in thousands) Years Ended December 31, 2018 39,433 $ $ 99.0% 2017 22,695 134.8% Change $ 16,738 (35.8)% % change 74 % (26.6)% Our effective tax rate is affected by recurring items, such as tax rates in foreign jurisdictions and the relative amounts of income we earn, or losses we incur, in those jurisdictions. It is also affected by discrete items that may occur in any given year but are not consistent from year to year. Our effective tax rate is also impacted by valuation allowances recorded against loss carryforwards in the U.S. and certain other jurisdictions, foreign withholding taxes and changes in foreign currency exchange rates. The following items had the most significant impact on the difference between our statutory U.S. federal income tax rate of 21.0% and our effective tax rate for the year ended December 31, 2018: • • • • A $28.3 million increase (71.0% increase) resulting primarily from foreign withholding taxes, $16.1 million in negative impacts of foreign currency devaluations in Argentina, and deemed distributions to the U.S. from certain of our non-U.S. subsidiaries. A $19.0 million reduction (47.6% reduction) resulting from the release of valuation allowances primarily recorded against U.S federal net operating losses and certain deferred tax assets of our foreign subsidiaries. An $8.3 million increase (21.0% increase) resulting from deductions of foreign taxes paid previously recorded as deferred tax asset carryforwards. A $9.5 million increase (23.8% increase) related to unrecognized tax benefits recorded in the current year. For the year ended December 31, 2017, our provision for income tax and effective tax rate of 134.8% was positively impacted by the reversal of previously recorded valuation allowances of $5.6 million against our U.S. corporate alternative minimum tax (“AMT”) carryforwards due to the Tax Cuts and Jobs Act (“Tax Reform Act”) which provided for the cancellation of the AMT and allows for a future refund and/or credit against regular income tax carryforwards. In addition, as a result of the reduction in the U.S. corporate tax rate from 35% to 21%, we recorded a provisional estimate of $15.5 million due to the re-measurement of deferred tax assets and liabilities and recorded a provisional estimate of $10.1 million due to the transition tax on undistributed earnings. Both of these were offset by a tax benefit from the reduction of the valuation allowance previously recorded against our U.S. deferred tax assets. Our effective tax rate was negatively impacted by a $17.1 million additional valuation allowance we recorded on our net U.S. deferred tax assets because beginning in 2016, we were no longer able to support that it was more likely-than-not that we would have sufficient taxable income in the future to realize our U.S. deferred tax assets. In addition, we recorded a $3.1 million benefit for the change in tax rates due to tax legislation enacted and signed into law in 2017 in Argentina. Our income tax expense for the year ended December 31, 2017 included benefits related to the reversal of valuation allowances previously recorded against deferred tax assets of $15.2 million related to income tax loss carryforwards that were utilized under two Brazilian tax programs. The following items had the most significant impact on the difference between our statutory U.S. federal income tax rate of 35.0% and our effective tax rate for the year ended December 31, 2017: • • • • • A $48.1 million reduction (285.4% reduction) resulting from the release of valuation allowances primarily recorded against certain deferred tax assets of our foreign subsidiaries and federal net operating losses and credits in the U.S. A $44.9 million increase (266.5% increase) resulting primarily from foreign withholding taxes, negative impacts of foreign currency devaluations in Argentina, and deemed distributions to the U.S. from certain of our non-U.S. subsidiaries. The increase includes a reduction resulting from rate differences between U.S. and foreign jurisdictions. A $15.5 million increase (92.2% increase) resulting from changes to the tax rates at which certain deferred taxes are recorded due to U.S. tax reform legislation enacted and signed into law in 2017. An $11.2 million reduction (66.7% reduction) resulting from claiming foreign taxes as credits primarily for foreign withholding taxes. The foreign tax credits are available to offset future payments of U.S. federal income taxes. A $10.1 million increase (59.7% increase) resulting from transition tax charges related to U.S. tax reform legislation enacted and signed into law in 2017. 39 Discontinued Operations (dollars in thousands) Income from discontinued operations, net of tax $ 24,462 $ 39,736 $ (15,274) (38)% Years Ended December 31, 2018 2017 Change % change Income from discontinued operations, net of tax, includes our Venezuelan subsidiary’s operations that were expropriated in June 2009, including compensation for expropriation, and our Belleli EPC business. Income from discontinued operations, net of tax, during the year ended December 31, 2018 compared to the year ended December 31, 2017 decreased primarily due to a $15.4 million decrease in income from Belleli EPC. The decrease in income from Belleli EPC was primarily due to recoveries in the first quarter of 2017 resulting from our release of liquidated damages by a customer in exchange for us releasing them from certain extension of time claims and the obtainment of customer approved change orders. Additionally, during the years ended December 31, 2018 and 2017, we received installment payments, including an annual charge, of $19.8 million and $19.7 million, respectively, from PDVSA Gas, S.A. (“PDVSA Gas”) in respect to our Venezuelan subsidiary’s sale of its previously nationalized assets. As of December 31, 2018, we have received all payments from PDVSA Gas. For further details on our discontinued operations, see Note 4 to the Financial Statements. The Year Ended December 31, 2017 Compared to the Year Ended December 31, 2016 Contract Operations (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2017 $ 375,269 133,380 $ 241,889 2016 $ 392,463 143,670 $ 248,793 Change $ (17,194) (10,290) (6,904) $ 64% 63% 1% % change (4)% (7)% (3)% 2 % The decrease in revenue during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to a $15.4 million decrease in revenue in Mexico primarily driven by projects that terminated operations in 2016 and a decrease in revenue of $7.7 million resulting from an early termination of a project in Indonesia in January 2016 that had been operating since the third quarter of 2009. These decreases were partially offset by an $8.0 million increase in revenue in Brazil primarily driven by the start-up of a project during the second half of 2016. Gross margin decreased during the year ended December 31, 2017 compared to the year ended December 31, 2016 primarily due to the revenue decrease explained above, partially offset by demobilization expenses of $6.1 million incurred in 2016 on the early termination of a project in Indonesia discussed above. Gross margin percentage during the year ended December 31, 2017 compared to the year ended December 31, 2016 remained relatively flat. 40     Aftermarket Services (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2017 $ 107,063 78,221 2016 $ 120,550 87,342 $ 28,842 $ 33,208 Change $ (13,487) (9,121) (4,366) $ 27% 28% (1)% % change (11)% (10)% (13)% (4)%   The decrease in revenue during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to a decrease in operations and maintenance services of $5.2 million in Colombia, a decrease in parts sales of $7.1 million in China, a $3.3 million decrease in revenue due to the sale of our North America refurbishment and services business in the first quarter of 2017 and a $3.5 million decrease in revenue on a contract in the Middle East resulting from ongoing customer negotiations. These decreases were partially offset by a $4.6 million increase in Brazil primarily driven by increased maintenance services. Gross margin decreased during the year ended December 31, 2017 compared to the year ended December 31, 2016 primarily due to the revenue decrease explained above. Gross margin percentage during the year ended December 31, 2017 compared to the year ended December 31, 2016 remained relatively flat. Product Sales (dollars in thousands) Revenue Cost of sales (excluding depreciation and amortization expense) Gross margin Gross margin percentage Years Ended December 31, 2017 $ 732,962 656,553 2016 $ 392,384 365,394 Change $ 340,578 291,159 $ 76,409 $ 26,990 $ 49,419 10% 7% 3% % change 87% 80% 183% 43%   The increase in revenue during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to increases of $316.3 million and $32.4 million in North America and in the Middle East and Africa region, respectively, partially offset by a decrease of $16.7 million in the Asia Pacific region. The increase in revenue in North America was primarily due to a significant increase in North America booking activities during 2017 compared to 2016. In North America, compression equipment revenue and processing and treating equipment revenue increased by $168.6 million and $160.6 million, respectively, partially offset by a decrease of $10.3 million in production equipment revenue. The increase revenue in the Middle East and Africa region was primarily due to an increase of $29.6 million in processing and treating equipment revenue. The decrease in revenue in the Asia Pacific region was primarily due to a decrease of $15.1 million in compression equipment revenue. Gross margin and gross margin percentage increased during the year ended December 31, 2017 compared to the year ended December 31, 2016 primarily due to the revenue increase explained above and a shift in product mix during 2017. 41 Costs and Expenses (dollars in thousands) Selling, general and administrative $ Depreciation and amortization Long-lived asset impairment Restatement related charges Restructuring and other charges Interest expense Equity in income of non-consolidated affiliates Other (income) expense, net Years Ended December 31, $ 2017 176,318 107,824 5,700 3,419 3,189 34,826 — (975) $ 2016 157,485 132,886 14,495 18,879 22,038 34,181 (10,403) (13,046) Change % change 18,833 (25,062) (8,795) (15,460) (18,849) 645 10,403 12,071 12 % (19)% (61)% (82)% (86)% 2 % (100)% (93)% Selling, general and administrative SG&A expense increased during the year ended December 31, 2017 compared to the year ended December 31, 2016 primarily due to the reinstitution of certain incentive compensation that was suspended in 2016 and an increase in third-party professional expenses primarily related to the redesign of our internal controls framework in an effort to remediate previously identified internal control deficiencies, partially offset by cost savings resulting from the portions of our cost reduction plan previously implemented. During the years ended December 31, 2017 and 2016, SG&A expense as a percentage of revenue was 15% and 17%, respectively. The facility previously utilized to manufacture products for our Belleli EPC business has been repurposed to manufacture product sales equipment. As such, certain personnel, buildings, equipment and other assets that were previously related to the Belleli EPC business will remain as part of our continuing operations. As a result, SG&A expense during the years ended December 31, 2017 and 2016 included $2.4 million and $2.3 million, respectively, of costs associated with our ongoing operations at our repurposed facility. Depreciation and amortization Depreciation and amortization expense during the year ended December 31, 2017 compared to the year ended December 31, 2016 decreased primarily due to depreciation expense of $22.2 million recognized during the year ended December 31, 2016 on a contract operations project in Indonesia that early terminated operations in January 2016. The depreciation expense recognized on this project in 2016 primarily related to capitalized installation costs, which included, among other things, civil engineering, piping, electrical instrumentation and project management costs. The project had been operating since the third quarter of 2009. Long-lived asset impairment We regularly review the future deployment of our idle compression assets used in our contract operations segment for units that are not of the type, configuration, condition, make or model that are cost efficient to maintain and operate. During the years ended December 31, 2017 and 2016, we determined that one idle compressor unit and 62 idle compressor units, respectively, would be retired from the active fleet. The retirement of these units from the active fleet triggered a review of these assets for impairment, and as a result, we recorded asset impairments of $0.6 million and $12.7 million, respectively, to reduce the book value of each unit to its estimated fair value. In the fourth quarter of 2017, we classified certain assets within our product sales business that we expect to sell within the next twelve months as assets held for sale. We also determined that certain other assets within our product sales business were assessed to have no future benefit to our ongoing operations. In conjunction with the planned disposition and assessment of certain other assets, we recorded an impairment of long-lived assets that totaled $5.1 million to write-down these assets to their approximate fair values. During the year ended December 31, 2016, we evaluated other assets for impairment and recorded long-lived asset impairments of $1.7 million on these assets. 42 Restatement related charges As discussed in Note 14 to the Financial Statements, during the first quarter of 2016, our senior management identified errors relating to the application of percentage-of-completion accounting principles to specific Belleli EPC product sales projects. During the years ended December 31, 2017 and 2016, we incurred $6.2 million and $30.1 million, respectively, of external costs associated with an SEC investigation and remediation activities related to the restatement of our financial statements, of which $2.8 million and $11.2 million, respectively, was recovered from Archrock pursuant to the separation and distribution agreement. Restructuring and other charges In the second quarter of 2015, we announced a cost reduction plan primarily focused on workforce reductions and the reorganization of certain facilities. These actions were in response to unfavorable market conditions in North America combined with the impact of lower international activity due to customer budget cuts driven by lower oil prices. As a result of this plan, during the year ended December 31, 2017, we incurred restructuring and other charges of $2.6 million primarily related to employee termination benefits. During the year ended December 31, 2016, we incurred $18.1 million of restructuring and other charges as a result of this plan, which primarily related to $14.5 million of employee termination benefits and a $2.9 million charge for the exit of a corporate building under an operating lease. Additionally, during the year ended December 31, 2017, we incurred $0.6 million of costs associated with the Spin-off primarily related to retention awards to certain employees. During the year ended December 31, 2016, we incurred $3.9 million of costs associated with the Spin-off, of which $3.1 million related to retention awards to certain employees. The charges incurred in conjunction with the cost reduction plan and Spin-off are included in restructuring and other charges in our statements of operations. We have substantially completed restructuring activities related to the Spin-off and cost reduction plan. See Note 15 to the Financial Statements for further discussion of these charges. Interest expense The increase in interest expense during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to an increase in the effective interest rate on our debt and interest expense of $2.4 million recorded for the settling of non-income-based tax debt during 2017 in connection with two Brazilian tax programs we entered into in 2017, partially offset by an increase in capitalized interest resulting from increased construction activities and a lower average balance of long-term debt and letters of credit outstanding. As discussed in Note 11 to the Financial Statements, the proceeds received in April 2017 from the issuance of our 8.125% senior secured notes due 2025 (the “2017 Notes”) were used to repay all of the borrowings outstanding under the term loan facility and revolving credit facility. For further discussion on the Brazilian tax programs, see Note 16 to the Financial Statements. Equity in income of non-consolidated affiliates In March 2012, our Venezuelan joint ventures sold their assets to PDVSA Gas. We received installment payments, including an annual charge of $10.4 million during the year ended December 31, 2016. As of December 31, 2017, the remaining principal amount due to us was approximately $4 million. Payments we receive from the sale are recognized as equity in income of non- consolidated affiliates in our statements of operations in the periods such payments are received. Other (income) expense, net The change in other (income) expense, net, was primarily due to foreign currency losses of $0.7 million during the year ended December 31, 2017 compared to foreign currency gains, net of foreign currency derivatives, of $5.8 million during the year ended December 31, 2016. Foreign currency gains and losses included translation gains of $0.5 million during the year ended December 31, 2017 compared to translation gains, net of foreign currency derivatives, of $8.6 million during the year ended December 31, 2016 related to the currency remeasurement of our foreign subsidiaries’ non-functional currency denominated intercompany obligations. The change in other (income) expense, net, was also due to penalties of $1.8 million incurred for the settling of non-income-based tax debt during the year ended December 31, 2017 in connection with the two Brazilian tax programs discussed above and a decrease of $0.5 million in gain on sale of property, plant and equipment. 43 Provision for income taxes Effective tax rate Income Taxes (dollars in thousands) Years Ended December 31, $ 2017 22,695 134.8% 2016 $ 124,242 Change $ (101,547) (261.4)% 396.2% % change (82)% (151.6)% For the year ended December 31, 2017, our provision for income tax and effective tax rate of 134.8% was positively impacted by the reversal of previously recorded valuation allowances of $5.6 million against our U.S. AMT carryforwards due to the Tax Reform Act which provided for the cancellation of the AMT and allows for a future refund and/or credit against regular income tax carryforwards. In addition, as a result of the reduction in the U.S. corporate tax rate from 35% to 21%, we recorded a provisional estimate of $15.5 million due to the re-measurement of deferred tax assets and liabilities and recorded a provisional estimate of $10.1 million due to the transition tax on undistributed earnings. Both of these were offset by a tax benefit from the reduction of the valuation allowance previously recorded against our U.S. deferred tax assets. Our effective tax rate was negatively impacted by a $17.1 million additional valuation allowance we recorded on our net U.S. deferred tax assets because beginning in 2016, we were no longer able to support that it was more likely-than-not that we would have sufficient taxable income in the future to realize our U.S. deferred tax assets. In addition, we recorded a $3.1 million benefit for the change in tax rates due to tax legislation enacted and signed into law in 2017 in Argentina. Our income tax expense for the year ended December 31, 2017 included benefits related to the reversal of valuation allowances previously recorded against deferred tax assets of $15.2 million related to income tax loss carryforwards that were utilized under two Brazilian tax programs. For the year ended December 31, 2016, our provision for income tax and effective tax rate of (261.4)% was adversely impacted by valuation allowances recorded against U.S. deferred tax assets and activity at our non-U.S. subsidiaries, which included valuation allowances against certain deferred tax assets, foreign currency devaluations and the settlement of a foreign audit. These negative impacts were partially offset by nontaxable Venezuelan joint venture proceeds and a net nontaxable capital contribution related to the Spin-off. Our effective tax rate is affected by recurring items, such as tax rates in foreign jurisdictions and the relative amounts of income we earn, or losses we incur, in those jurisdictions. It is also affected by discrete items that may occur in any given year but are not consistent from year to year. The following items had the most significant impact on the difference between our statutory U.S. federal income tax rate of 35.0% and our effective tax rate. For the year ended December 31, 2017: • • • • • A $48.1 million reduction (285.4% reduction) resulting from the release of valuation allowances primarily recorded against certain deferred tax assets of our foreign subsidiaries and federal net operating losses and credits in the U.S. A $44.9 million increase (266.5% increase) resulting primarily from foreign withholding taxes, negative impacts of foreign currency devaluations in Argentina, and deemed distributions to the U.S. from certain of our non-U.S. subsidiaries. The increase includes a reduction resulting from rate differences between U.S. and foreign jurisdictions. A $15.5 million increase (92.2% increase) resulting from changes to the tax rates at which certain deferred taxes are recorded due to U.S. tax reform legislation enacted and signed into law in 2017. An $11.2 million reduction (66.7% reduction) resulting from claiming foreign taxes as credits primarily for foreign withholding taxes. The foreign tax credits are available to offset future payments of U.S. federal income taxes. A $10.1 million increase (59.7% increase) resulting from transition tax charges related to U.S. tax reform legislation enacted and signed into law in 2017. For the year ended December 31, 2016: • • • A $124.9 million increase (262.7% reduction) resulting from valuation allowances primarily recorded against U.S. deferred tax assets and certain deferred tax assets of our subsidiary in Nigeria. A $29.4 million increase (61.9% reduction) resulting primarily from foreign withholding taxes, negative impacts of foreign currency devaluations in Argentina and Mexico, settlement of a Nigeria tax audit and deemed distributions to the U.S. from certain of our non-U.S. subsidiaries. The increase includes a reduction resulting from rate differences between U.S. and foreign jurisdictions primarily related to income we earned in Oman and Mexico where the rates are 12.0% and 30.0%, respectively. A $9.5 million reduction (20.0% increase) resulting from claiming foreign taxes as credits primarily for foreign withholding taxes. The foreign tax credits are available to offset future payments of U.S. federal income taxes. 44 • • • A $3.6 million increase (7.6% reduction) resulting from unrecognized tax benefits primarily from additions based on tax positions related to 2016. A $3.6 million reduction (7.7% increase) due to $10.4 million of nontaxable proceeds from sale of joint venture assets in Venezuela. A $2.9 million reduction (6.1% increase) primarily due to $11.2 million of cash recovered from Archrock with respect to our restatement related charges. Payments between Archrock and us are treated as nontaxable capital contributions or distributions pursuant to the tax matters agreement. Discontinued Operations (dollars in thousands) Years Ended December 31, Income (loss) from discontinued operations, net of tax $ 39,736 $ 2017 2016 (56,171) $ Change % change 95,907 (171)% Income (loss) from discontinued operations, net of tax, includes our Venezuelan subsidiary’s operations that were expropriated in June 2009, including compensation for expropriation, and our Belleli CPE and Belleli EPC businesses. Income from discontinued operations, net of tax, during the year ended December 31, 2017 compared to the year ended December 31, 2016 increased primarily due to asset impairment charges totaling $68.8 million recorded during the year ended December 31, 2016 for the planned disposition of Belleli CPE and a $42.8 million increase in income from Belleli EPC in 2017 compared to 2016 primarily due to recoveries in 2017 resulting from our release of liquidated damages by a customer in exchange for us releasing them from certain extension of time claims and the obtainment of customer approved change orders. These increases were partially offset by a $19.5 million decrease in income from our Venezuelan subsidiary. During the years ended December 31, 2017 and 2016, we received installment payments, including an annual charge, of $19.7 million and $38.8 million, respectively, from PDVSA Gas in respect to our Venezuelan subsidiary’s sale of its previously nationalized assets. For further details on our discontinued operations, see Note 4 to the Financial Statements. Liquidity and Capital Resources Our unrestricted cash balance was $19.3 million at December 31, 2018 compared to $49.1 million at December 31, 2017. Working capital decreased to $108.7 million at December 31, 2018 from $134.0 million at December 31, 2017. The decrease in working capital was primarily due to increases in contract liabilities and accounts payable and decreases in accounts receivable and current assets held for sale, partially offset by increases in contract assets and inventory. The increase in contract liabilities was primarily driven by the timing of milestone billings on a product sales project in the Middle East and Africa region. The increases in inventory, contract assets and accounts payable were primarily driven by higher product sales activity in the North America region. The decrease in accounts receivable was driven by the timing of payments received from customers during the current year period. The decrease in current assets held for sale was driven by the sale of our PEQ assets in June 2018 as discussed in further detail in Note 8 to the Financial Statements. Our cash flows from operating, investing and financing activities, as reflected in the statements of cash flows, are summarized in the following table (in thousands): Net cash provided by (used in) continuing operations: Operating activities Investing activities Financing activities Effect of exchange rate changes on cash, cash equivalents and restricted cash Discontinued operations Net change in cash, cash equivalents and restricted cash Years Ended December 31, 2018 2017 $ $ $ 153,296 (207,578) 6,897 (3,841) 21,013 (30,213) $ 150,420 (121,913) (32,154) (792) 17,781 13,342 45   Operating Activities.  Net cash provided by operating activities during the year ended December 31, 2018 compared to the year ended December 31, 2017 remained relatively flat primarily due to improved gross margins in the current year period for our product sales segment and a decrease in income taxes paid in the current year period, offset by lower current period decreases in working capital. Working capital cash changes during the year ended December 31, 2018 included an increase of $62.9 million in contract liabilities, an increase of $59.7 million in inventory and an increase of $34.6 million in contract assets. Working capital cash changes during the year ended December 31, 2017 included an increase of $62.0 million in account payable and other liabilities, an increase of $65.3 million in accounts receivable and a decrease of $40.9 million in costs and estimated earnings versus billings on uncompleted contracts. Investing Activities.  The increase in net cash used in investing activities during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily attributable to an $83.4 million increase in capital expenditures. The increase in capital expenditures was primarily driven by an increase in growth capital expenditures on contract operations services projects in the Middle East and Africa region and Latin America region. Financing Activities.  The decrease in net cash used in financing activities during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily attributable to a $26.0 million decrease in cash transferred to Archrock pursuant to the separation and distribution agreement and an increase in net borrowings of $9.9 million on our long-term debt. The transfers of cash to Archrock during the years ended December 31, 2018 and 2017 were required under the separation and distribution agreement upon our receipt of payments from PDVSA Gas relating to the sale of our previously nationalized assets and our occurrence of a qualified capital raise in 2017 that required a payment of $25.0 million to Archrock. Discontinued Operations.  The increase in net cash provided by discontinued operations during the year ended December 31, 2018 compared to year ended December 31, 2017 was primarily attributable to working capital changes related to our Belleli EPC business. Net cash provided by discontinued operations included proceeds received from the sale of our Venezuelan subsidiary’s assets to PDVSA Gas of $19.8 million and $19.7 million during the years ended December 31, 2018 and 2017, respectively. Capital 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 equipment required for us to render those contract operations services to our customers. Our capital requirements have consisted primarily of, and we anticipate will continue to consist of, the following: • growth capital expenditures, which are made to expand or to replace partially or fully depreciated assets or to expand the operating capacity or revenue generating capabilities of existing or new assets, whether through construction, acquisition or modification; and • maintenance capital expenditures, which are made to maintain the existing operating capacity of our assets and related cash flows further extending the useful lives of the assets. The majority of our growth capital expenditures are related to installation costs on contract operations services projects and acquisition costs of new compressor units and processing and treating equipment that we add to our contract operations fleet. In addition, growth capital expenditures can include the upgrading of major components on an existing compressor unit where the current configuration of the compressor unit is no longer in demand and the compressor unit is not likely to return to an operating status without the capital expenditures. These latter expenditures substantially modify the operating parameters of the compressor unit such that it can be used in applications for which it previously was not suited. Maintenance capital expenditures are related to major overhauls of significant components of a compressor unit, such as the engine, compressor and cooler, that return the components to a “like new” condition, but do not modify the applications for which the compressor unit was designed. Growth capital expenditures were $186.2 million, $104.9 million and $53.0 million during the years ended December 31, 2018, 2017 and 2016, respectively. The increase in growth capital expenditures during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily due to an increase in installation expenditures on a contract operations services project in Oman and an increase in compression expenditures on a contract operations services contract in Bolivia during 2018. The increase in growth capital expenditures during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to an increase in installation expenditures on contract operations services projects in Oman during 2017. 46 Maintenance capital expenditures were $6.6 million, $15.7 million and $14.4 million during the years ended December 31, 2018, 2017 and 2016, respectively. The decrease in maintenance capital expenditures during the year ended December 31, 2018 compared to the year ended December 31, 2017 was primarily driven by decreased overhaul activities as a result of delayed discretionary spending. The increase in maintenance capital expenditures during the year ended December 31, 2017 compared to the year ended December 31, 2016 was primarily due to increased overhaul activities. We intend to grow our business both organically and through third-party acquisitions. If we are successful in growing our business in the future, we would expect our maintenance capital expenditures to increase over the long term. We generally invest funds necessary to manufacture contract operations fleet additions when our idle equipment cannot be reconfigured to economically fulfill a project’s requirements and the new equipment expenditure is expected to generate economic returns over its expected useful life that exceeds our targeted return on capital. We currently plan to spend approximately $205 million to $215 million in capital expenditures during 2019, including (1) approximately $170 million on contract operations growth capital expenditures and (2) approximately $35 million to $45 million on equipment maintenance capital related to our contract operations business and other capital expenditures. Long-Term Debt. On October 9, 2018, we and EESLP entered into a Second Amended and Restated Credit Agreement (the “Amended Credit Agreement”), which among other things, increased the borrowing capacity under our revolving credit facility from $680.0 million to $700.0 million. The Amended Credit Agreement also extended the maturity date of our revolving credit facility from November 2020 to October 2023. During the years ended December 31, 2018 and 2017, the average daily borrowings of long-term debt were $428.6 million and $374.3 million respectively. The weighted average annual interest rate on outstanding borrowings under our revolving credit facility at December 31, 2018 was 4.3%. As of December 31, 2017, there were no outstanding borrowings under the revolving credit facility. As of December 31, 2018, we had $56.7 million in outstanding letters of credit under our revolving credit facility and, taking into account guarantees through outstanding letters of credit, we had undrawn capacity of $608.3 million under our revolving credit facility. Our Amended Credit Agreement limits our senior secured leverage ratio (as defined in the Amended Credit Agreement) on the last day of the fiscal quarter to no greater than 2.75 to 1.0. As a result of this limitation, $578.4 million of the $608.3 million of undrawn capacity under our revolving credit facility was available for additional borrowings as of December 31, 2018. The Amended Credit Agreement contains various covenants with which we, EESLP and our respective restricted subsidiaries must comply, including, but not limited to, limitations on the incurrence of indebtedness, investments, liens on assets, repurchasing equity, making distributions, transactions with affiliates, mergers, consolidations, dispositions of assets and other provisions customary in similar types of agreements. We are required to maintain, on a consolidated basis, a minimum interest coverage ratio (as defined in the Amended Credit Agreement) of 2.25 to 1.00; a maximum total leverage ratio (as defined in the Amended Credit Agreement) of 4.50 to 1.00; and a maximum senior secured leverage ratio (as defined in the Amended Credit Agreement) of 2.75 to 1.00. As of December 31, 2018, Exterran Corporation maintained a 9.3 to 1.0 interest coverage ratio, a 1.8 to 1.0 total leverage ratio and a 0.2 to 1.0 senior secured leverage ratio. As of December 31, 2018, we were in compliance with all financial covenants under the Amended Credit Agreement. In April 2017, our 100% owned subsidiaries EESLP and EES Finance Corp. issued the 2017 Notes, which consists of $375.0 million aggregate principal amount of senior unsecured notes. The 2017 Notes are guaranteed by us on a senior unsecured basis. Prior to May 1, 2020, we may redeem all or a portion of the 2017 Notes at a redemption price equal to the sum of (i) the principal amount thereof, and (ii) a make-whole premium at the redemption date, plus accrued and unpaid interest, if any, to the redemption date. In addition, we may redeem up to 35% of the aggregate principal amount of the 2017 Notes prior to May 1, 2020 with the net proceeds of one or more equity offerings at a redemption price of 108.125% of the principal amount of the 2017 Notes, plus any accrued and unpaid interest to the date of redemption, if at least 65% of the aggregate principal amount of the 2017 Notes issued under the indenture remains outstanding after such redemption and the redemption occurs within 180 days of the date of the closing of such equity offering. On or after May 1, 2020, we may redeem all or a portion of the 2017 Notes at redemption prices (expressed as percentages of principal amount) equal to 106.094% for the twelve-month period beginning on May 1, 2020, 104.063% for the twelve-month period beginning on May 1, 2021, 102.031% for the twelve-month period beginning on May 1, 2022 and 100.000% for the twelve-month period beginning on May 1, 2023 and at any time thereafter, plus accrued and unpaid interest, if any, to the applicable redemption date of the 2017 Notes. 47 We may from time to time seek to retire, extend or purchase our outstanding debt through cash purchases and/or exchanges for equity securities, in open market purchases, privately negotiated transactions or otherwise. Such extensions, repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material. Historically, we have financed capital expenditures with a combination of net cash provided by operating and financing activities. Our ability to access the capital markets may be restricted at the time when we would like, or need, to do so, which could have an adverse impact on our ability to maintain our operations and to grow. If any of our lenders become unable to perform their obligations under the Amended Credit Agreement, our borrowing capacity under our revolving credit facility could be reduced. Inability to borrow additional amounts under our revolving credit facility could limit our ability to fund our future growth and operations. Based on current market conditions, we expect that net cash provided by operating activities and borrowings under our revolving credit facility will be sufficient to finance our operating expenditures, capital expenditures and other contractual cash obligations, including our debt obligations. However, if net cash provided by operating activities and borrowings under our revolving credit facility are not sufficient, we may seek additional debt or equity financing. Unrestricted Cash. Of our $19.3 million unrestricted cash balance at December 31, 2018, $18.7 million was held by our non- U.S. subsidiaries. In the event of a distribution of earnings to the U.S. in the form of dividends, we may be subject to foreign withholding taxes. We do not believe that the cash held by our non-U.S. subsidiaries has an adverse impact on our liquidity because we expect that the cash we generate in the U.S., the available borrowing capacity under our revolving credit facility and the repayment of intercompany liabilities from our non-U.S. subsidiaries will be sufficient to fund the cash needs of our U.S. operations for the foreseeable future. Dividends.  We do not currently anticipate paying cash dividends on our common stock. We currently intend to retain our future earnings to support the growth and development of our business. The declaration of any future cash dividends and, if declared, the amount of any such dividends, will be subject to our financial condition, earnings, capital requirements, financial covenants, applicable law and other factors our board of directors deems relevant. Contractual Obligations.  The following table summarizes our cash contractual obligations as of December 31, 2018 and the effect such obligations are expected to have on our liquidity and cash flow in future periods (in thousands): Total 2019 2020-2021 2022-2023 Thereafter Debt:(1) Revolving credit facility due October 2023 8.125% senior notes due May 2025 (2) Other Total debt Interest on debt Purchase commitments Facilities and other operating leases Total contractual obligations $ 35,000 $ 375,000 687 410,687 215,030 483,074 34,997 $ 1,143,788 — $ — — $ — 449 449 34,578 480,422 6,076 238 238 69,156 2,652 10,512 35,000 $ — — — 35,000 68,222 — 6,794 375,000 — 375,000 43,074 — 11,615 $ 521,525 $ 82,558 $ 110,016 $ 429,689 (1) (2) For more information on our debt, see Note 11 to the Financial Statements. Amounts represent the full face value of the 2017 Notes and do not include unamortized debt financing costs of $6.4 million as of December 31, 2018. As of December 31, 2018, $27.8 million of unrecognized tax benefits (including discontinued operations) have been recorded as liabilities in accordance with the accounting standard for income taxes related to uncertain tax positions, and we are uncertain as to if or when such amounts may be settled. Related to these unrecognized tax benefits, we have also recorded a liability for potential penalties and interest (including discontinued operations) of $4.7 million. 48 Indemnifications. In conjunction with, and effective as of the completion of, the Spin-off, we entered into the separation and distribution agreement with Archrock, which governs, among other things, the treatment between Archrock and us relating to certain aspects of indemnification, insurance, confidentiality and cooperation. Generally, the separation and distribution agreement provides for cross-indemnities principally designed to place financial responsibility for the obligations and liabilities of our business with us and financial responsibility for the obligations and liabilities of Archrock’s business with Archrock. Pursuant to the agreement, we and Archrock will generally release the other party from all claims arising prior to the Spin-off that relate to the other party’s business, subject to certain exceptions. Additionally, in conjunction with, and effective as of the completion of, the Spin-off, we entered into the tax matters agreement with Archrock. Under the tax matters agreement and subject to certain exceptions, we are generally liable for, and indemnify Archrock against, taxes attributable to our business, and Archrock is generally liable for, and indemnify us against, all taxes attributable to its business. We are generally liable for, and indemnify Archrock against, 50% of certain taxes that are not clearly attributable to our business or Archrock’s business. Any payment made by us to Archrock, or by Archrock to us, is treated by all parties for tax purposes as a nontaxable distribution or capital contribution, respectively, made immediately prior to the Spin-off. Off-Balance Sheet Arrangements We have no material off-balance sheet arrangements. Effects of Inflation Our revenues and results of operations have not been materially impacted by inflation in the past three fiscal years. Critical Accounting Policies, Practices and Estimates This discussion and analysis of our financial condition and results of operations is based upon the Financial Statements, which have been prepared in accordance with GAAP. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. On an ongoing basis, we evaluate our estimates and accounting policies, including those related to bad debt, inventories, accrued demobilization costs, fixed assets, intangible assets, income taxes, revenue recognition, contingencies and litigation. We base our estimates on historical experience and on 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 liquidity. See Note 2 to our Financial Statement for a summary of significant accounting policies. Allowances and Reserves We maintain allowances for doubtful accounts for estimated losses resulting from the inability of our customers to make required payments. The determination of the collectability of amounts due from our customers requires us to use estimates and make judgments regarding future events and trends, including monitoring our customers’ payment history and current creditworthiness to determine that collectibility is reasonably assured, as well as consideration of the overall business climate in which our customers operate. Inherently, these uncertainties require us to make judgments and estimates regarding our customers’ ability to pay amounts due to us in order to determine the appropriate amount of valuation allowances required for doubtful accounts. We review the adequacy of our allowance for doubtful accounts quarterly. We determine the allowance needed based on historical write-off experience and by evaluating significant balances aged greater than 90 days individually for collectibility. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. During the years ended December 31, 2018, 2017 and 2016, we recorded bad debt expense of $0.1 million, $0.9 million and $3.0 million, respectively. Our allowance for doubtful accounts was approximately 2% of our gross accounts receivable balance at December 31, 2018 and 2017. Inventory is a significant component of current assets and is stated at the lower of cost and net realizable value. This requires us to record provisions and maintain reserves for obsolete and slow moving inventory. To determine these reserve amounts, we regularly review inventory quantities on hand and compare them to historical demand and management estimates of market conditions and production requirements. These estimates and forecasts inherently include uncertainties and require us to make judgments regarding potential outcomes. During 2018, 2017 and 2016, we recorded $0.1 million, $1.3 million and $0.8 million, respectively, in inventory write-downs and reserves for inventory which was obsolete or slow moving. Significant or unanticipated changes to our estimates and forecasts could impact the amount and timing of any additional provisions for obsolete or slow moving inventory that may be required. Our reserve for obsolete and slow moving inventory was approximately 10% and 11% of our gross raw materials inventory balance at December 31, 2018 and 2017, respectively. 49 Accrued Demobilization Costs The majority of our contract operations services contracts contain contractual requirements for us to perform demobilization activities at the end of the contract, with the scope of those activities varying by contract. Demobilization activities typically include, among other requirements, civil work and the removal of our equipment and installation from the customer’s site. Demobilization activities represent costs to fulfill obligations under our contracts and are not considered distinct within the context of our contract operations services contracts. Accrued demobilization costs are recorded, if applicable, at the time we become contractually obligated to perform these activities, which generally occurs upon our completion of the installation and commissioning of our equipment at the customer’s site. We record accrued demobilization costs as a liability and an equivalent demobilization asset as a capitalized fulfillment cost. As of December 31, 2018, we had current and long-term accrued demobilization costs liability balances of $14.8 million and $19.5 million, respectively. Accrued demobilization costs are subsequently increased by interest accretion throughout the expected term of the contract. As of December 31, 2018, we had capitalized fulfillment costs relating to demobilization assets of $6.6 million. Demobilization assets are amortized to cost of sales on a straight-line basis over the expected term of the contract. Any difference between the actual costs realized for the demobilization activities and the estimated liability established are recognized in cost of sales in our statement of operations. Accrued demobilization costs recorded represent the fair value of the estimated cost for future demobilization activities. The initial obligation is measured at its estimated fair value using various judgments and assumptions. Fair value is calculated using an expected present value technique that is based on assumptions of market participants and estimated demobilization costs in current period dollars that are inflated to the anticipated demobilization date and then discounted back to the date the demobilization obligations are expected to be incurred. Changes in assumptions and estimates included within the calculations of the value of the accrued demobilization costs could result in significantly different results than those identified and recorded in our financial statements. In future periods, we may also make adjustments to accrued demobilization costs as a result of the availability of new information, contract amendments, technology changes, changes in labor costs and other factors. Accrued demobilization costs are based on a number of assumptions requiring professional judgment. These include estimates for: (1) expected future cash flows related to contractual obligations; (2) anticipated timing of the expected cash flows; (3) our credit-adjusted risk free rate that considers our estimated credit rating; (4) the market risk premiums; and (5) relevant inflation factors. If the expected future cash flows relating to our estimated accrued demobilization costs had been higher or lower by 10% in 2018, accrued demobilization costs would have decreased or increased by approximately $3.4 million at December 31, 2018. We are unable to predict the type of revisions to these assumptions that will be required in future periods due to the availability of additional information, contract amendments, technology changes, the price of labor costs and other factors. Depreciation Property, plant and equipment is carried at cost. Depreciation for financial reporting purposes is computed on a straight-line basis using estimated useful lives and salvage values, including idle assets in our active fleet. The assumptions and judgments we use in determining the estimated useful lives and salvage values of our property, plant and equipment reflect both historical experience and expectations regarding future use of our assets. We periodically analyze our estimates of useful lives of our property, plant and equipment to determine if the depreciable periods and salvage values continue to be appropriate. The use of different estimates, assumptions and judgments in the establishment of property, plant and equipment accounting policies, especially those involving their useful lives, would likely result in significantly different net book values of our assets and results of operations. In the fourth quarter of 2017, we evaluated the estimated useful lives and salvage values of our property, plant and equipment. As a result of this evaluation, we changed the estimate of useful lives and salvage values for our compression equipment from a maximum useful life of 30 years to 23 years and a maximum salvage value of 20% to 15% based on expected future use. During the years ended December 31, 2018 and 2017, we recorded an increase in depreciation expense of $8.9 million and $1.2 million, respectively, as a result of these changes in useful lives and salvage values. 50 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 compressor units from our active fleet, indicate that the carrying amount of an asset may not be recoverable. Compressor units in our active fleet that were idle as of December 31, 2018 comprise a net book value of approximately $83.1 million. The determination that the carrying amount of an asset may not be recoverable requires us to make judgments regarding long-term forecasts of future revenue and costs related to the assets subject to review. For idle compression units that are removed from the active fleet and that will be sold to third parties as working compression units, significant assumptions include forecasted sale prices based on future market conditions and demand, forecasted costs to maintain the assets until sold and the forecasted length of time necessary to sell the assets. 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. An impairment loss exists when estimated undiscounted cash flows expected to result from the use of the asset and its eventual disposition are less than its carrying amount. When necessary, an impairment loss is recognized and represents the excess of the asset’s carrying value as compared to its estimated fair value and is charged to the period in which the impairment occurred. Income Taxes Our income tax provision, 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 approximately 25 countries and, as a result, we and our subsidiaries file consolidated and separate income tax returns in the U.S. federal jurisdiction and in numerous state and foreign jurisdictions. In addition, certain of our operations were historically included in Archrock’s consolidated income tax returns in the U.S. federal and state jurisdictions. Our tax provision for periods prior to the Spin-off was determined on a separate return, stand-alone basis. Differences between the separate return method utilized and Archrock’s U.S. income tax returns and cash flows attributable to income taxes for our U.S. operations were recognized as distributions to, or contributions from, parent within parent equity. Significant judgments and estimates are required in determining our consolidated income tax provision. Deferred income taxes arise from temporary differences between the financial statement carrying amounts and the tax basis of assets and liabilities. In evaluating our ability to recover our deferred tax assets within the jurisdiction from which they arise, 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, state and foreign 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 are using to manage the underlying businesses. In evaluating the objective evidence that historical results provide, we consider three years of cumulative operating income (loss). The accounting standard for income taxes provides that a tax benefit from an uncertain tax position is only 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. In addition, guidance is provided on measurement, derecognition, classification, interest and penalties, accounting in interim periods, disclosure and transition. We adjust reserves for unrecognized tax benefits 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 tax liabilities. These differences will be reflected as increases or decreases to income tax provision in the period in which new information is available. We consider the earnings of substantially all of our subsidiaries to be indefinitely reinvested, and accordingly, we have not provided for taxes on these unremitted earnings. If we were to make a distribution from the unremitted earnings of these subsidiaries, we could be subject to taxes payable to various jurisdictions. If our expectations were to change regarding future tax consequences, we may be required to record additional deferred taxes that could have a material effect on our consolidated statement of financial position, results of operations or cash flows. 51 Revenue Recognition — Product Sales Recognized Over Time In our product sales segment, we recognize revenue from the sale of compression equipment and processing and treating equipment over time based on the proportion of labor hours expended to the total labor hours expected to complete the contract performance obligation when the applicable criteria are met. During the year ended December 31, 2018, approximately 98% of our total product sales revenues were recognized over time. This calculation requires management to estimate the number of total labor hours required for each project and to estimate the profit expected on the project. The recognition of revenue over time based on the proportion of labor hours expended to the total labor hours expected to complete depends largely on our ability to make reasonable dependable estimates related to the extent of progress toward completion of the contract, contract revenues and contract costs. Recognized revenues and profits are subject to revisions as the contract progresses to completion. Revisions in profit estimates are charged to income in the period in which the facts that give rise to the revision become known using the cumulative catch-up method. Due to the nature of some of our contracts, developing the estimates of costs often requires significant judgment. Factors that must be considered in estimating the work to be completed and ultimate profit include labor productivity and availability, the nature and complexity of work to be performed, the impact of change orders, availability of raw materials and the impact of delayed performance. Although we continually strive to accurately estimate our progress toward completion and profitability, adjustments to overall contract revenue and contract costs could be significant in future periods due to several factors including but not limited to, settlement of claims against customers, supplier claims by or against us, customer change orders, changes in cost estimates, changes in project contingencies and settlement of customer claims against us, such as liquidated damage claims. If the aggregate combined cost estimates for uncompleted contracts that are recognized over time based on the proportion of labor hours expended to the total labor hours expected to complete in our product sales business had been higher or lower by 5% in 2018, our income before income taxes would have decreased or increased by approximately $11.3 million. Contingencies and Litigation We are substantially self-insured for workers’ compensation, employer’s liability, property, auto liability, general liability 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 deductible amounts are estimated and accrued based upon known facts, historical trends and industry averages. We review these estimates quarterly and believe such accruals to be adequate. However, insurance liabilities are difficult to estimate due to unknown factors, including the severity of an injury, the determination of our liability in proportion to other parties, the timeliness of reporting of occurrences, ongoing treatment or loss mitigation, general trends in litigation recovery outcomes and the effectiveness of safety and risk management programs. Therefore, if our actual experience differs from the assumptions and estimates used for recording the liabilities, adjustments may be required and would be recorded in the period in which the difference becomes known. As of December 31, 2018 and 2017, we had recorded approximately $1.1 million and $1.3 million, respectively, in insurance claim reserves. 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, the accounting standard for contingencies requires management to make judgments about future events that are inherently uncertain. We are required to record (and have recorded) a loss during any period in which we believe a loss contingency is probable and can be reasonably estimated. In making determinations of likely outcomes of pending or threatened legal matters, we consider the evaluation of counsel knowledgeable about each matter. We regularly assess and, if required, establish accruals for income tax as well as non-income-based tax contingencies pursuant to the applicable accounting standards that could result from assessments of additional tax by taxing jurisdictions in countries where we operate. Tax contingencies are subject to a significant amount of judgment and are reviewed and adjusted on a quarterly basis in light of changing facts and circumstances considering the outcome expected by management. As of December 31, 2018 and 2017, we had recorded approximately $37.6 million and $27.6 million, respectively, of accruals for tax contingencies (including penalties and interest and discontinued operations). Of these amounts, $32.5 million and $24.8 million are accrued for income taxes as of December 31, 2018 and 2017, respectively, and $5.1 million and $2.8 million are accrued for non-income-based taxes as of December 31, 2018 and 2017, respectively. Furthermore, as of December 31, 2018 and 2017, we had an indemnification receivable from Archrock related to non-income-based taxes of $2.8 million and $1.5 million, respectively. If our actual experience differs from the assumptions and estimates used for recording the liabilities, adjustments may be required and would be recorded in the period in which the difference becomes known. Recent Accounting Pronouncements See Note 2 to the Financial Statements. 52 Item 7A.  Quantitative and Qualitative Disclosures About Market Risk We are exposed to market risks associated with changes in foreign currency exchange rates due to our significant international operations. While the majority of our revenue contracts are denominated in the U.S. dollar, certain contracts or portions of certain contracts, most notably within our contract operations segment, are exposed to foreign currency fluctuations. Approximately 25% of revenues in our contract operations segment are denominated in a currency other than the U.S. dollar. The currencies for which we have our largest exchange rate exposures are related to changes in the Argentine Peso and the Brazilian Real. During the year ended December 31, 2018, a devaluation of the Argentine Peso and Brazilian Real of approximately 52% and 15%, respectively, resulted in a decrease in revenue in our contract operations segment of approximately $20 million and $4 million, respectively. The impact of foreign currency risk on income for these contracts is generally mitigated by matching costs with revenues in the same currency. Additionally, the net assets and liabilities of our international operations are exposed to changes in foreign currency exchange rates. These operations may have net assets and liabilities not denominated in their functional currency, which exposes us to changes in foreign currency exchange rates that impact income. We recorded foreign currency losses of $8.5 million and $0.7 million in our statements of operations during the years ended December 31, 2018 and 2017, respectively. Our foreign currency gains and losses are primarily due to exchange rate fluctuations related to monetary asset and liability balances denominated in currencies other than the functional currency, including foreign currency exchange rate changes recorded on intercompany obligations. Our material exchange rate exposure relates to intercompany loans to a subsidiaries whose functional currency are the Brazilian Real and Canadian Dollar, which loans carried U.S. dollars balances of $27.4 million and $15.9 million, respectively, as of December 31, 2018. Foreign currency losses during the years ended December 31, 2018 and 2017 included translation losses of $5.2 million and translation gains of $0.5 million, respectively, related to the functional currency remeasurement of our foreign subsidiaries’ non-functional currency denominated intercompany obligations. Changes in exchange rates may create gains or losses in future periods to the extent we maintain net assets and liabilities not denominated in the functional currency. We also have exposure to foreign currency exchange risk from the translation of certain international operating units from the local currency into the U.S. dollar. Our comprehensive income for the years ended December 31, 2018 and 2017 included foreign currency translation adjustment losses of $7.5 million and $1.8 million, respectively. A 10% increase in the value of the U.S. dollar relative to foreign currencies would have increased our foreign currency translation adjustment loss by approximately $4.5 million for the year ended December 31, 2018. This sensitivity analysis is inherently limited as it assumes that rates of multiple foreign currencies will always move in the same direction relative to the value of the U.S. dollar. As of December 31, 2018, we do not have any derivative financial instruments outstanding to mitigate foreign currency risk. In the future, we may utilize derivative instruments to manage the risk of fluctuations in foreign currency exchange rates that could potentially impact our future earnings and forecasted cash flows. Item 8.  Financial Statements and Supplementary Data The consolidated financial statements and supplementary information specified by this Item are presented in Part IV, Item 15 (“Exhibits and Financial Statement Schedules”) of this report. Item 9.  Changes in and Disagreements with Accountants on Accounting and Financial Disclosure None. Item 9A.  Controls and Procedures This Item 9A includes information concerning the controls and controls evaluation referred to in the certifications of our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”) required by Rule 13a-14 of the Exchange Act included in this Annual Report as Exhibits 31.1 and 31.2. 53 Management’s Evaluation of Disclosure Controls and Procedures The CEO and CFO have reviewed and evaluated the effectiveness of the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of the end of the fiscal year for which this annual report on Form 10-K is filed. Based on that evaluation, the CEO and CFO have concluded that the current disclosure controls and procedures are effective to ensure that information required to be disclosed in reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms, and include controls and procedures designed to ensure that information required to be disclosed by the Company in such reports is accumulated and communicated to management, including the CEO and CFO, as appropriate to allow timely decisions regarding required disclosures. Management, including our CEO (principal executive officer) and CFO (principal financial officer), believes the consolidated financial statements included in this Annual Report on Form 10-K fairly represent in all material respects our financial condition, results of operations and cash flows at and for the periods presented in accordance with U.S. GAAP. Management’s Annual Report on Internal Control over Financial Reporting Management, under the supervision of our principal executive officer and principal financial officer, is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) and 15d(f) under the Exchange Act). Internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external reporting purposes in accordance with GAAP, and includes those policies and procedures that: (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with GAAP, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and directors of the Company; and (iii) provide reasonable assurance regarding the 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 the 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. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis. Our management conducted an assessment of the effectiveness of our internal control over financial reporting as of December 31, 2018. This assessment was based on the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission in Internal Control-Integrated Framework (2013 framework). Based on this assessment, management determined that our internal control over financial reporting was effective as of December 31, 2018. Our independent registered public accounting firm has issued a report on the effectiveness of our internal control over financial reporting which is below. 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. The effectiveness of our internal control over financial reporting as of December 31, 2018 has been audited by Deloitte & Touche, LLP, an independent registered public accounting firm, as stated in their attestation report that follows. 54 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the shareholders and the Board of Directors of Exterran Corporation Opinion on Internal Control over Financial Reporting We have audited the internal control over financial reporting of Exterran Corporation and subsidiaries (the “Company”) as of December 31, 2018, 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, 2018, 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 statements of operations, comprehensive income (loss), stockholders’ equity, cash flows, and the related notes and schedule listed in the Index at Item 15 (collectively referred to as the “financial statements”) for the year ended December 31, 2018, of the Company and our report dated February 26, 2019, 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 26, 2019 55 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 report is incorporated by reference to the sections entitled “Election of Directors,” “Corporate Governance,” “Executive Officers” and “Beneficial Ownership of Common Stock” in our definitive proxy statement, to be filed with the SEC within 120 days of the end of our fiscal year. We have adopted a Code of Business Conduct, which is available on our website at http://www.exterran.com under the “Investors — Governance Highlights” section. Any amendments to, or waivers of, the Code of Business Conduct will be disclosed on our website promptly following the date of such amendment or waiver. Item 11.  Executive Compensation  The information required in Part III, Item 11 of this report is incorporated by reference to the sections entitled “Compensation Discussion and Analysis” and “Information Regarding Executive Compensation” 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 See the table below for securities authorized for issuance under our equity compensation plans. Other information required in Part III, Item 12 of this report are incorporated by reference to the section entitled “Beneficial Ownership of Common Stock” 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, 2018, with respect to the Exterran Corporation compensation plans under which our common stock is authorized for issuance, aggregated as follows: (a) Number of Securities to be Issued Upon Exercise of Outstanding Options, Warrants and Rights (b) Weighted-Average Exercise Price of Outstanding Options, Warrants and Rights (c) Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans (Excluding Securities Reflected in Column (a)) (#) ($) (#) 73,564 $ — 73,564 25.81 — 1,192,308 — 1,192,308 Plan Category Equity compensation plans approved by security holders (1) Equity compensation plans not approved by security holders Total (1) Comprised of (i) the Exterran Corporation 2015 Stock Incentive Plan, the (“2015 Plan”) and (ii) the Exterran Corporation 2015 Directors’ Stock and Deferral Plan. The 2015 Plan also governs awards originally granted by Archrock under the Archrock, Inc. 2013 Stock Incentive Plan. In addition to the outstanding options, as of December 31, 2018, there were 539,666 restricted stock units outstanding, payable in common stock upon vesting, under the 2015 Plan. Item 13.  Certain Relationships and Related Transactions and Director Independence The information required in Part III, Item 13 of this report is incorporated by reference to the sections entitled “Certain Relationships and Related Transactions” and “Corporate Governance” in our definitive proxy statement, to be filed with the SEC within 120 days of the end of our fiscal year. 56 Item 14.  Principal Accountant Fees and Services The information required in Part III, Item 14 of this report is incorporated by reference to the section entitled “Ratification of the Appointment of 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. 57 Item 15.  Exhibits and Financial Statement Schedules (a) Documents filed as a part of this report. PART IV 1. Financial Statements.  The following financial statements are filed as a part of this report. Report of Independent Registered Public Accounting Firm Consolidated Balance Sheets Consolidated Statements of Operations Consolidated Statements of Comprehensive Income (Loss) Consolidated Statements of Stockholders’ Equity Consolidated Statements of Cash Flows Notes to Consolidated Financial Statements 2. Financial Statement Schedule Schedule II — Valuation and Qualifying Accounts F-1 F-2 F-3 F-4 F-5 F-6 F-8 S-1 All other schedules have been omitted because they are not required under the relevant instructions. 3. Exhibits Exhibit No. 2.1 2.2 3.1 3.2 3.3 4.1 4.2 10.1 10.2 10.3 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 First Amendment to Separation and Distribution Agreement, dated as of December 15, 2015, by and among Archrock, 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 2.2 to the Registrant’s Original Annual Report on Form 10-K for the year ended December 31, 2015 filed on February 26, 2016 Amended and Restated Certificate of Incorporation of Exterran Corporation, incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Amended and Restated Bylaws of Exterran Corporation, incorporated by reference to Exhibit 3.2 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Restated Certificate of Incorporation of the Company, incorporated by reference to Exhibit 3.1 to the Registrant’s Current Report on From 8-K filed on April 30, 2018 Indenture, dated as of April 4, 2017, by and among Exterran Energy Solutions, L.P., EES Finance Corp., Exterran Corporation, as parent, the subsidiary guarantors party thereto from time to time, and Wells Fargo Bank, National Association, as trustee, incorporated by reference to Exhibit 4.1 to the Registrant’s Current Report on Form 8-K filed on April 4, 2017 Registration Rights Agreement, dated as of April 4, 2017, by and among Exterran Energy Solutions, L.P., EES Finance Corp., Exterran Corporation and Wells Fargo Securities, LLC, for itself and as representative of the other Initial Purchasers, incorporated by reference to Exhibit 4.3 to the Registrant’s Current Report on Form 8-K filed on April 4, 2017 Tax Matters Agreement, dated as of November 3, 2015, by and between Exterran Holdings, 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 Form of Indemnification Agreement, incorporated by reference to Exhibit 10.5 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Amended and Restated Credit Agreement, dated as of October 5, 2015, by and among Exterran Holdings, Inc., Exterran Energy Solutions, L.P., the lenders signatory thereto and Wells Fargo Bank, National Association, as administrative agent, incorporated by reference to Exhibit 4.2 to Amendment No. 5 to the Company’s Registration Statement on Form 10-12B, as filed on October 6, 2015 58 Exhibit No. 10.4† 10.5† 10.6† 10.7† 10.8† 10.9† 10.10† 10.11† 10.12† 10.13† 10.14† 10.15† 10.16† 10.17† 10.18† 10.19† 10.20† 10.21† 10.22† 10.23† 10.24† Description Exterran Corporation 2015 Stock Incentive Plan, incorporated by reference to Exhibit 99.1 to the Company’s Registration Statement on Form S-8, as filed on November 2, 2015 Form of Award Notice and Agreement for Incentive Stock Options pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.8 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Award Notice and Agreement for Nonqualified Stock Options pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.9 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Award Notice and Agreement for Performance Units pursuant to the 2015 Stock Incentive Plan, 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 2015 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 Form of Award Notice and Agreement for Cash-Settled Restricted Stock Units pursuant to the 2015 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 Award Notice and Agreement for Stock-Settled Restricted Stock Units pursuant to the 2015 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 Form of Award Notice and Agreement for Common Stock Award for Non-Employee Directors pursuant to the 2015 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 Corporation Directors’ Stock and Deferral Plan, incorporated by reference to Exhibit 99.2 to the Company’s Registration Statement on Form S-8, as filed on November 2, 2015 Form of Employment Letter, incorporated by reference to Exhibit 10.16 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Form of Severance Benefit Agreement, incorporated by reference to Exhibit 10.11 to Amendment No. 4 to the Company’s Registration Statement on Form 10-12B, as filed on August 5, 2015 Form of Change of Control Agreement, incorporated by reference to Exhibit 10.10 to Amendment No. 4 to the Company’s Registration Statement on Form 10-12B, as filed on August 5, 2015 Exterran Corporation Deferred Compensation Plan, incorporated by reference to Exhibit 10.19 to the Registrant’s Current Report on Form 8-K filed on November 5, 2015 Exterran Corporation Amended and Restated Directors’ Stock and Deferral Plan, incorporated by reference to Exhibit 10.20 to the Registrant’s Original Annual Report on Form 10-K for the year ended December 31, 2015 filed on February 26, 2016 First Amendment, Exterran Corporation Deferred Compensation Plan, incorporated by reference to Exhibit 10.3 of the Registrant’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2016 filed on January 4, 2017 2016 Form of Severance Benefit Agreement, incorporated by reference to Exhibit 10.4 of the Registrant’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2016 filed on January 4, 2017 2016 Form of Change of Control Agreement, incorporated by reference to Exhibit 10.5 of the Registrant’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2016 filed on January 4, 2017 Form of Award Notice and Agreement for Performance Units pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.29 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2016 filed on March 10, 2017 Form of Award Notice and Agreement for Restricted Stock pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.30 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2016 filed on March 10, 2017 Form of Award Notice and Agreement for Cash-Settled Restricted Stock Units pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.31 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2016 filed on March 10, 2017 Form of Award Notice and Agreement for Stock-Settled Restricted Stock Units pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.32 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2016 filed on March 10, 2017 59 Exhibit No. 10.25† 10.26† 10.27† 10.28† 10.29† 10.30 21.1* 23.1* 24.1* 31.1* 31.2* 32.1** 32.2** Description Form of Award Notice and Agreement for Common Stock Award for Non-Employee Directors pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.33 to the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2016 filed on March 10, 2017 Form of Award Notice and Agreement for Performance Units pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.1 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 filed on May 3, 2018 Form of Award Notice and Agreement for Restricted Stock pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.2 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 filed on May 3, 2018 Form of Award Notice and Agreement for Stock-Settled Restricted Stock Units pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.3 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 filed on May 3, 2018 Form of Award Notice and Agreement for Cliff-Vested Restricted Stock pursuant to the 2015 Stock Incentive Plan, incorporated by reference to Exhibit 10.4 to the Registrant’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2018 filed on May 3, 2018 Second Amended and Restated Credit Agreement, dated as of October 9, 2018, by and among Exterran Corporation, Exterran Energy Solutions, L.P., the lenders signatory thereto and Wells Fargo Bank, National Association, as administrative agent, incorporated by reference to Exhibit 10.1 to the Registrant’s Current Report on Form 8-K filed on October 9, 2018 List of Subsidiaries Consent of Deloitte & Touche LLP Powers of Attorney (included on the signature page to this Report) 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 101.INS XBRL Instance Document. 101.SCH XBRL Taxonomy Extension Schema Document. 101.CAL XBRL Extension Calculation Linkbase Document. 101.DEF XBRL Taxonomy Extension Definition Linkbase Document. 101.LAB XBRL Taxonomy Extension Labels Linkbase Document. 101.PRE XBRL Taxonomy Extension Presentation Linkbase Document. † * ** Management contract or compensatory plan or arrangement. Filed herewith. Furnished, not filed. Item 16.  Form 10-K Summary None. 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 Exterran Corporation /s/ ANDREW J. WAY Name: Andrew J. Way Title: President and Chief Executive Officer Date: February 26, 2019 61 POWER OF ATTORNEY KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints Andrew J. Way, David A. Barta, Valerie L. Banner and Michael W. Sanders, 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 26, 2019. Signature Title /s/ ANDREW J. WAY Andrew J. Way /s/ DAVID A. BARTA David A. Barta /s/ MICHAEL W. SANDERS Michael W. Sanders /s/ WILLIAM M. GOODYEAR William M. Goodyear /s/ JOHN P. RYAN John P. Ryan /s/ CHRISTOPHER T. SEAVER Christopher T. Seaver /s/ IEDA GOMES YELL Ieda Gomes Yell /s/ JAMES C. GOUIN James C. Gouin /s/ MARK R. SOTIR Mark R. Sotir President and 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 62 REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the shareholders and the Board of Directors of Exterran Corporation Opinion on the Financial Statements We have audited the accompanying consolidated balance sheets of Exterran Corporation and subsidiaries (the “Company”) as of December 31, 2018 and 2017, the related consolidated statements of operations, comprehensive income (loss), stockholders’ equity, and cash flows, for each of the three years in the period ended December 31, 2018, and the related notes and the schedule 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, 2018 and 2017, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2018, 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, 2018, 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 26, 2019, 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. /s/ DELOITTE & TOUCHE LLP Houston, Texas February 26, 2019 We have served as the Company’s auditor since 2014. F-1 EXTERRAN CORPORATION CONSOLIDATED BALANCE SHEETS (In thousands, except par value and share amounts) ASSETS Current assets: Cash and cash equivalents Restricted cash Accounts receivable, net of allowance of $5,474 and $5,388, respectively Inventory, net (Note 5) Costs and estimated earnings in excess of billings on uncompleted contracts Contract assets (Note 3) Other current assets Current assets held for sale (Note 8) Current assets associated with discontinued operations (Note 4) Total current assets Property, plant and equipment, net (Note 6) Deferred income taxes (Note 16) Intangible and other assets, net (Note 7) Long-term assets held for sale (Note 8) Long-term assets associated with discontinued operations (Note 4) Total assets LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable, trade Accrued liabilities (Note 10) Deferred revenue Billings on uncompleted contracts in excess of costs and estimated earnings Contract liabilities (Note 3) Current liabilities associated with discontinued operations (Note 4) Total current liabilities Long-term debt (Note 11) Deferred income taxes (Note 16) Long-term deferred revenue Long-term contract liabilities (Note 3) Other long-term liabilities Long-term liabilities associated with discontinued operations (Note 4) Total liabilities Commitments and contingencies (Note 21) Stockholders’ equity: $ $ $ December 31, 2018 2017 $ 19,300 178 248,467 150,689 — 91,602 44,234 — 11,605 566,075 901,577 11,370 86,371 — 1,661 49,145 546 266,052 107,909 40,695 — 38,707 15,761 23,751 542,566 822,279 10,550 76,980 4,732 3,700 1,567,054 $ 1,460,807 $ 165,744 123,335 — — 153,483 14,767 457,329 403,810 6,005 — 101,363 39,812 5,914 1,014,233 148,744 114,336 23,902 89,565 — 31,971 408,518 368,472 9,746 92,485 — 20,272 6,528 906,021 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; 36,868,066 and 36,193,930 shares issued, respectively Additional paid-in capital Accumulated deficit Treasury stock — 721,280 and 453,178 common shares, at cost, respectively Accumulated other comprehensive income Total stockholders’ equity (Note 17) Total liabilities and stockholders’ equity 369 734,458 (208,677) (11,560) 38,231 552,821 1,567,054 $ 362 739,164 (223,510) (6,937) 45,707 554,786 1,460,807 $ The accompanying notes are an integral part of these consolidated financial statements. F-2 EXTERRAN CORPORATION CONSOLIDATED STATEMENTS OF OPERATIONS (In thousands, except per share amounts) Revenues (Note 3): Contract operations Aftermarket services Product sales Costs and expenses: Cost of sales (excluding depreciation and amortization expense): Contract operations Aftermarket services Product sales Selling, general and administrative Depreciation and amortization Long-lived asset impairment (Note 13) Restatement related charges (recoveries), net (Note 14) Restructuring and other charges (Note 15) Interest expense Equity in income of non-consolidated affiliates (Note 9) Other (income) expense, net Income (loss) before income taxes Provision for income taxes (Note 16) Income (loss) from continuing operations Income (loss) from discontinued operations, net of tax (Note 4) Net income (loss) Basic net income (loss) per common share (Note 19): Income (loss) from continuing operations per common share Income (loss) from discontinued operations per common share Net income (loss) per common share Diluted net income (loss) per common share (Note 19): Income (loss) from continuing operations per common share Income (loss) from discontinued operations per common share Net income (loss) per common share Years Ended December 31, 2018 2017 2016 $ 360,973 120,676 879,207 1,360,856 $ 375,269 107,063 732,962 1,215,294 $ 392,463 120,550 392,384 905,397 122,138 89,666 765,624 178,401 123,922 3,858 (276) 1,997 29,217 — 6,484 1,321,031 39,825 39,433 392 24,462 24,854 0.01 0.67 0.68 0.01 0.67 0.68 $ $ $ $ $ 133,380 78,221 656,553 176,318 107,824 5,700 3,419 3,189 34,826 — (975) 1,198,455 16,839 22,695 (5,856) 39,736 33,880 (0.17) 1.14 0.97 (0.17) 1.14 0.97 $ $ $ $ $ $ $ $ $ $ 143,670 87,342 365,394 157,485 132,886 14,495 18,879 22,038 34,181 (10,403) (13,046) 952,921 (47,524) 124,242 (171,766) (56,171) (227,937) (4.97) (1.62) (6.59) (4.97) (1.62) (6.59) Weighted average common shares outstanding used in net income (loss) per common share (Note 19): Basic Diluted 35,433 35,489 34,959 34,959 34,568 34,568 The accompanying notes are an integral part of these consolidated financial statements. F-3 EXTERRAN CORPORATION CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (In thousands) Net income (loss) Other comprehensive income (loss): Foreign currency translation adjustment Comprehensive income (loss) Years Ended December 31, 2018 2017 24,854 $ 33,880 $ 2016 (227,937) (7,476) 17,378 $ (1,801) 32,079 $ 18,310 (209,627) $ $ The accompanying notes are an integral part of these consolidated financial statements. F-4 EXTERRAN CORPORATION CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (In thousands, except share data) Balance at January 1, 2016 35,153,358 $ 352 $ 805,755 $ (29,315) (5,776) $ (54) $ 29,198 $ 805,936 Common Stock Shares Amount Additional Paid-in Capital Treasury Stock Accumulated Deficit Shares Amount Accumulated Other Comprehensive Income Total Net loss Options exercised Foreign currency translation adjustment Transfer to Archrock, Inc. (Note 17) Treasury stock purchased 61,177 Stock-based compensation, net of forfeitures 426,578 4 Other 786 (49,176) 10,962 (23) (227,937) 18,310 (196,654) (2,091) (227,937) 786 18,310 (49,176) (2,091) 10,966 (23) Balance at December 31, 2016 35,641,113 $ 356 $ 768,304 $ (257,252) (202,430) $ (2,145) $ 47,508 $ 556,771 Cumulative-effect adjustment from adoption of ASU 2016-09 Net income Options exercised Foreign currency translation adjustment Transfer to Archrock, Inc. (Note 17) Treasury stock purchased 69,122 Stock-based compensation, net of forfeitures 483,695 (138) 33,880 138 683 (44,720) 14,759 1 5 (1,801) (250,748) (4,792) — 33,880 684 (1,801) (44,720) (4,792) 14,764 Balance at December 31, 2017 36,193,930 $ 362 $ 739,164 $ (223,510) (453,178) $ (6,937) $ 45,707 $ 554,786 Cumulative-effect adjustment from adoption of ASC Topic 606 (Note 2) Net income Options exercised Foreign currency translation adjustment Transfer to Archrock, Inc. (Note 17) Treasury stock purchased 136,847 Stock-based compensation, net of forfeitures 537,289 (10,021) 24,854 1 6 547 (19,814) 14,561 (7,476) (268,102) (4,623) (10,021) 24,854 548 (7,476) (19,814) (4,623) 14,567 Balance at December 31, 2018 36,868,066 $ 369 $ 734,458 $ (208,677) (721,280) $ (11,560) $ 38,231 $ 552,821 The accompanying notes are an integral part of these consolidated financial statements. F-5 EXTERRAN CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS (In thousands) Cash flows from operating activities: Net income (loss) Adjustments to reconcile net income (loss) to cash provided by operating activities: Depreciation and amortization Long-lived asset impairment Amortization of deferred financing costs (Income) loss from discontinued operations, net of tax Provision for doubtful accounts Gain on sale of property, plant and equipment Equity in income of non-consolidated affiliates (Gain) loss on remeasurement of intercompany balances Loss on foreign currency derivatives Loss on sale of businesses Stock-based compensation expense Deferred income tax provision (benefit) Changes in assets and liabilities: Accounts receivable and notes Inventory Costs and estimated earnings versus billings on uncompleted contracts Contract assets Other current assets Accounts payable and other liabilities Deferred revenue Contract liabilities Other Net cash provided by continuing operations Net cash provided by (used in) discontinued operations Net cash provided by operating activities Cash flows from investing activities: Capital expenditures Proceeds from sale of property, plant and equipment Proceeds from sale of businesses Return of investments in non-consolidated affiliates Settlement of foreign currency derivatives Net cash used in continuing operations Net cash provided by discontinued operations Net cash used in investing activities Cash flows from financing activities: Proceeds from borrowings of debt Repayments of debt Cash transfer to Archrock, Inc. (Note 17) Payments for debt issuance costs Proceeds from stock options exercised F-6 Years Ended December 31, 2018 2017 2016 $ 24,854 $ 33,880 $ (227,937) 123,922 107,824 132,886 3,858 3,347 5,700 4,714 (24,462) (39,736) 14,495 4,584 56,171 2,972 (2,986) (10,403) (9,268) 709 — 10,966 71,090 863 (2,517) — (516) — 111 14,764 (3,193) (65,311) 126,276 20,594 40,949 — (1,541) 62,029 (13,711) — (14,483) 150,420 (1,794) 148,626 49,736 24,637 — (7,074) 2,078 24,414 — (857) 262,489 1,016 263,505 86 (629) — 5,241 — 1,714 14,567 1,537 8,669 (59,676) — (34,571) 5,045 13,801 — 62,934 3,059 153,296 4,004 157,300 (215,108) (131,673) (73,670) 2,530 5,000 — — 8,866 894 — — (207,578) (121,913) 17,009 19,575 (190,569) (102,338) 2,814 — 10,403 (709) (61,162) 36,079 (25,083) 585,014 501,088 430,758 (550,497) (476,503) (610,261) (18,744) (4,801) 548 (44,720) (7,911) 684 (49,176) (779) 786   Purchases of treasury stock Net cash provided by (used in) financing activities Effect of exchange rate changes on cash, cash equivalents and restricted cash Net increase (decrease) in cash, cash equivalents and restricted cash Cash, cash equivalents and restricted cash at beginning of period Cash, cash equivalents and restricted cash at end of period Supplemental disclosure of cash flow information: Income taxes paid, net Interest paid, net of capitalized amounts Supplemental disclosure of non-cash transactions: Accrued capital expenditures Non-cash proceeds from the sale of a plant Non-cash proceeds from sale of business $ $ $ $ $ $ (4,623) 6,897 (3,841) (30,213) 49,691 (4,792) (2,091) (32,154) (230,763) (792) 13,342 36,349 (1,832) 5,827 30,522 36,349 19,478 $ 49,691 $ 11,601 26,278 $ $ 47,403 28,178 $ $ 57,580 29,046 21,479 $ 16,735 $ — $ 14,573 $ — $ — $ 5,985 7,000 — The accompanying notes are an integral part of these consolidated financial statements. F-7 EXTERRAN CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS  Note 1. Description of Business and Basis of Presentation Description of Business Exterran Corporation (together with its subsidiaries, “Exterran Corporation,” “our,” “we” or “us”), a Delaware corporation formed in March 2015, is a global systems and process company offering solutions in the oil, gas, water and power markets. We are a leader in natural gas processing and treatment and compression products and services, providing critical midstream infrastructure solutions to customers throughout the world. Outside the United States of America (“U.S.”), we are a leading provider of full-service natural gas contract compression and a supplier of aftermarket parts and services. We provide our products and services to a global customer base consisting of companies engaged in all aspects of the oil and natural gas industry, including large integrated oil and natural gas companies, national oil and natural gas companies, independent oil and natural gas producers and oil and natural gas processors, gatherers and pipeline operators. Our manufacturing facilities are located in the U.S., Singapore and the United Arab Emirates. We operate in three primary business lines: contract operations, aftermarket services and product sales. In our contract operations business line, we provide compression and processing and treating services through the operation of our natural gas compression equipment and crude oil and natural gas production and process equipment for our customers. In our aftermarket services business line, we sell parts and components and provide operations, maintenance, repair, overhaul, upgrade, startup and commissioning and reconfiguration services to customers who own their own oil and natural gas compression, production, processing, treating and related equipment. In our product sales business line, we design, engineer, manufacture, install and sell natural gas compression packages as well as equipment used in the treating and processing of crude oil and natural gas to our customers throughout the world and for use in our contract operations business line. We also offer our customers, on either a contract operations basis or a sale basis, the engineering, design, project management, procurement and construction services necessary to incorporate our products into production, processing and compression facilities, which we refer to as integrated projects. On November 3, 2015, Archrock, Inc. (named Exterran Holdings, Inc. prior to November 3, 2015) (“Archrock”) completed the spin-off (the ‘‘Spin-off”) of its international contract operations, international aftermarket services and global fabrication businesses into an independent, publicly traded company named Exterran Corporation. Following the completion of the Spin- off, we and Archrock became and continue to be independent, publicly traded companies with separate boards of directors and management. Basis of Presentation The accompanying consolidated financial statements of Exterran Corporation included herein have been prepared in accordance with generally accepted accounting principles in the U.S. (“GAAP”) and the rules and regulations of the Securities and Exchange Commission (the “SEC”). Certain reclassifications resulting from the adoption of ASU 2016-18, Restricted Cash have been made to the statement of cash flows for the prior year periods to conform to the current year presentation. We refer to the consolidated financial statements collectively as “financial statements,” and individually as “balance sheets,” “statements of operations,” “statements of comprehensive income (loss),” “statements of stockholders’ equity” and “statements of cash flows” herein. Note 2. Significant Accounting Policies Use of Estimates in the Financial Statements The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amount of assets, liabilities, revenue and expenses, as well as the disclosures of contingent assets and liabilities. Because of the inherent uncertainties in this process, actual future results could differ from those expected at the reporting date. Significant estimates are required for contracts within our product sales segments that are accounted for based largely on our estimates on the extent of progress toward completion of the contracts, contract revenues and contract costs. As of December 31, 2018, we have made these significant estimates on all of our ongoing contracts. However, it is possible that current estimates could change due to unforeseen events, which could result in adjustments to our estimates. Variations from estimated contract performance could result in material adjustments to operating results. Management believes that the estimates and assumptions used are reasonable. F-8 Cash and Cash Equivalents We consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents. Restricted Cash Restricted cash as of December 31, 2018 and 2017 consists of cash that contractually is not available for immediate use. Restricted cash is presented separately from cash and cash equivalents in our balance sheets. Revenue Recognition Revenue is recognized when control of the promised goods or services are transferred to our customers, in an amount that reflects the consideration that we expect to receive in exchange for those goods or services. See Note 3 for further discussion on revenue recognition. Concentrations of Credit Risk Financial instruments that potentially subject us to concentrations of credit risk consist of cash and cash equivalents and accounts receivable. We believe that the credit risk in temporary cash investments is limited because our cash is held in accounts with multiple financial institutions. We record trade accounts receivable at the amount we invoice our customers, net of allowance for doubtful accounts. Trade accounts receivable are due from companies of varying sizes engaged principally in oil and natural gas activities throughout the world. 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 products and services we provide and the terms of our contract operations customer service agreements. We maintain allowances for doubtful accounts for estimated losses resulting from our customers’ inability to make required payments. The determination of the collectibility of amounts due from our customers requires us to use estimates and make judgments regarding future events and trends, including monitoring our customers’ payment history and current creditworthiness to determine that collectibility is reasonably assured, as well as consideration of the overall business climate in which our customers operate. Inherently, these uncertainties require us to make judgments and estimates regarding our customers’ ability to pay amounts due to us in order to determine the appropriate amount of valuation allowances required for doubtful accounts. We review the adequacy of our allowance for doubtful accounts quarterly. We determine the allowance needed based on historical write-off experience and by evaluating significant balances aged greater than 90 days individually for collectibility. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. During the years ended December 31, 2018, 2017 and 2016, we recorded bad debt expense of $0.1 million, $0.9 million and $3.0 million, respectively. Inventory Inventory consists of parts used for manufacturing or maintenance of natural gas compression equipment, production equipment, processing and treating equipment and facilities and parts held for sale. Inventory is stated at the lower of cost and net realizable value using the average cost method. A reserve is recorded against inventory balances for estimated obsolete and slow moving items based on specific identification, historical experience and management estimates of market conditions and production requirements. Property, Plant and Equipment Property, plant and equipment is recorded at cost and depreciated using the straight-line method over their estimated useful lives as follows: Compression equipment, processing facilities and other fleet assets Buildings Transportation, shop equipment and other 3 to 23 years 20 to 35 years 3 to 10 years F-9 Installation costs capitalized on contract operations projects are generally depreciated over the life of the underlying contract. Major improvements that extend the useful life of an asset are capitalized. Repairs and maintenance are expensed as incurred. When property, plant and equipment is sold, or otherwise disposed of, the gain or loss is recorded in other (income) expense, net. Interest is capitalized during the construction period on equipment and facilities that are constructed for use in our operations. The capitalized interest is included as part of the cost of the asset to which it relates and is amortized over the asset’s estimated useful life. Computer Software Certain costs related to the development or purchase of internal-use software are capitalized and amortized over the estimated useful life of the software, which ranges from three to five years. Costs related to the preliminary project stage and the post- implementation/operation stage of an internal-use computer software development project are expensed as incurred. Capitalized software costs are included in property, plant and equipment, net, in our balance sheets. Long-Lived Assets We review long-lived assets such as property, plant and equipment and identifiable intangibles subject to amortization for impairment whenever events or changes in circumstances, including the removal of compressor units 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 to result from the use of the asset and its eventual disposition are less than its carrying amount. When necessary, the excess of the asset’s carrying value as compared to its estimated fair value is recognized as an impairment in the period in which the impairment occurred. Identifiable intangibles are amortized over the assets’ estimated useful lives. Demobilization The majority of our contract operations services contracts contain contractual requirements for us to perform demobilization activities at the end of the contract, with the scope of those activities varying by contract. Demobilization activities typically include, among other requirements, civil work and the removal of our equipment and installation from the customer’s site. Demobilization activities represent costs to fulfill obligations under our contracts and are not considered distinct within the context of our contract operations services contracts. Accrued demobilization costs are recorded, if applicable, at the time we become contractually obligated to perform these activities, which generally occurs upon our completion of the installation and commissioning of our equipment at the customer’s site. We record accrued demobilization costs as a liability and an equivalent demobilization asset as a capitalized fulfillment cost. Accrued demobilization costs are subsequently increased by interest accretion throughout the expected term of the contract. During the year ended December 31, 2018, we recorded $2.6 million in accretion expense, which is reflected in depreciation and amortization expense in our statements of operations. Demobilization assets are amortized to cost of sales on a straight-line basis over the expected term of the contract. Any difference between the actual costs realized for the demobilization activities and the estimated liability established are recognized in cost of sales in our statement of operations. Other (Income) Expense, Net Other (income) expense, net, is primarily comprised of gains and losses from the remeasurement of our international subsidiaries’ net assets exposed to changes in foreign currency rates, short-term investments and the sale of used assets. Income Taxes Our operations are subject to U.S. federal, state and local and foreign income taxes. We and our subsidiaries file consolidated and separate income tax returns in the U.S. federal jurisdiction and in numerous state and foreign jurisdictions. 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 statement carrying amounts 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 rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. F-10 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. In the event we were to determine that we would be able to realize our deferred income tax assets in the future in excess of their net recorded amount, we would make an adjustment to the deferred tax asset 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. Foreign Currency Translation The financial statements of our subsidiaries outside the U.S., except those for which we have determined that the U.S. dollar is the functional currency, are measured using the local currency as the functional currency. Assets and liabilities of these subsidiaries are translated at the exchange rates in effect at the balance sheet date. Income and expense items are translated at average monthly exchange rates. The resulting gains and losses from the translation of accounts into U.S. dollars are included in accumulated other comprehensive income in our balance sheets. For all subsidiaries, gains and losses from remeasuring foreign currency accounts into the functional currency are included in other (income) expense, net, in our statements of operations. We recorded foreign currency losses of $8.5 million and $0.7 million and foreign currency gains of $6.5 million during the years ended December 31, 2018, 2017 and 2016, respectively. Included in our foreign currency gains and losses were non-cash losses of $5.2 million and non-cash gains of $0.5 million and $9.3 million during the years ended December 31, 2018, 2017 and 2016, respectively, from foreign currency exchange rate changes recorded on intercompany obligations. During the second quarter of 2016, we entered into forward currency exchange contracts with a total notional value of $11.3 million that expired over varying dates through October 31, 2016. We entered into these foreign currency derivatives to offset exchange rate exposure related to intercompany loans to a subsidiary whose functional currency is the Brazilian Real. We did not designate these forward currency exchange contracts as hedge transactions. Changes in fair value and gains and losses on settlement on these forward currency exchange contracts were recognized in other (income) expense, net, in our statements of operations. During the year ended December 31, 2016, we recognized a loss of $0.7 million on forward currency exchange contracts. All of the forward currency exchange contracts that we entered into were settled prior to December 31, 2016. Recent Accounting Pronouncements We consider the applicability and impact of all Accounting Standard Updates (“ASUs”). ASUs not listed below were assessed and determined to be not applicable. Recently Adopted Accounting Pronouncements In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 (“Topic 606”) outlines a single comprehensive model for companies to use in accounting for revenue arising from contracts with customers and supersedes the most current revenue recognition guidance, including industry-specific guidance. The core principle of the guidance is that an entity should recognize revenue when promised goods or services are transferred to customers in an amount that reflects the consideration to which the entity expects to be entitled for those goods or services. The update also requires disclosures enabling users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. On January 1, 2018, we adopted this update using the modified retrospective approach to all contracts that were not completed as of January 1, 2018. As a result of this adoption, we recorded a net increase to the accumulated deficit of $10.0 million as of January 1, 2018 and an increase of $3.7 million in revenue for the year ended December 31, 2018. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. See Note 3 for the required disclosures related to the impact of adopting this standard and a discussion of our updated policies related to revenue recognition. F-11 As a result of applying the modified retrospective method to adopt the new revenue guidance, the following adjustments were made to the balance sheet as of January 1, 2018 (in thousands): Impact of Changes in Accounting Policies December 31, 2017 Adjustments January 1, 2018 ASSETS Current assets: Cash and cash equivalents Restricted cash Accounts receivable, net of allowance Inventory, net Costs and estimated earnings in excess of billings on uncompleted contracts Contract assets Other current assets Current assets held for sale Current assets associated with discontinued operations Total current assets Property, plant and equipment, net Deferred income taxes Intangible and other assets, net Long-term assets held for sale Long-term assets associated with discontinued operations Total assets LIABILITIES AND STOCKHOLDERS’ EQUITY Current liabilities: Accounts payable, trade Accrued liabilities Deferred revenue Billings on uncompleted contracts in excess of costs and estimated earnings Contract liabilities Current liabilities associated with discontinued operations $ $ Total current liabilities Long-term debt Deferred income taxes Long-term deferred revenue Long-term contract liabilities Other long-term liabilities Long-term liabilities associated with discontinued operations Total liabilities Stockholders’ equity: Preferred stock Common stock Additional paid-in capital Accumulated deficit Treasury stock Accumulated other comprehensive income Total stockholders’ equity Total liabilities and stockholders’ equity $ 49,145 $ — $ — 546 266,052 107,909 40,695 — 38,707 15,761 23,751 542,566 822,279 10,550 76,980 4,732 3,700 1,460,807 $ (4,801) (124) (40,695) 50,824 (179) — — 5,025 (2,029) 404 18,273 — — 21,673 49,145 546 261,251 107,785 — 50,824 38,528 15,761 23,751 547,591 820,250 10,954 95,253 4,732 3,700 1,482,480 $ 148,744 $ — $ 114,336 23,902 89,565 — 31,971 408,518 368,472 9,746 92,485 — 20,272 6,528 906,021 — 362 739,164 (223,510) (6,937) 45,707 16,044 (23,902) (89,565) 112,244 — 14,821 — (1,908) (92,485) 89,004 22,262 — 31,694 — — — (10,021) — — 148,744 130,380 — — 112,244 31,971 423,339 368,472 7,838 — 89,004 42,534 6,528 937,715 — 362 739,164 (233,531) (6,937) 45,707 554,786 1,460,807 $ (10,021) 21,673 $ 544,765 1,482,480 $ F-12 In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230). The update addresses eight specific cash flow issues and is intended to reduce diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. On January 1, 2018, we adopted this update. The adoption of this update did not have an impact on our statements of cash flows. In October 2016, the FASB issued ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory. The update requires a reporting entity to recognize the tax expense from intra-entity asset transfers of assets other than inventory in the selling entity’s tax jurisdiction when the transfer occurs, even though the pre-tax effects of that transaction are eliminated in consolidation. Any deferred tax asset that arises in the buying entity’s jurisdiction would also be recognized at the time of the transfer. On January 1, 2018, we adopted this update using a modified retrospective approach. The impact of this adoption was immaterial to our financial statements. In November 2016, the FASB issued ASU 2016-18, Restricted Cash. The guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents and amounts generally described as restricted cash or restricted cash equivalents. On January 1, 2018, we adopted this update retrospectively. As a result of this adoption, $0.5 million and $0.7 million of restricted cash has been included in the cash and cash equivalent balances in the statements of cash flows for the years ended December 31, 2017 and 2016, respectively. At December 31, 2016, the $36.3 million of cash, cash equivalents and restricted cash on our statement of cash flow was composed of $35.7 million of cash and cash equivalent and $0.7 million of restricted cash. At December 31, 2017, the $49.7 million of cash, cash equivalents and restricted cash on our statement of cash flows was composed of $49.1 million of cash and cash equivalents and $0.5 million of restricted cash. At December 31, 2018, the $19.5 million of cash, cash equivalents and restricted cash on our statement of cash flows was composed of $19.3 million of cash and cash equivalents and $0.2 million of restricted cash. The impact of this adoption was immaterial to our financial statements. In May 2017, the FASB issued ASU 2017-09, Compensation—Stock Compensation (Topic 718). This update provides guidance that clarifies that changes to the terms or conditions of a share-based payment award should be accounted for as modifications. On January 1, 2018, we adopted this update using a prospective approach. The impact of this adoption was immaterial to our financial statements. Recently Issued Accounting Pronouncements Not Yet Adopted In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842). The update requires lessees to recognize assets and liabilities on the balance sheet for the rights and obligations created by long-term leases. Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition in the statements of operations. The update also requires certain qualitative and quantitative disclosures about the amount, timing and uncertainty of cash flows arising from leases. Lessor accounting will be similar to the current model except for changes made to align with certain changes to the lessee model and the new revenue recognition standard. In July 2018, the FASB issued additional updates to provide clarification on the lease standard and to give entities another option for transition and to provide lessors with a practical expedient to reduce the cost and complexity of implementing the new standard. The new transition option allows entities to not apply the new leases standard in the comparative periods they present in their financial statements in the year of adoption. We intend to adopt the new lease guidance on January 1, 2019, using the transition method that allows us to initially apply Topic 842 as of January 1, 2019 and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. Additionally, we expect to elect most of the standard’s available practical expedients upon adoption, including the package of practical expedients that allows us to not reassess expired or existing contracts for: (1) embedded leases, (2) lease classification and (3) initial direct costs. For existing contracts that do not require reassessment due to the practical expedient package we have elected, those contracts will continue to be recognized in our financial statements according to our accounting policies in place at December 31, 2018. New contracts entered into or any contract in existence at December 31, 2018 modified on or after January 1, 2019 will be assessed in accordance with Topic 842 and Topic 606, as applicable. In preparation for our adoption of the new standard, we are analyzing and updating data previously collected to evaluate the impact the adoption will have on our financial statements and implementing a system to capture the increased reporting and disclosure requirements. Currently, we tentatively estimate that, as a lessee, our assets and liabilities will increase by no more than $30 million upon adoption of the new lease guidance. Based upon the transition method and practical expedients we have elected, we do not believe the adoption of this standard will have a material effect on our statements of operations and cash flows. F-13 In June 2016, the FASB issued ASU 2016-13, Financial Instruments—Credit Losses (Topic 326). The update changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, held-to- maturity debt securities and loans, and requires entities to use a new forward-looking expected loss model that will result in the earlier recognition of allowance for losses. This update is effective for annual and interim periods beginning after December 15, 2019, with early adoption permitted. Adoption will require a modified retrospective approach beginning with the earliest period presented. We are currently evaluating the potential impact of the update on our financial statements. In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement. The update modifies the disclosure requirements on fair value measurements by removing, modifying and adding certain disclosure requirements. This update is effective for annual and interim periods beginning after December 15, 2019. Early adoption is permitted for any removed or modified disclosures upon issuance of the guidance and delayed adoption of the additional required disclosures is permitted until the effective date. Adoption will require a prospective or retrospective approach based on the specific amendments. We are currently evaluating the potential impact of the update on our financial statements. Note 3. Revenue On January 1, 2018, we adopted Topic 606 applying the modified retrospective method to all contracts that were not completed as of the date of adoption. For contracts that were modified before the effective date, we reflected the aggregate effect of all modifications when identifying performance obligations and allocating transaction price in accordance with a Topic 606 practical expedient. Results for reporting periods beginning after January 1, 2018 are presented under Topic 606, while prior period amounts have not been adjusted and continue to be reported under the accounting standards in effect for the prior period. We recorded a net increase to accumulated deficit of $10.0 million as of January 1, 2018 due to the cumulative impact of adopting Topic 606. Revenues for the year ended December 31, 2018 increased by $3.7 million as a result of adopting Topic 606. Disaggregation of Revenue The following tables present disaggregated revenue by products and services lines and by geographical regions for the year ended December 31, 2018 (in thousands): Revenue by Products and Services Contract Operations Segment: Contract operations services (1) Aftermarket Services Segment: Operation and maintenance services (1) Part sales (2) Other services (1) Total aftermarket services Product Sales Segment: Compression equipment (1) Processing and treating equipment (1) Production equipment (2) Other product sales (1) (2) Total product sales revenues Total revenues (1) (2) Revenue recognized over time. Revenue recognized at a point in time. F-14 Year Ended December 31, 2018 $ $ $ $ $ $ 360,973 57,123 43,928 19,625 120,676 476,480 368,137 18,932 15,658 879,207 1,360,856 Revenue by Geographical Regions North America Latin America Middle East and Africa Asia Pacific Total revenues Year Ended December 31, 2018 $ $ 858,934 274,414 163,093 64,415 1,360,856 The North America region is primarily comprised of our operations in Mexico and the U.S. The Latin America region is primarily comprised of our operations in Argentina, Bolivia and Brazil. The Middle East and Africa region is primarily comprised of our operations in Bahrain, Iraq, Oman, Nigeria and the United Arab Emirates. The Asia Pacific region is primarily comprised of our operations in China, Indonesia, Thailand and Singapore. Revenue is recognized when control of the promised goods or services are transferred to our customers, in an amount that reflects the consideration that we expect to receive in exchange for those goods or services. The following is a description of principal activities from which we generate revenue. Contract Operations Segment In our contract operations segment, we provide compression and processing and treating services through the operation of our natural gas compression equipment and crude oil and natural gas production and process equipment for our customers. Our services include the provision of personnel, equipment, tools, materials and supplies to meet our customers’ natural gas compression and oil and natural gas production and processing service needs. Activities we may perform in meeting our customers’ needs include engineering, designing, sourcing, constructing, installing, operating, servicing, repairing, maintaining and demobilizing equipment owned by us necessary to provide these services. Contract operations services represent a series of distinct monthly services that are substantially the same, with the same pattern of transfer to the customer. Because our customers benefit equally throughout the service period and our efforts in providing contract operations services are incurred relatively evenly over the period of performance, revenue is recognized over time using a time based measure as we provide our services to the customer. Our contracts generally require customers to pay a monthly service fee, which may contain variable consideration such as production or volume based fees, guaranteed run rates, performance bonuses or penalties, liquidated damages and standby fees. Variable considerations included in our contracts are typically resolved on a monthly basis, and as such, variable considerations included in our contracts are generally allocated to each distinct month in the series within the contract. In addition, our contracts may include billings prior to or after the performance of our contract operations services that are not considered distinct within the context of our contracts, such as mobilization and demobilization revenue. Consideration that does not relate to a distinct good or service are allocated to the contract operations services performance obligation and recognized as revenue on a straight-line basis over the contract term. We generally enter into contracts with our contract operations customers with initial terms ranging between three to 12 years. In many instances, we are able to renew those contracts prior to the expiration of the initial term and in other instances, we may sell the underlying assets to our customers pursuant to purchase options or negotiated sale agreements. As of December 31, 2018, we had contract operations services contracts with unsatisfied performance obligations (commonly referred to as backlog) extending through the year 2029. The total aggregate transaction price allocated to the unsatisfied performance obligations as of December 31, 2018 was approximately $1.4 billion, of which approximately $292 million is expected to be recognized in 2019, $197 million is expected to be recognized in 2020, $203 million is expected to be recognized in 2021, $165 million is expected to be recognized in 2022 and $148 million is expected to be recognized in 2023. These amounts do not include anticipated contract renewals. Additionally, contracts that currently contain month-to-month terms are represented in our backlog as one month of unsatisfied performance obligations. Our contracts are subject to cancellation or modification at the election of the customer; however, due to the level of capital deployed by our customers on underlying projects, we have not been materially adversely affected by contract cancellations or modifications in the past. At December 31, 2018, three contracts, each of which were signed in 2018 and in aggregate represent approximately 10% of the total value of our backlog, are accounted for as operating leases. For these contracts, revenues are recognized on a straight line basis and represent approximately 18% of total backlog expected to be recognized in 2019 and thereafter represent no more than 14% for each subsequent periods. Revenues recognized during the year ended December 31, 2018 and assets assigned to these contracts at December 31, 2018 were not material to our statements of operation and balance sheets, respectively. F-15 Aftermarket Services Segment In our aftermarket services business, we sell parts and components and provide operations, maintenance, repair, overhaul, upgrade, startup and commissioning and reconfiguration services to customers who own their own oil and natural gas compression, production, processing, treating and related equipment. Our services range from routine maintenance services and parts sales done on a transactional basis to the full operation and maintenance of customer-owned equipment under long-term agreements. Operations and maintenance services: Operation and maintenance services include personnel to run the equipment and monitor the outputs of the equipment, along with performing preventative or scheduled maintenance on customer-owned equipment. Operation and maintenance services represent a series of distinct monthly services that are substantially the same, with the same pattern of transfer to the customer. Because our customers benefit equally throughout the service period and our efforts in providing operation and maintenance services are incurred relatively evenly over the period of performance, revenue is recognized over time using a time based measure as we provide our services to the customer. Our contracts generally require customers to pay a monthly service fee, which may contain variable consideration such as production or volume based fees and performance bonuses or penalties. Variable considerations included in our contracts are typically resolved on a monthly basis, and as such, variable considerations included in our contracts are generally allocated to each distinct month in the series within the contract. We generally enter into contracts with our operation and maintenance customers with initial terms ranging between one to four years, and in some cases, in excess of five years. In many instances, we are able to renew those contracts prior to the expiration of the initial term. Parts sales: We offer our customers a full range of parts needed for the maintenance, repair and overhaul of oil and natural gas equipment, including natural gas compressors, industrial engines and production and processing equipment. We recognize revenue from parts sales at a point in time following the transfer of control of such parts to the customer, which typically occurs upon shipment or delivery depending on the terms of the underlying contract. Our contracts require customers to pay a fixed fee upon shipment or delivery of the parts. Other services: Within our aftermarket services segment we also provide a wide variety of other services such as overhaul, commissioning, upgrade and reconfiguration services on customer-owned equipment. Overhaul services provided to customers are intended to return the major components to a “like new” condition without significantly modifying the applications for which the units were designed. Commissioning services that we provide to our customers generally include supervision and the introduction of fluids or gases into the systems to test vibrations, pressures and temperatures to ensure that customer-owned equipment is operating properly and is ready for start-up. Upgrade and reconfiguration services modify the operating parameters of customer-owned equipment such that the equipment can be used in applications for which it previously was not suited. Generally, the wide array of other services provided within the aftermarket services segment are expected to be completed within a six month period. Individually these services are generally distinct within the context of the contract and are not highly interdependent or interrelated with other service offerings. We recognize revenue from these services over time based on the proportion of labor hours expended to the total labor hours expected to complete the contract performance obligation. Our contracts generally require customers to pay a service fee that is either fixed or on a time and materials basis, which may include progress billings. Our aftermarket services contracts are subject to cancellation or modification at the election of the customer. Product Sales Segment In our product sales segment, we design, engineer, manufacture, install and sell natural gas compression packages as well as equipment used in the treating and processing of crude oil and natural gas primarily to major and independent oil and natural gas producers as well as national oil and natural gas companies around the world. Compression equipment: We design, engineer, manufacture and sell skid-mounted natural gas compression equipment to meet standard or unique customer specifications. We recognize revenue from the sale of compression equipment over time based on the proportion of labor hours expended to the total labor hours expected to complete the contract performance obligation. Compression equipment manufactured for our customers are specifically designed and engineered to our customers’ specification and do not have an alternative use to us. Our contracts include a fixed fee and require our customers to make progress payments based on completion of contractual milestones during the life cycle of the manufacturing process. Our contracts provide us with an enforceable right to payment for work performed to date. Components of variable considerations exist in certain of our contracts and may include unpriced change orders, liquidated damages and performance bonuses or penalties. Typically, we expect the manufacturing of our compressor equipment to be completed within a three to 12 month period. F-16 Processing and treating equipment: Processing and treating equipment sold to our customers consists of custom-engineered processing and treating plants, such as refrigeration, amine, cryogenic and natural gas processing plants. The manufacturing of processing and treating equipment generally represents a single performance obligation within the context of the contract. We recognize revenue from the sale of processing and treating equipment over time based on the proportion of labor hours expended to the total labor hours expected to complete the contract performance obligation. Processing and treating equipment manufactured for our customers are specifically designed and engineered to our customers’ specification and do not have an alternative use to us. Our contracts include a fixed fee and require our customers to make progress payments based on our completion of contractual milestones during the life cycle of the manufacturing process. Our contracts provide us with an enforceable right to payment for work performed to date. Components of variable considerations exist in certain of our contracts and may include unpriced change orders, liquidated damages and performance bonuses or penalties. Typically, we expect the manufacturing of our processing and treating equipment to be completed within a six to 24 month period. Production equipment: In June 2018, we completed the sale of our North America production equipment assets (“PEQ assets”), which included $12.0 million in unsatisfied performance obligations. See Note 8 for further details on the sale of our PEQ assets. In North America, we previously manufactured standard production equipment used for processing wellhead production from onshore or shallow-water offshore platform production. The manufacturing of production equipment generally represented a single performance obligation within the context of the contract. We recognized revenue from the sale of production equipment at a point in time following the transfer of control of the equipment to the customer, which typically occurred upon completion of the manufactured equipment, depending on the terms of the underlying contract. Our contracts generally required customers to pay a fixed fee upon completion. Other product sales: Within our product sales segment we also provide for the sale of standard and custom water treatment equipment and floating production storage and offloading equipment and supervisor site work services. We recognize revenue from the sale of standard water treatment equipment at a point in time following the transfer of control of such equipment to the customer, which typically occurs upon shipment or delivery depending on the terms of the underlying contract. We recognize revenue from the sale of custom water treatment equipment over time based on the proportion of costs expended to the total costs expected to complete the contract performance obligation. We recognize revenue from the sale of floating production storage and offloading equipment and supervisor site work services over time based on the proportion of labor costs expended to the total labor costs expected to complete the contract performance obligation. Product sales contracts that include engineering, design, project management, procurement, construction and installation services necessary to incorporate our products into production, processing and compression facilities are treated as a single performance obligation due to the services that significantly integrate each piece of equipment into the combined output contracted by the customer. We provide assurance-type warranties on certain equipment in our product sales contracts. These warranties generally do not constitute a separate performance obligation. Product warranty reserves are established in the same period that revenue from the sale of the related products is recognized, or in the period that a specific issue arises as to the functionality of a product. The determination of such reserves requires that we make estimates of expected costs to repair or to replace the products under warranty. The amounts of the reserves are based on established terms and our best estimate of the amounts necessary to settle future and existing claims on product sales as of the balance sheet date. If actual repair and replacement costs differ significantly from estimates, adjustments to recognize additional cost of sales may be required in future periods. As of December 31, 2018, the total aggregate transaction price allocated to the unsatisfied performance obligations for product sales contracts was approximately $706 million, of which approximately $690 million is expected to be recognized in 2019 and approximately $16 million is expected to be recognized in 2020. Our contracts are subject to cancellation or modification at the election of the customer; however, due to our enforceable right to payment for work performed, we have not been materially adversely affected by contract cancellations or modifications in the past. F-17 Significant Estimates The recognition of revenue over time based on the proportion of labor hours expended to the total labor hours expected to complete depends largely on our ability to make reasonable dependable estimates related to the extent of progress toward completion of the contract, contract revenues and contract costs. Recognized revenues and profits are subject to revisions as the contract progresses to completion. Revisions in profit estimates are charged to income in the period in which the facts that give rise to the revision become known using the cumulative catch-up method. Due to the nature of some of our contracts, developing the estimates of costs often requires significant judgment. To calculate the proportion of labor hours expended to the total labor hours expected to complete the contract performance obligation, management uses significant judgment to estimate the number of total hours and profit expected for each project. Variable Consideration The nature of our contracts gives rise to several types of variable consideration. We estimate variable consideration at the most likely amount to which we expect to be entitled. We include estimated amounts in the transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved. Additionally, we include in our contract estimates additional revenue for unapproved change orders or claims against customers when we believe we have an enforceable right to the modification or claim, the amount can be estimated reliably and its realization is probable. Our estimates of variable consideration and determination of whether to include estimated amounts in the transaction price are based largely on an assessment of our anticipated performance and historical, current and forecasted information that is reasonably available to us. Contracts with Multiple Performance Obligations Some of our contracts have multiple performance obligations. For instance, some of our product sales contracts include commissioning services or the supply of spare parts. For contracts with multiple performance obligations, we allocate the contract’s transaction price to each performance obligation using our best estimate of the standalone selling price of each distinct good or service in the contract. The primary method used to estimate standalone selling price is the expected cost plus a margin approach, under which we forecast our expected costs of satisfying a performance obligation and then add an appropriate margin for that distinct good or service. Contract Assets and Contract Liabilities The following table provides information about accounts receivables, net, contract assets and contract liabilities from contracts with customers (in thousands): Accounts receivables, net Contract assets and contract liabilities: Current contract assets Long-term contract assets Current contract liabilities Long-term contract liabilities As of December 31, 2018 248,467 $ As of January 1, 2018 $ 261,251 91,602 5,430 153,483 101,363 50,824 11,835 112,244 89,004 Accounts receivables are recorded when the right to consideration becomes unconditional. Our contract assets include amounts related to revenue that has been recognized in advance of billing the customer. The contract assets in our balance sheets include costs in excess of billings and unbilled receivables. When we receive consideration, or such consideration is unconditionally due from a customer prior to transferring goods or services to the customer under the terms of the contract, we record a contract liability. Our contract liabilities include payments received in advance of performance under the contract. The contract liabilities in our balance sheets include billings in excess of costs and deferred revenue. Billings in excess of costs primarily relate to billings that have not been recognized as revenue on product sales jobs where the transfer of control to the customer occurs over time. Deferred revenue is primarily comprised of upfront billings on contract operations jobs and billings related to product sales jobs that have not begun where revenue is recognized over time. Upfront payments received from customers on contract operations jobs are generally deferred and amortized over the contract term as we perform our services and the customer receives and consumes the benefits of the services we provide. Contract assets and liabilities are reported in our balance sheets on a net contract asset or liability position on a contract-by-contract basis at the end of each reporting period. F-18 During the year ended December 31, 2018, revenue recognized from contract operations services included $20.3 million of revenue deferred in previous periods. Revenue recognized during the year ended December 31, 2018 from product sales performance obligations partially satisfied in previous periods was $423.5 million, of which $84.3 million was included in billings in excess of costs at the beginning of the period. Additionally, during the year ended December 31, 2018, we recognized $4.3 million in revenue from contract operations services performance obligations that were satisfied in a previous period. The increases in current contract assets and current contract liabilities during the year ended December 31, 2018 were primarily driven by progression of product sales projects and the timing of milestone billings. Costs to Fulfill a Contract We capitalize costs incurred to fulfill our revenue contracts that (i) relate directly to the contract (ii) are expected to generate resources that will be used to satisfy the performance obligation under the contract and (iii) are expected to be recovered through revenue generated under the contract. As of December 31, 2018, we had capitalized fulfillment costs of $6.6 million related to contractual obligations incurred at the completion of the commissioning phase and prior to providing services on contracts within our contract operations segment. Contract fulfillment costs are expensed to cost of sales as we satisfy our performance obligations by transferring contract operations services to the customer. Capitalized fulfillment costs are included in intangible and other assets, net, in the balance sheets. Costs to Obtain a Contract We recognize an asset for the incremental costs of obtaining a contract with a customer if we expect the benefit of those costs to be longer than one year. We have determined that certain commissions paid to internal sales representatives and third party agents meet the requirements to be capitalized. The amount capitalized for incremental costs to obtain contracts as of December 31, 2018 was $6.7 million. The judgments made in determining the amount of costs incurred include whether the commissions are in fact incremental and would not have occurred absent the customer contract. Capitalized costs to obtain a contract are included in intangible and other assets, net, in the balance sheets and are amortized to selling, general and administrative expense over the expected period of benefit in a manner that is consistent with the transfer of the related goods or services to which the asset relates. During the year ended December 31, 2018, we recorded amortization expense for capitalized costs to obtain a contract of $1.4 million. Practical Expedients and Exemptions We have elected the following practical expedients: • We do not adjust the promised amount of consideration for the effects of a significant financing component when we expect, at contract inception, that the period between our transfer of a promised product or service to a customer and when the customer pays for that product or service will be one year or less. • We treat shipping and handling activities that occur after the transfer of control as costs to fulfill a contract rather than a separate performance obligation. • We record taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction and collected by us from our customers on a net basis, and thus, such taxes are excluded from the measurement of a performance obligation’s transaction price. • We expense sales commissions as incurred when we expect that the amortization period of such costs will be one year or less. F-19 Impact of New Revenue Recognition Guidance on Financial Statement Line Items The following tables summarize the impacts of the adoption of the new revenue recognition guidance on our balance sheet, statement of operations and statement of cash flows as of and for the year ended December 31, 2018 (in thousands): ASSETS Inventory, net Contract assets Other current assets Property, plant and equipment, net Deferred income taxes Intangible and other assets, net Total assets LIABILITIES AND STOCKHOLDERS’ EQUITY Accrued liabilities Contract liabilities Deferred income taxes Long-term contract liabilities Other long-term liabilities Total liabilities Accumulated deficit Total stockholders’ equity Total liabilities and stockholders’ equity December 31, 2018 As Reported Adjustments Balances Without Adoption of Topic 606 $ $ $ $ 150,689 91,602 44,234 901,577 11,370 86,371 1,567,054 123,335 153,483 6,005 101,363 39,812 1,014,233 (208,677) 552,821 1,567,054 $ $ 1,303 (20,114) 14,432 1,855 (972) (17,448) (20,944) (14,273) 2,347 (32) 3,512 (14,902) (23,348) 2,404 2,404 (20,944) 151,992 71,488 58,666 903,432 10,398 68,923 1,546,110 109,062 155,830 5,973 104,875 24,910 990,885 (206,273) 555,225 1,546,110 The adoption of the new revenue recognition guidance resulted in increases in total assets and liabilities of $20.9 million and $23.3 million, respectively. This was primarily due to capitalized contract fulfillment and obtainment costs and related liabilities recorded associated with contracts within our contract operations segment. F-20 Revenues: Contract operations Aftermarket services Cost of sales (excluding depreciation and amortization expense): Contract operations Aftermarket services Selling, general and administrative Depreciation and amortization Income before income taxes Provision for income taxes Income (loss) from continuing operations Net income Basic net income per common share Diluted net income per common share Year Ended December 31, 2018 As Reported Adjustments Balances Without Adoption of Topic 606 $ $ 360,973 $ 120,676 (2,079) $ (1,662) 122,138 89,666 178,401 123,922 39,825 39,433 392 24,854 2,344 (1,278) 6,739 (2,468) (9,078) (1,461) (7,617) (7,617) $ 0.68 0.68 (0.19) $ (0.19) 358,894 119,014 124,482 88,388 185,140 121,454 30,747 37,972 (7,225) 17,237 0.49 0.49 The adoption of the new revenue recognition guidance resulted in an increase in net income of $7.6 million for the year ended December 31, 2018. Most notably, costs to obtain a contract during the year ended December 31, 2018 would have resulted in an increase in selling, general and administrative expense under previous accounting standards. Cash flows from operating activities: Net income Depreciation and amortization Deferred income tax provision Changes in assets and liabilities: Inventory Contract assets Other current assets Accounts payable and other liabilities Contract liabilities Other Net cash provided by continuing operations Year Ended December 31, 2018 As Reported Adjustments Balances Without Adoption of Topic 606 $ 24,854 $ (7,617) $ 123,922 1,537 (59,676) (34,571) 5,045 13,801 62,934 3,059 153,296 (2,468) (1,461) (1,179) 2,477 (951) 9,894 1,414 (109) — 17,237 121,454 76 (60,855) (32,094) 4,094 23,695 64,348 2,950 153,296 The adoption of the new revenue recognition guidance resulted in offsetting shifts in cash flows within cash flows from operating activities and did not have an impact on our total cash flows from operations. Note 4. Discontinued Operations In June 2009, Petroleos de Venezuela S.A. (“PDVSA”) commenced taking possession of our assets and operations in a number of our locations in Venezuela, and by the end of the second quarter of 2009, PDVSA had assumed control over substantially all of our assets and operations in Venezuela. In March 2010, our Spanish subsidiary filed a request for the institution of an arbitration proceeding against Venezuela with the International Centre for Settlement of Investment Disputes (“ICSID”) related to the seized assets and investments under the agreement between Spain and Venezuela for the Reciprocal Promotion and Protection of Investments and under Venezuelan law. The arbitration hearing occurred in July 2012. F-21 In August 2012, our Venezuelan subsidiary sold its previously nationalized assets to PDVSA Gas, S.A. (“PDVSA Gas”) for a purchase price of approximately $441.7 million. We received an initial payment of $176.7 million in cash at closing, of which we remitted $50.0 million to repay the amount we collected in January 2010 under the terms of an insurance policy we maintained for the risk of expropriation. We received installment payments, including an annual charge, totaling $19.8 million, $19.7 million and $38.8 million during the years ended December 31, 2018, 2017 and 2016, respectively. As of December 31, 2018, we have received all payments from PDVSA Gas. We recognized payments received as income from discontinued operations in the periods such payments were received. The proceeds from the sale of the assets were not subject to Venezuelan national taxes due to an exemption allowed under the Venezuelan Reserve Law applicable to expropriation settlements. In accordance with the separation and distribution agreement from the Spin-off, a subsidiary of Archrock has the right to receive payments from our wholly owned subsidiary, Exterran Energy Solutions, L.P. (“EESLP”), based on a notional amount corresponding to payments received by our subsidiaries from PDVSA Gas in respect of the sale of our previously nationalized assets promptly after such amounts are collected by our subsidiaries. Pursuant to the separation and distribution agreement, we transferred cash of $18.7 million, $19.7 million and $38.8 million to Archrock during the years ended December 31, 2018, 2017 and 2016, respectively. The transfers of cash were recognized as reductions to additional paid-in capital in our financial statements. In the first quarter of 2016, we began executing a plan to exit certain Belleli businesses to focus on our core businesses. Specifically, we began marketing for sale the Belleli CPE business comprised of engineering, procurement and manufacturing services related to the manufacture of critical process equipment for refinery and petrochemical facilities (referred to as “Belleli CPE” or the “Belleli CPE business” herein). Belleli CPE met the held for sale criteria and is reflected as discontinued operations in our financial statements for all periods presented. In August 2016, we completed the sale of our Belleli CPE business to Tosto S.r.l. for cash proceeds of $5.5 million. Belleli CPE was previously included in our product sales segment. In conjunction with the planned disposition of Belleli CPE, we recorded impairments of long-lived assets and current assets that totaled $68.8 million during the year ended December 31, 2016. The impairment charges are reflected in income (loss) from discontinued operations, net of tax. In addition, in the first quarter of 2016, we began executing the exit of our Belleli EPC business that has historically been comprised of engineering, procurement and construction for the manufacture of tanks for tank farms and the manufacture of evaporators and brine heaters for desalination plants in the Middle East (referred to as “Belleli EPC” or the “Belleli EPC business” herein) by ceasing the bookings of new orders. As of the fourth quarter of 2017, we had substantially exited our Belleli EPC business and, in accordance with GAAP, it is reflected as discontinued operations in our financial statements for all periods presented. Although we have reached mechanical completion on all remaining Belleli EPC contracts, we are still subject to risks and uncertainties potentially resulting from warranty obligations, customer or suppliers claims against us, settlement of claims against customers, completion of demobilization activities and litigation developments. The facility previously utilized to manufacture products for our Belleli EPC business has been repurposed to manufacture product sales equipment. As such, certain personnel, buildings, equipment and other assets that were previously related to our Belleli EPC business remain a part of our continuing operations. As a result, activities associated with our ongoing operations at our repurposed facility are included in continuing operations. The following table summarizes the operating results of discontinued operations (in thousands): Revenue $ — $ 16,274 $ 16,274 $ — $ 72,693 $ 72,693 $ — $ 123,856 $ 28,469 $ 152,325 2018 2017 2016 Venezuela Belleli EPC Total Venezuela Belleli EPC Total Venezuela Belleli EPC Belleli CPE Total Years Ended December 31, Cost of sales (excluding depreciation and amortization expense) Selling, general and administrative Depreciation and amortization Long-lived asset impairment — 131 — — Recovery attributable to expropriation (16,564) Restructuring related charges (recoveries), net Interest expense Other (income) expense, net Provision for income taxes Income (loss) from discontinued operations, net of tax — — (3,249) — 10,271 1,652 480 — — — — 10,271 1,783 480 — — 131 — — (16,564) (16,514) — — — — (1,342) 433 (4,591) (3,157) 433 — 41,329 5,262 5,653 — — (439) — 539 153 41,329 5,393 5,653 — — 54 — — (16,514) (33,124) (439) — (2,618) 153 — — (5,966) — 126,322 27,323 153,645 8,500 5,088 651 — 5,419 — (42) 518 1,494 861 68,780 10,048 5,949 69,431 — (33,124) 2,735 17 (191) 57 8,154 17 (6,199) 575 $ 19,682 $ 4,780 $ 24,462 $ 19,540 $ 20,196 $ 39,736 $ 39,036 $ (22,600) $ (72,607) $ (56,171) F-22 The following table summarizes the balance sheet data for discontinued operations (in thousands): December 31, 2018 December 31, 2017 Venezuela Belleli EPC Total Venezuela Belleli EPC Total $ $ $ Cash Accounts receivable Costs and estimated earnings in excess of billings on uncompleted contracts Other current assets Total current assets associated with discontinued operations Property, plant and equipment, net Intangible and other assets, net Total assets associated with discontinued operations Accounts payable Accrued liabilities Billings on uncompleted contracts in excess of costs and estimated earnings Total current liabilities associated with discontinued operations Other long-term liabilities Total liabilities associated with discontinued operations Note 5. Inventory, Net $ — $ 3 $ 11,509 11,509 3 — — 7 10 — — — 86 11,595 28 1,633 $ $ 10 $ 13,256 — $ 12 — 12 — 4,382 7,831 2,542 14,755 5,914 — 93 11,605 28 1,633 13,266 4,382 7,843 2,542 14,767 5,914 $ $ 3 14,770 7,786 1,192 23,751 1,054 2,646 27,451 9,253 15,676 3 — — 2 5 — — $ — $ 14,770 7,786 1,190 23,746 1,054 2,646 5 $ 27,446 $ $ 9,253 15,617 — $ 59 — 59 1 7,042 7,042 31,912 6,527 31,971 6,528 $ 12 $ 20,669 $ 20,681 $ 60 $ 38,439 $ 38,499 Inventory, net of reserves, consisted of the following amounts (in thousands): Parts and supplies Work in progress Finished goods Inventory, net December 31, 2018 2017 $ $ 92,016 $ 49,547 9,126 79,803 21,853 6,253 150,689 $ 107,909 During the years ended December 31, 2018, 2017 and 2016, we recorded $0.1 million, $1.3 million and $0.8 million, respectively, in inventory write-downs and reserves for obsolete or slow moving inventory. As of December 31, 2018 and 2017, we had inventory reserves of $10.0 million and $10.4 million, respectively. F-23 Note 6. Property, Plant and Equipment, Net Property, plant and equipment, net, consisted of the following (in thousands): Compression equipment, processing facilities and other fleet assets (1) Land and buildings Transportation and shop equipment Computer software Other Accumulated depreciation Property, plant and equipment, net December 31, 2018 1,713,153 101,571 82,960 54,572 47,210 2017 1,577,052 $ 96,463 82,240 50,299 40,096 1,999,466 (1,097,889) 901,577 $ 1,846,150 (1,023,871) 822,279 $ $ (1) In the fourth quarter of 2017, we evaluated the estimated useful lives and salvage values of our property, plant and equipment. As a result of this evaluation, we changed the useful lives and salvage values for our compression equipment from a maximum useful life of 30 years to 23 years and a maximum salvage value of 20% to 15% based on expected future use. During the years ended December 31, 2018 and 2017, we recorded increases in depreciation expense of $8.9 million and $1.2 million, respectively, as a result of these changes in useful lives and salvage values which impacted our diluted net income per share by $0.25 and $0.03, respectively. Depreciation expense was $118.9 million, $105.0 million and $129.2 million during the years ended December 31, 2018, 2017 and 2016, respectively. Assets under construction of $237.7 million and $130.4 million as of December 31, 2018 and 2017, respectively, were primarily related to our contract operations business. During the years ended December 31, 2018, 2017 and 2016, we capitalized $9.9 million, $3.4 million and $0.3 million of interest related to construction in process, respectively. Note 7. Intangible and Other Assets, Net Intangible and other assets, net, consisted of the following (in thousands): Intangible assets, net Deferred financing costs Long-term non-income tax receivable Long-term income tax credits Long-term notes receivable Long-term deposits Long-term contract assets Contract fulfillment costs Contract obtainment costs Other Intangibles and other assets, net December 31, 2018 2017 $ 8,174 $ 7,237 8,621 2,412 20,399 13,492 5,430 6,580 6,739 7,287 $ 86,371 $ 9,861 4,786 14,560 11,344 3,004 11,648 8,500 — — 13,277 76,980 F-24 Intangible assets and deferred financing costs consisted of the following (in thousands): December 31, 2018 December 31, 2017 Gross Carrying Amount Accumulated Amortization Gross Carrying Amount Accumulated Amortization Deferred financing costs (1) Marketing related (20 year life) Customer related (17-20 year life) Technology based (20 year life) Contract based (2-11 year life) $ 13,164 $ 542 75,331 3,153 45,059 Intangible assets and deferred financing costs $ 137,249 $ (5,927) $ (542) (68,423) (3,153) (43,793) (121,838) $ 8,368 $ 629 76,946 3,655 43,953 133,551 $ (3,582) (589) (67,342) (3,438) (43,953) (118,904) (1) Represents debt issuance costs relating to our revolving credit facility. See Note 11 for further discussion regarding our revolving credit facility. Amortization of deferred financing costs related to our revolving credit facility totaled $2.3 million, $1.7 million and $1.6 million during the years ended December 31, 2018, 2017 and 2016, respectively, and was recorded to interest expense in our statements of operations. Amortization of intangible assets totaled $2.4 million, $2.8 million and $3.7 million during the years ended December 31, 2018, 2017 and 2016, respectively. Estimated future intangible amortization expense is as follows (in thousands): 2019 2020 2021 2022 2023 Thereafter Total Note 8. Sale of PEQ Assets $ $ 2,160 1,852 1,494 1,074 899 695 8,174 In the fourth quarter of 2017, we classified certain PEQ assets primarily related to inventory and property, plant and equipment, net, within our product sales business as assets held for sale in our balance sheets. In April 2018, we entered into a definitive agreement for the sale of these assets to Titan Production Equipment Acquisition, LLC, an affiliate of Castle Harlan, Inc. During the years ended December 31, 2018 and 2017, we recorded impairments of $1.8 million and $2.1 million, respectively, to reduce these assets to their approximate fair values based on the expected net proceeds. The impairment charges are reflected in long-lived asset impairment in our statements of operations. In June 2018, we completed the sale of our PEQ assets. The sale of our PEQ assets resulted in a loss of $1.7 million during the year ended December 31, 2018, which is reflected in other (income), expense, net, in our statements of operations. Note 9. Investments in Non-Consolidated Affiliates Investments in affiliates that are not controlled by us where we have the ability to exercise significant influence over the operations are accounted for using the equity method. We own a 30.0% interest in WilPro Energy Services (PIGAP II) Limited and 33.3% interest in WilPro Energy Services (El Furrial) Limited, which are joint ventures that provided natural gas compression and injection services in Venezuela. In May 2009, PDVSA assumed control over the assets of our Venezuelan joint ventures and transitioned the operations, including the hiring of their employees, to PDVSA. In March 2011, our Venezuelan joint ventures, together with the Netherlands’ parent company of our joint venture partners, filed a request for the institution of an arbitration proceeding against Venezuela with ICSID related to the seized assets and investments. F-25 In March 2012, our Venezuelan joint ventures sold their assets to PDVSA Gas. We received an initial payment of $37.6 million in March 2012, and received installment payments, including an annual charge, totaling $10.4 million during the year ended December 31, 2016. As of December 31, 2018, the remaining principal amount due to us was approximately $4 million. We have not recognized amounts payable to us by PDVSA Gas as a receivable and will therefore recognize payments received in the future as equity in income of non-consolidated affiliates in our statements of operations in the periods such payments are received. In connection with the sale of our Venezuelan joint ventures’ assets, the joint ventures and our joint venture partners agreed to suspend their previously filed arbitration proceeding against Venezuela pending payment in full by PDVSA Gas of the purchase price for the assets. The arbitration proceeding has since been dismissed, and the principal amount due to us remains outstanding. In accordance with the separation and distribution agreement, a subsidiary of Archrock has the right to receive payments from EESLP based on a notional amount corresponding to payments received by our subsidiaries from PDVSA Gas in respect of the sale of our joint ventures’ previously nationalized assets promptly after such amounts are collected by our subsidiaries. Pursuant to the separation and distribution agreement, we transferred cash of $10.4 million to Archrock during the year ended December 31, 2016. The transfer of cash was recognized as a reduction to additional paid-in capital in our financial statements. See Note 21 for further discussion related to our contingent liability to Archrock. Note 10. Accrued Liabilities Accrued liabilities consisted of the following (in thousands): Accrued salaries and other benefits Accrued income and other taxes Accrued demobilization costs Accrued warranty expense Accrued interest Accrued other liabilities Accrued liabilities December 31, 2018 2017 $ 46,836 $ 31,862 14,839 2,191 5,778 21,829 53,492 26,503 — 3,190 6,000 25,151 $ 123,335 $ 114,336 Our warranty expense was $1.9 million, $1.9 million and $1.6 million during the years ended December 31, 2018, 2017 and 2016, respectively. F-26 Note 11. Debt Debt consisted of the following (in thousands): Revolving credit facility due October 2023 8.125% senior notes due May 2025 Other debt Unamortized deferred financing costs of 8.125% senior notes Total debt Less: Amounts due within one year (1) Long- term debt December 31, 2018 2017 $ 35,000 $ — 375,000 687 (6,428) 404,259 (449) 403,810 $ 375,000 1,171 (7,250) 368,921 (449) 368,472 $ (1) Short-term debt and the current portion of long-term debt are included in accrued liabilities in our balance sheets. Revolving Credit Facility On July 10, 2015, we and our wholly owned subsidiary, EESLP, entered into a $750.0 million credit agreement (the “Credit Agreement”) with Wells Fargo, as the administrative agent, and various financial institutions as lenders. On October 5, 2015, the parties amended and restated the Credit Agreement to provide for a $925.0 million credit facility, consisting of a $680.0 million revolving credit facility and a $245.0 million term loan facility. In November 2016, we repaid $12.3 million of borrowings outstanding under the term loan facility. In April 2017, we paid the remaining principal amount of $232.8 million due under the term loan facility with proceeds from the 2017 Notes (as defined below) issuance. As a result of the repayment of the term loan facility, we expensed $1.7 million of unamortized deferred financing costs during the year ended December 31, 2017, which is reflected in interest expense in our statements of operations. On October 9, 2018, we and EESLP entered into a Second Amended and Restated Credit Agreement (the “Amended Credit Agreement”), which among other things, increased the borrowing capacity under our revolving credit facility from $680.0 million to $700.0 million. The Amended Credit Agreement also extended the maturity date of our revolving credit facility to October 9, 2023. As a result of the Amended Credit Agreement, we expensed $0.7 million of unamortized deferred financing costs during the year ended December 31, 2018, which is reflected in interest expense in our statements of operations. As of December 31, 2018, we had $35.0 million in outstanding borrowings and $56.7 million in outstanding letters of credit under our revolving credit facility. At December 31, 2018, taking into account guarantees through outstanding letters of credit, we had undrawn capacity of $608.3 million under our revolving credit facility. Our Amended Credit Agreement limits our senior secured leverage ratio (as defined in the Amended Credit Agreement) on the last day of the fiscal quarter to no greater than 2.75 to 1.0. As a result of this limitation, $578.4 million of the $608.3 million of undrawn capacity under our revolving credit facility was available for additional borrowings as of December 31, 2018. Revolving borrowings under the Amended Credit Agreement bear interest at a rate equal to, at our option, either the Base Rate or LIBOR (or EURIBOR, in the case of Euro-denominated borrowings) plus the applicable margin. “Base Rate” means the greatest of (a) the prime rate, (b) the federal funds effective rate plus 0.50% and (c) one-month LIBOR plus 1.00%. The applicable margin for revolving borrowings varies (i) in the case of LIBOR and EURIBOR loans, from 1.75% to 2.75% and (ii) in the case of Base Rate loans, from 0.75% to 1.75%, and in each case will be determined based on a total leverage ratio pricing grid. The weighted average annual interest rate on outstanding borrowings under the revolving credit facility at December 31, 2018 was 4.3%. We guarantee EESLP’s obligations under the revolving credit facility. In addition, EESLP’s obligations under the revolving credit facility are secured by (1) substantially all of our assets and the assets of EESLP and our Significant Domestic Subsidiaries (as defined in the Amended Credit Agreement), including certain real property, and (2) all of the equity interests of our U.S. restricted subsidiaries (other than certain excluded subsidiaries) (as defined in the Amended Credit Agreement) and 65% of the voting equity interests in certain of our first-tier foreign subsidiaries. F-27 8.125% Senior Notes Due May 2025 In April 2017, our 100% owned subsidiaries EESLP and EES Finance Corp. issued $375.0 million aggregate principal amount of 8.125% senior unsecured notes due 2025 (the “2017 Notes”). The 2017 Notes are guaranteed by us on a senior unsecured basis. The net proceeds of $367.1 million from the 2017 Notes issuance were used to repay all of the borrowings outstanding under the term loan facility and revolving credit facility and for general corporate purposes. Additionally, pursuant to the separation and distribution agreement from the Spin-off, EESLP used proceeds from the issuance of the 2017 Notes to pay a subsidiary of Archrock $25.0 million in satisfaction of EESLP’s obligation to pay that sum following the occurrence of a qualified capital raise. The transfer of cash to Archrock’s subsidiary was recognized as a reduction to additional paid-in capital in the second quarter of 2017. Prior to May 1, 2020, we may redeem all or a portion of the 2017 Notes at a redemption price equal to the sum of (i) the principal amount thereof, and (ii) a make-whole premium at the redemption date, plus accrued and unpaid interest, if any, to the redemption date. In addition, we may redeem up to 35% of the aggregate principal amount of the 2017 Notes prior to May 1, 2020 with the net proceeds of one or more equity offerings at a redemption price of 108.125% of the principal amount of the 2017 Notes, plus any accrued and unpaid interest to the date of redemption, if at least 65% of the aggregate principal amount of the 2017 Notes issued under the indenture remains outstanding after such redemption and the redemption occurs within 180 days of the date of the closing of such equity offering. On or after May 1, 2020, we may redeem all or a portion of the 2017 Notes at redemption prices (expressed as percentages of principal amount) equal to 106.094% for the twelve-month period beginning on May 1, 2020, 104.063% for the twelve-month period beginning on May 1, 2021, 102.031% for the twelve-month period beginning on May 1, 2022 and 100.000% for the twelve-month period beginning on May 1, 2023 and at any time thereafter, plus accrued and unpaid interest, if any, to the applicable redemption date of the 2017 Notes. Unamortized Debt Financing Costs In connection with the issuance of the 2017 Notes, we incurred transaction costs of $7.9 million related to the issuance of the 2017 Notes. These costs are presented as a direct deduction from the carrying value of the 2017 Notes and are being amortized over the term of the 2017 Notes. Amortization of deferred financing costs relating to the 2017 Notes totaled $1.0 million and $0.7 million during the years ended December 31, 2018 and 2017, respectively, and was recorded to interest expense in our statements of operations. Amortization of deferred financing costs relating to the term loan facility totaled $2.4 million and $2.9 million during the years ended December 31, 2017 and 2016, respectively, and was recorded to interest expense in our statements of operations. During the year ended December 31, 2018, we incurred transaction costs of approximately $4.8 million related to our revolving credit facility. Debt issuance costs relating to our revolving credit facility are included in intangible and other assets, net, and are being amortized over the term of the facility. See Note 7 for further discussion regarding the amortization of deferred financing costs related to our revolving credit facility. Debt Compliance The Amended Credit Agreement contains various covenants with which we, EESLP and our respective restricted subsidiaries must comply including, but not limited to, limitations on the incurrence of indebtedness, investments, liens on assets, repurchasing equity, distributions, transactions with affiliates, mergers, consolidations, dispositions of assets and other provisions customary in similar types of agreements. We are required to maintain, on a consolidated basis, a minimum interest coverage ratio (as defined in the Amended Credit Agreement) of 2.25 to 1.00; a maximum total leverage ratio (as defined in the Amended Credit Agreement) of 4.50 to 1.00; and a maximum senior secured leverage ratio (as defined in the Amended Credit Agreement) of 2.75 to 1.00. As of December 31, 2018, we were in compliance with all financial covenants under the Amended Credit Agreement. F-28 Debt Maturity Schedule Contractual maturities of debt (excluding interest to be accrued thereon) at December 31, 2018 are as follows (in thousands): 2019 2020 2021 2022 2023 Thereafter Total debt (1) December 31, 2018 449 238 — — 35,000 375,000 410,687 $ $ (1) This amount includes the full face value of the 2017 Notes and does not include unamortized debt financing costs of $6.4 million as of December 31, 2018. Note 12. Fair Value Measurements The accounting standard for fair value measurements and disclosures establishes a fair value hierarchy that prioritizes the inputs to 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. Nonrecurring Fair Value Measurements The following table presents our assets and liabilities measured at fair value on a nonrecurring basis during the years ended December 31, 2018 and 2017, with pricing levels as of the date of valuation (in thousands): Impaired long-lived assets (1) Impaired assets—assets held for sale (2) Long-term note receivable (3) Year Ended December 31, 2018 (Level 1) (Level 2) $ — $ — — — $ — — (Level 3) 550 $ 21,026 14,573 Year Ended December 31, 2017 (Level 1) (Level 2) — $ — — — $ — — (Level 3) 403 20,493 — (1) (2) (3) Our estimate of the fair value of the impaired long-lived assets during the years ended December 31, 2018 and 2017 was primarily based on the expected net sale proceeds compared to other fleet units we sold and/or a review of other units offered for sale by third parties. Our estimate of the fair value of the impaired PEQ assets, which were classified as assets held for sale as of December 31, 2017 and sold in June 2018, was based on the expected and actual net proceeds from the sale of the assets. Our estimate of the fair value of a note receivable was discounted based on a settlement period of eight years and a discount rate of 5.2%. F-29 Financial Instruments Our financial instruments consist of cash, restricted cash, receivables, payables and debt. At December 31, 2018 and 2017, the estimated fair values of cash, restricted cash, receivables and payables approximated their carrying amounts as reflected in our balance sheets due to the short-term nature of these financial instruments. The fair value of the 2017 Notes was estimated based on model derived calculations using market yields observed in active markets, which are Level 2 inputs. As of December 31, 2018 and 2017, the carrying amount of the 2017 Notes, excluding unamortized deferred financing costs, of $375.0 million was estimated to have a fair value of $362.0 million and $404.0 million, respectively. Due to the variable rate nature of our revolving credit facility, the carrying value as of December 31, 2018 approximated the fair value as the rate was comparable to the then-current market rate at which debt with similar terms could have been obtained. Note 13. Long-Lived 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 compressor units from our active fleet, indicate that the carrying amount of an asset may not be recoverable. We regularly review the future deployment of our idle compression assets used in our contract operations segment for units that are not the type, configuration, condition, make or model that are cost efficient to maintain and operate. During the year ended December 31, 2018, we evaluated for impairment idle units that had been previously culled from our fleet and are available for sale. Based upon that review, we reduced the expected proceeds from disposition for certain units. This resulted in an additional impairment of $2.1 million to reduce the book value of each unit to its estimated fair value during the year ended December 31, 2018. During the years ended December 31, 2017 and 2016, we determined that one idle compressor unit and 62 idle compressor units, respectively, would be retired from the active fleet. The retirement of these units from the active fleet triggered a review of these assets for impairment. As a result, we recorded asset impairments of $0.6 million and $12.7 million during the years ended December 31, 2017 and 2016, respectively, to reduce the book value of each unit to its estimated fair value. The fair value of each unit was estimated based on either the expected net sale proceeds compared to other fleet units we sold and/or a review of other units offered for sale by third parties during that time or the estimated component value of the equipment on each compressor unit that we planned to use at that time. In the fourth quarter of 2017, we classified our PEQ assets primarily related to inventory and property, plant and equipment, net, within our product sales business as assets held for sale in our balance sheets. As described in Note 8, in June 2018, we completed the sale of our PEQ assets. During the years ended December 31, 2018 and 2017, we recorded impairments of $1.8 million and $2.1 million, respectively, to reduce these assets to their approximate fair values based on the expected net proceeds. Additionally, in the fourth quarter of 2017, we determined that certain other assets within our product sales business were assessed to have no future benefit to our ongoing operations. In conjunction with the assessment of these other assets, we recorded an impairment charge of $3.0 million to write-down these assets. During the year ended December 31, 2016, we evaluated other assets for impairment and recorded long-lived asset impairments of $1.7 million on these assets. Note 14. Restatement Related Charges (Recoveries), Net During the first quarter of 2016, our senior management identified errors relating to the application of percentage-of- completion accounting principles to specific Belleli EPC product sales projects. As a result, the Audit Committee of the Company’s Board of Directors initiated an internal investigation, including the use of services of a forensic accounting firm. Management also engaged a consulting firm to assist in accounting analysis and compilation of restatement adjustments. We incurred restatement related charges of $0.9 million, $6.2 million and $30.1 million during the years ended December 31, 2018, 2017 and 2016, respectively. The costs incurred were external costs associated with an SEC investigation and remediation activities related to the restatement of our financial statements. We recorded recoveries from Archrock pursuant to the separation and distribution agreement for previously incurred restatement related costs of $1.2 million, $2.8 million and $11.2 million, during the years ended December 31, 2018, 2017 and 2016, respectively. We may incur additional cash expenditures related to external legal counsel costs associated with an ongoing SEC investigation surrounding the restatement of our financial statements, of which a portion may be recoverable from Archrock. F-30 The following table summarizes the changes to our accrued liability balance related to restatement charges, net, for the years ended December 31, 2017 and 2018 (in thousands): Beginning balance at January 1, 2017 Additions for costs expensed, net Reductions for payments, net Ending balance at December 31, 2017 Reductions for recoveries, net Reductions for payments, net Ending balance at December 31, 2018 Restatement Related Charges 2,212 3,419 (5,052) 579 (276) (256) 47 $ $ The following table summarizes the components of charges included in restatement related charges (recoveries), net, in our statements of operations for the years ended December 31, 2018, 2017 and 2016 (in thousands): External accounting costs External legal costs Other Recoveries from Archrock Total restatement related charges (recoveries), net Note 15. Restructuring and Other Charges Years Ended December 31, 2018 2017 2016 $ $ — $ 531 413 (1,220) (276) $ 1,071 4,396 753 (2,801) 3,419 $ $ 21,073 7,565 1,448 (11,207) 18,879 In the second quarter of 2018, we initiated a relocation plan in the North America region to better align our contract operations business with our customers. As a result of this plan, during the year ended December 31, 2018, we incurred restructuring and other charges of $2.0 million. As of December 31, 2018, the accrued liability balance related to this plan was $0.3 million. The charges incurred in conjunction with this relocation plan are included in restructuring and other charges in our statements of operations. We currently estimate that we will incur additional charges with respect to this relocation plan of approximately $0.3 million. We expect the majority of the estimated additional charges will result in cash expenditures. In connection with the Spin-off, we incurred restructuring and other charges of $0.6 million and $3.9 million during the years ended December 31, 2017 and 2016, respectively, primarily related to retention awards to certain employees of $0.6 million and $3.1 million, respectively, which were amortized over the required service period of each applicable employee. Additionally, we announced a cost reduction plan primarily focused on workforce reductions and the reorganization of certain facilities in the second quarter of 2015. We incurred restructuring and other charges associated with the cost reduction plan of $2.6 million and $18.1 million during the years ended December 31, 2017 and 2016, respectively. Cost incurred for employee termination benefits during the year ended December 31, 2017 were $2.1 million. Restructuring and other charges incurred during the year ended December 31, 2016 were primarily related to employee termination benefits and the exit from a leased corporate building. Costs incurred for employee termination benefits during the year ended December 31, 2016 were $14.5 million, of which $9.0 million related to our product sales segment. We ceased the use of a corporate building under an operating lease in the second quarter of 2016, and as a result, recorded net charges of $2.9 million during the year ended December 31, 2016. The charges incurred in conjunction with the Spin-off and cost reduction plan are reflected as restructuring and other charges in our statements of operations. In 2017, we completed restructuring activities related to the Spin-off and cost reduction plan. F-31 The following table summarizes the changes to our accrued liability balance related to restructuring and other charges for the years ended December 31, 2017 and 2018 (in thousands): Spin-off Cost Reduction Plan Relocation Plan Total Beginning balance at January 1, 2017 $ 934 $ Additions for costs expensed Less non-cash income (expense) Reductions for payments Ending balance at December 31, 2017 Additions for costs expensed Reductions for payments Ending balance at December 31, 2018 $ 599 (223) (1,310) — — — — $ $ 2,461 2,590 740 (5,179) 612 — (612) — $ — $ — — — — 1,997 (1,688) 309 $ 3,395 3,189 517 (6,489) 612 1,997 (2,300) 309 The following table summarizes the components of charges included in restructuring and other charges in our statements of operations for the years ended December 31, 2018, 2017 and 2016 (in thousands): Consulting fees Start-up of stand-alone functions Retention awards to certain employees Employee termination benefits Net charges to exit the use of a corporate operating lease Relocation costs Other Years Ended December 31, 2018 2017 2016 $ — $ — — $ — — 910 — 1,087 — 599 2,100 — — 490 22 887 3,056 14,473 2,904 — 696 Total restructuring and other charges $ 1,997 $ 3,189 $ 22,038 Note 16. Provision for Income Taxes The components of income (loss) before income taxes were as follows (in thousands):  United States Foreign Income (loss) before income taxes Years Ended December 31, 2018 2017 $ $ (6,899) $ 46,724 39,825 $ (43,403) $ 60,242 16,839 $ 2016 (129,864) 82,340 (47,524) F-32 The provision for income taxes consisted of the following (in thousands): Years Ended December 31, 2018 2017 2016 Current tax provision (benefit): U.S. federal State Foreign Total current Deferred tax provision (benefit): U.S. federal State Foreign Total deferred Provision for income taxes $ $ 769 258 36,869 37,896 242 (71) 1,366 1,537 $ 39,433 $ — $ 250 25,638 25,888 (5,102) (15) 1,924 (3,193) 22,695 (131) (792) 54,075 53,152 62,672 2,306 6,112 71,090 $ 124,242 The provision for income taxes for 2018, 2017 and 2016 resulted in effective tax rates on continuing operations of 99.0%, 134.8% and (261.4)%, respectively. The reasons for the differences between these effective tax rates and the U.S. statutory rate are as follows (in thousands): Years Ended December 31, 2018 2017 2016 Income taxes at U.S. federal statutory rate of 21% (35% for 2017 and 2016) $ State income taxes net of federal tax benefit Foreign tax rate differential U.S. foreign tax credits or deductions Research and development credits Unrecognized tax benefits Change in valuation allowances Proceeds from sale of joint venture assets Capital contributions or distributions related to Spin-off Change in U.S. deferred taxes related to Tax Reform Act Transition Tax Other Provision for income taxes 8,363 $ 5,894 $ 261 28,266 8,349 — 9,496 (18,973) — (352) — 873 3,150 361 44,868 (11,224) — 3,332 (48,059) — (1,084) 15,518 10,060 3,029 $ 39,433 $ 22,695 $ (16,633) (1,841) 29,428 (9,492) (1,024) 3,629 124,850 (3,641) (2,887) — — 1,853 124,242   Tax legislation enacted and signed into law in 2017 in the U.S. and in Argentina resulted in changes to the statutory tax rates at which certain deferred tax assets and liabilities are recorded. In 2017, these rate changes resulted in reconciling items between income tax recorded at the U.S. statutory rate and the company’s provision for income taxes of $15.5 million and $(3.1) million, respectively. In the U.S., the valuation allowance that had been previously recorded was reduced as a result of the U.S. statutory rate changes. F-33 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 using enacted tax rates in effect for the year in which the differences are expected to reverse. The tax effects of temporary differences that give rise to deferred tax assets and deferred tax liabilities are as follows (in thousands): Deferred tax assets: Net operating loss carryforwards Foreign tax credit carryforward Research and development credit carryforwards Alternative minimum tax credit carryforwards Deferred revenue Other Subtotal Valuation allowances Total deferred tax assets Deferred tax liabilities: Property, plant and equipment Other Total deferred tax liabilities Net deferred tax assets December 31, 2018 2017 $ 68,377 $ 81,759 31,251 5,493 25,858 39,751 252,489 (200,105) 52,384 (28,413) (18,606) (47,019) 5,365 $ $ 86,060 92,734 31,251 5,575 32,496 47,496 295,612 (222,049) 73,563 (47,954) (24,805) (72,759) 804 During the year ended December 31, 2017, our Brazil subsidiary entered into two tax programs: 1) the Tax Regularization Program (the “PRT Program”) pursuant to Brazil Provisional Measure No. 766 issued on January 4, 2017 and 2) the Tax Special Regularization Program (the “PERT Program”) pursuant to Brazil Provisional Measure No. 783 issued on May 31, 2017. These programs allow for the partial settling of debts, both income tax debts and non-income-based tax debts, due by November 30, 2016 and April 30, 2017 to Brazil’s Federal Revenue Service for the PRT Program and PERT Program, respectively, with the use of tax credits, including income tax loss carryforwards. A $15.2 million income tax benefit was recorded during the year ended December 31, 2017 attributable to the reversal of valuation allowances against certain deferred tax assets related to income tax loss carryforwards that were utilized under the PRT Program and PERT Program, including interest income. Additionally, during the year ended December 31, 2017, we incurred $1.8 million in penalties, which is reflected in other (income) expense, net, in our statements of operations, and $2.4 million in interest expense, which is reflected in interest expense in our statements of operations, attributable to the settling of non-income-based tax debts in connection with the PRT Program and the PERT Program. At December 31, 2018, we had U.S. federal net operating loss carryforwards of approximately $77.4 million that are available to offset future taxable income. If not used, the carryforwards begin to expire in 2026. We also had approximately $146.8 million of net operating loss carryforwards in certain foreign jurisdictions (excluding discontinued operations), approximately $113.4 million of which has no expiration date, $3.7 million of which is subject to expiration from 2019 to 2023, and the remainder of which expires in future years through 2038. Foreign tax credit carryforwards of $81.8 million, research and development credits carryforwards of $31.3 million and alternative minimum tax credit carryforwards of $5.5 million are available to offset future payments of U.S. federal income tax. The foreign tax credits will expire in varying amounts beginning in 2020 and research and development credits will expire in varying amounts beginning in 2028. The U.S. corporate alternative minimum tax (“AMT”) has been repealed for tax years beginning after December 31, 2017. Companies with AMT credits that have not been utilized may claim a refund in future years for those credits even when no income tax liability exists. We expect our existing AMT credits to be fully utilized or refunded by 2021. F-34 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. Management assesses all available positive and negative evidence to estimate our ability to generate sufficient future taxable income of the appropriate character, and in the appropriate taxing jurisdictions, to permit use of our existing deferred tax assets. A significant piece of objective negative evidence is a cumulative loss incurred over a three-year period in a taxing jurisdiction. Prevailing accounting practice is that such objective evidence would limit the ability to consider other subjective evidence, such as our projections for future growth. We incurred a three-year cumulative loss in the U.S. during 2016. Due to this significant negative evidence of cumulative losses, which outweighed the positive evidence of firm sales backlog and projected future taxable income, we were no longer able to support that it was more-likely-than-not that we will have sufficient taxable income of the appropriate character in the future that will allow us to realize our U.S. deferred tax assets. During the year ended December 31, 2016, we recorded a full valuation allowances against our U.S. deferred tax assets resulting in an additional charge of $119.8 million, of which $65.5 million related to U.S. deferred tax assets that existed at December 31, 2015. Pursuant to Sections 382 and 383 of the Internal Revenue Code of 1986, as amended (the “Code”), utilization of loss carryforwards and credit carryforwards, such as foreign tax credits, will be subject to annual limitations due to the historical ownership changes of both Hanover Compressor Company (“Hanover”) and Universal Compression Holdings, Inc. (“Universal”). In general, an ownership change, as defined by Section 382 of the Code, results from transactions increasing the ownership of certain stockholders or public groups in the stock of a corporation by more than 50 percentage points over a three- year period. The merger of Hanover and Universal to form Archrock (formerly Exterran Holdings, Inc.) in August 2007 resulted in such an ownership change for both Hanover and Universal. Our ability to utilize loss carryforwards and credit carryforwards against future U.S. federal income tax may be limited. The limitations may cause us to pay U.S. federal income taxes earlier; however, we do not currently expect that any loss carryforwards or credit carryforwards will expire as a result of these limitations. We consider the earnings of substantially all of our foreign subsidiaries to be indefinitely reinvested, and accordingly, as of December 31, 2018, we have not provided for taxes on approximately $341.7 million of cumulative undistributed foreign earnings. If we were to make a distribution from the unremitted earnings of these subsidiaries, we could be subject to taxes payable to various jurisdictions. Computation of the potential deferred tax liability associated with these undistributed earnings and any other basis differences is not practicable. If our expectations were to change regarding future tax consequences, we may be required to record additional deferred taxes that could have a material effect on our consolidated statement of financial position, results of operations or cash flows. On December 22, 2017, the U.S. government enacted comprehensive tax legislation. The Tax Reform Act makes broad and complex changes to the U.S. tax code, including, but not limited to, (1) reducing the U.S. federal corporate tax rate from 35% to 21%; (2) requiring companies to pay a one-time transition tax on certain unrepatriated earnings of foreign subsidiaries (the “Transition Tax”); (3) generally eliminating U.S. federal income taxes on dividends from foreign subsidiaries; (4) requiring a current inclusion in U.S. federal taxable income of certain earnings of controlled foreign corporations; (5) eliminating the corporate AMT and changing how existing AMT credits can be realized; (6) creating the base erosion anti-abuse tax (“BEAT”), a new minimum tax; (7) creating a new limitation on deductible interest expense; and (8) changing rules related to uses and limitations of net operating loss carryforwards created in tax years beginning after December 31, 2017. Guidance under U.S. GAAP requires that the impact of tax legislation be recognized in the period in which the law was enacted. For the year ended December 31, 2017, our provision for income tax included the reversal of previously recorded valuation allowances of $5.6 million against our U.S. AMT carryforwards due to the Tax Cuts and Jobs Act (“Tax Reform Act”) which provides for the cancellation of the AMT and allows for a future refund and/or credit against regular income tax carry forwards. In December 2017, the SEC staff issued Staff Accounting Bulletin No. 118, which addresses how a company recognizes provisional amounts when a company does not have the necessary information available, prepared or analyzed (including computations) in reasonable detail to complete its accounting for the effect of the changes in the Tax Reform Act. The measurement period ends when a company has obtained, prepared and analyzed the information necessary to finalize its accounting, but cannot extend beyond one year. We completed our analysis and as a result recorded a $0.9 million adjustment in the fourth quarter of 2018 to the provisional estimate for Transition Tax that we had recorded for the year ended December 31, 2017. F-35 Deemed repatriation transition tax on undistributed earnings: The Transition Tax is a deemed repatriation tax on certain previously untaxed accumulated earnings and profits (“E&P”) of our foreign subsidiaries. For the year ended December 31, 2017, we were able to reasonably estimate the Transition Tax and recorded a provisional Transition Tax obligation of $10.1 million, with a corresponding tax benefit from the reduction of the valuation allowance previously recorded against U.S. deferred tax assets. In the fourth quarter of 2018, we completed our analysis and recorded an additional $0.9 million of Transition Tax with a corresponding tax benefit from the reduction of the valuation allowance previously recorded against U.S. deferred tax assets. Result of reduction in U.S. corporate tax rate: The Tax Reform Act reduced the U.S. corporate tax rate from 35% to 21%. For the year ended December 31, 2017, we recorded $15.5 million due to the remeasurement of deferred tax assets and liabilities, to reflect the impact of the lower effective rate, with a corresponding tax benefit from the reduction of the valuation allowance previously recorded against U.S. deferred tax assets. While the Tax Reform Act provides for a territorial tax system, beginning in 2018, it includes two new U.S. tax base erosion provisions: the global intangible low-taxed income (“GILTI”) provisions and the BEAT provisions. The GILTI provisions require us to include foreign subsidiary earnings in excess of an allowable return on the foreign subsidiary’s tangible assets in our U.S. income tax return. We have made an accounting policy choice to treat taxes due on future U.S. inclusions in taxable income related to GILTI as a current-period expense when incurred (the “period cost method”). For the year ended December 31, 2018, the GILTI tax provisions did not have a material impact on our provision for income taxes. The BEAT provisions eliminate the deduction of certain base-erosion payments made to related foreign corporations beginning in 2018, and impose a minimum tax if greater than regular tax. For the year ended December 31, 2018, the BEAT tax provisions resulted in a $0.4 million charge to our provision for income taxes. On January 15, 2019, the IRS and Treasury Department released final regulations related to the Transition Tax. We will be considering the impacts of these final regulations and any additional guidance released on applying the impact of the Tax Reform Act prospectively and will record changes to our provision amounts (if any) in future periods. A reconciliation of the beginning and ending amount of unrecognized tax benefits (including discontinued operations) is shown below (in thousands): Years Ended December 31, 2018 2017 2016 Beginning balance $ 20,548 $ 18,237 $ Additions based on tax positions related to prior years Additions based on tax positions related to current year Reductions based on settlement with government authority Reductions based on lapse of statute of limitations Reductions based on tax positions related to prior years Ending balance $ 2,542 9,983 (1,391) (1,997) (1,902) 27,783 $ 2,034 1,686 (241) (378) (790) 20,548 14,943 3,140 256 — (102) — $ 18,237 We had $27.8 million, $20.5 million and $18.2 million of unrecognized tax benefits at December 31, 2018, 2017 and 2016, respectively, which if recognized, would affect the effective tax rate (except for amounts that would be reflected in income (loss) from discontinued operations, net of tax). We also have recorded $4.7 million, $4.3 million and $3.0 million of potential interest expense and penalties related to unrecognized tax benefits associated with uncertain tax positions (including discontinued operations) as of December 31, 2018, 2017 and 2016, respectively. To the extent interest and penalties are not assessed with respect to unrecognized tax benefits, amounts accrued will be reduced and reflected as reductions in income tax expense. F-36 We and our subsidiaries file consolidated and separate income tax returns in the U.S. federal jurisdiction and in numerous state and foreign jurisdictions. Certain of our operations were historically included in Archrock’s consolidated income tax returns in the U.S. federal and state jurisdictions. In addition, certain of Archrock’s operations were historically included in our separate income tax returns in state jurisdictions. Under the Code and the related rules and regulations, each corporation that was a member of the Archrock consolidated U.S. federal income tax reporting group during any taxable period or portion of any taxable period ending on or before the effective time of the Spin-off is jointly and severally liable for the U.S. federal income tax liability of the entire Archrock consolidated tax reporting group for that taxable period. In connection with the Spin-off, we entered into a tax matters agreement with Archrock that allocates the responsibility for prior period taxes of the Archrock consolidated tax reporting group between us and Archrock. We are subject to examination by taxing authorities throughout the world, including the U.S and major foreign jurisdictions such as Argentina, Brazil and Mexico. With few exceptions, we and our subsidiaries are no longer subject to foreign income tax examinations for tax years before 2006. Several domestic and foreign audits are currently in progress and we do not expect any tax adjustments that would have a material impact on our financial position or results of operations. We believe it is reasonably possible that a decrease of up to approximately $9 million in unrecognized tax benefits may be necessary on or before December 31, 2019 due to the cash and non-cash settlement of audits and the expiration of statutes of limitations. However, due to the uncertain and complex application of tax regulations, it is possible that the ultimate resolution of these matters may result in liabilities which could materially differ from these estimates. Note 17. Stockholders’ Equity Preferred Stock We have authorized 50.0 million shares of preferred stock, $0.01 par value per share, none of which was issued and outstanding at December 31, 2018. Our board of directors is authorized to determine the rights, preferences, and restrictions on any series of preferred stock that we may issue. Common Stock We have authorized 250.0 million shares of common stock, $0.01 par value per share, of which 36,868,066 and 36,146,786 shares are issued and outstanding at December 31, 2018, respectively. Each share of common stock is entitled to a single vote. We have not declared or paid any dividends through December 31, 2018. Additional paid-in capital Pursuant to the separation and distribution agreement, EESLP contributed to a subsidiary of Archrock the right to receive payments based on a notional amount corresponding to payments received by our subsidiaries from PDVSA Gas in respect of the sale of our and our joint ventures’ previously nationalized assets promptly after such amounts are collected by our subsidiaries. Pursuant to the separation and distribution agreement, we transferred cash of $18.7 million, $19.7 million and $49.2 million to Archrock during the years ended December 31, 2018, 2017 and 2016, respectively. The transfers of cash were recognized as reductions to additional paid-in capital in our financial statements. Additionally, during the year ended December 31, 2017 we transferred cash of $25.0 million to Archrock in satisfaction of EESLP’s obligation to pay that sum following the occurrence of a qualified capital raise as required under the separation and distribution agreement. Comprehensive Income (Loss) Components of comprehensive income (loss) are net income (loss) and all changes in stockholders’ equity during a period except those resulting from transactions with owners. Our accumulated other comprehensive income consists of foreign currency translation adjustments. F-37 The following table presents the changes in accumulated other comprehensive income, net of tax, during the years ended December 31, 2016, 2017 and 2018 (in thousands): Accumulated other comprehensive income, January 1, 2016 Income recognized in other comprehensive income (loss) Loss reclassified from accumulated other comprehensive income (1) Accumulated other comprehensive income, December 31, 2016 Loss recognized in other comprehensive income (loss) Accumulated other comprehensive income, December 31, 2017 Loss recognized in other comprehensive income (loss) Accumulated other comprehensive income, December 31, 2018 Foreign Currency Translation Adjustment 29,198 3,151 15,159 47,508 (1,801) 45,707 (7,476) 38,231 $ $ (1) During the year ended December 31, 2016, we reclassified a loss of $15.2 million related to foreign currency translation adjustments to income (loss) from discontinued operations in our statement of operations. This amount represents cumulative foreign currency translation adjustments associated with our Belleli CPE business that previously had been recognized in accumulated other comprehensive income. See Note 4 for further discussion of the sale of our Belleli CPE business. Note 18. Stock-Based Compensation and Awards Stock Incentive Plan On October 30, 2015, our compensation committee and board of directors each approved the Exterran Corporation 2015 Stock Incentive Plan (the “2015 Plan”) to provide for the granting of stock options, stock appreciation rights, restricted stock, restricted stock units, performance awards, other stock-based awards and dividend equivalents rights to employees, directors and consultants of Exterran Corporation. The 2015 Plan became effective on November 1, 2015. The maximum aggregate number of shares of our common stock that may be issued under the 2015 Plan is 3,000,000 shares, of which 1,114,438 shares were available to be issued under the plan as of December 31, 2018. Awards granted under the 2015 Plan that are subsequently cancelled, terminated or forfeited are available for future grant. Directors’ Stock and Deferral Plan On October 30, 2015, our compensation committee and board of directors each approved the Exterran Corporation 2015 Directors’ Stock and Deferral Plan (the “Director Plan”). Under the Director Plan, which became effective on October 30, 2015, members of our board of directors may elect, on an annual basis, to receive 25%, 50%, 75% or 100% of their retainer and meeting fees (the “Retainer Fees”) in shares of our common stock in lieu of cash. The number of shares of our common stock issued to each director who elects to have a portion of their Retainer Fees paid in shares in lieu of cash is determined by dividing the applicable dollar amount of such portion by the closing sales price per share of our common stock on the last trading day of the quarter. Any portion of the Retainer Fees paid in cash will be paid to the director following the close of the calendar quarter for which such Retainer Fees were earned. Under the Director Plan, members of the board of directors who elect to receive the Retainer Fees in the form of shares may also elect to defer the receipt of the Retainer Fees until a later date. The maximum aggregate number of shares of our common stock that may be issued under the Director Plan is 125,000 shares, of which 77,870 shares were available to be issued under the plan as of December 31, 2018. The board of directors will administer the Director Plan and has the authority to make certain equitable adjustments under the Director Plan in the event of certain corporate transactions. F-38 Stock-based compensation expense relates to awards to employees, directors and consultants of Exterran Corporation. The following table presents the stock-based compensation expense included in our results of operations (in thousands): Stock options Restricted stock, restricted stock units, performance units, cash settled restricted stock units and cash settled performance units Restructuring and other charges—stock-based compensation expense Total stock-based compensation expense Stock Options Years Ended December 31, 2018 2017 2016 — $ 21 $ 115 14,088 — 14,685 662 14,088 $ 15,368 $ 13,188 1,333 14,636 $ $ Stock options are granted at fair market value at the grant date, are exercisable according to the vesting schedule established and generally expire no later than 10 years after the grant date. Stock options generally vest one-third per year on each of the first three anniversaries of the grant date. There were no stock options granted during the years ended December 31, 2018, 2017 and 2016. The table below presents the changes in stock option awards for our common stock during the year ended December 31, 2018. Stock Options (in thousands) Weighted Average Exercise Price Per Share Weighted Average Remaining Life (in years) Aggregate Intrinsic Value (in thousands) Options outstanding, January 1, 2018 Granted Exercised Cancelled Options outstanding, December 31, 2018 Options exercisable, December 31, 2018 210 $ — (136) — 74 74 15.61 — 10.06 — 25.81 25.81 $ 1.7 1.7 — — Intrinsic value is the difference between the market value of our common stock and the exercise price of each stock option multiplied by the number of stock options outstanding for those stock options where the market value exceeds their exercise price. The total intrinsic value of stock options exercised to purchase our common stock during the year ended December 31, 2018 was $2.1 million. Restricted Stock, Restricted Stock Units and Performance Units For grants of restricted stock, restricted stock units and performance units, we recognize compensation expense over the applicable vesting period equal to the fair value of our common stock at the grant date. Grants of restricted stock, restricted stock units and performance units generally vest one-third per year on each of the first three anniversaries of the grant date. Certain grants of restricted stock vest on the third anniversary of the grant date and certain grants of performance units vest on the second anniversary of the grant date. F-39 The table below presents the changes in restricted stock, restricted stock units and performance units for our common stock during the year ended December 31, 2018. Non-vested awards, January 1, 2018 Granted Vested Cancelled Non-vested awards, December 31, 2018 Weighted Average Grant-Date Fair Value Per Share Shares (in thousands) 1,165 $ 576 (591) (106) 1,044 23.93 26.25 22.50 25.18 25.89 As of December 31, 2018, we estimate $16.5 million of unrecognized compensation cost related to unvested restricted stock, restricted stock units and performance units issued to our employees to be recognized over the weighted-average vesting period of 1.5 years. Note 19. Net Income (Loss) Per Common 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 restricted stock units that have non-forfeitable rights to receive dividends or dividend equivalents, whether paid or unpaid. During periods of net loss from continuing operations, no effect is given to participating securities because they do not have a contractual obligation to participate in our losses. Diluted net income (loss) per common share is computed using the weighted average number of common shares outstanding adjusted for the incremental common stock equivalents attributed to outstanding options to purchase common stock and non- participating restricted stock units, unless their effect would be anti-dilutive. F-40 The following table presents a reconciliation of basic and diluted net income (loss) per common share for the years ended December 31, 2018, 2017 and 2016 (in thousands, except per share data): Numerator for basic and diluted net income (loss) per common share: Income (loss) from continuing operations Income (loss) from discontinued operations, net of tax Less: Net income attributable to participating securities Net income (loss) — used in basic and diluted net income (loss) per common share 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 restricted stock units Weighted average common shares outstanding — used in diluted net income (loss) per common share Net income (loss) per common share: Basic Diluted Years Ended December 31, 2018 2017 2016 392 $ 24,462 (641) (5,856) $ 39,736 — (171,766) (56,171) — 24,213 $ 33,880 $ (227,937) 36,371 (938) 35,961 (1,002) 35,489 (921) 35,433 34,959 34,568 56 * * 35,489 34,959 34,568 0.68 0.68 $ $ 0.97 0.97 $ $ (6.59) (6.59) $ $ $ $ * Excluded from diluted net income (loss) per common share as their inclusion would have been anti-dilutive. The following table shows the potential shares of common stock issuable for the years ended December 31, 2018, 2017 and 2016 that were excluded from computing diluted net income (loss) per common share as their inclusion would have been anti- dilutive (in thousands): Net dilutive potential common shares issuable: On exercise of options where exercise price is greater than average market value for the period On exercise of options and vesting of restricted stock units Net dilutive potential common shares issuable Note 20. Retirement Benefit Plan Years Ended December 31, 2018 2017 2016 35 — 35 43 81 124 225 50 275 Our 401(k) retirement plan provides for optional employee contributions for certain employees who are U.S. citizens up to the Internal Revenue Service limit and discretionary employer matching contributions. During the year ended December 31, 2018, we made discretionary matching contributions to each participant’s account at a rate of (i) 100.0% of each participant’s first 2% of contributions plus (ii) 50% of each participant’s contributions up to the next 4% of eligible compensation. During the years ended December 31, 2017 and 2016, we made discretionary matching contributions to each participant’s account at a rate of (i) 100.0% of each participant’s first 1% of contributions plus (ii) 50% of each participant’s contributions up to the next 5% of eligible compensation. Costs incurred for employer matching contributions of $3.3 million, $2.4 million and $2.4 million during the years ended December 31, 2018, 2017 and 2016, respectively, are presented as selling, general and administrative expense in our statements of operations. F-41 Note 21. Commitments and Contingencies Rent expense relating to facilities and other operating leases for 2018, 2017 and 2016 was approximately $9.9 million, $9.3 million and $9.9 million, respectively. Commitments for future minimum rental payments with terms in excess of one year as of December 31, 2018 are as follows (in thousands): 2019 2020 2021 2022 2023 Thereafter Total Contingencies December 31, 2018 $ $ 6,076 5,929 4,583 3,756 3,038 11,615 34,997 Pursuant to the separation and distribution agreement, EESLP contributed to a subsidiary of Archrock the right to receive payments based on a notional amount corresponding to payments received by our subsidiaries from PDVSA Gas in respect of the sale of our joint ventures’ previously nationalized assets promptly after such amounts are collected by our subsidiaries. Our balance sheets do not reflect this contingent liability to Archrock or the amount payable to us by PDVSA Gas as a receivable. As of December 31, 2018, the remaining principal amount due to us from PDVSA Gas in respect of the sale of our joint ventures’ previously nationalized assets was approximately $4 million. In subsequent periods, the recognition of a liability, if applicable, resulting from this contingency to Archrock is expected to impact equity, and as such, is not expected to have an impact on our statements of operations. In addition to U.S. federal, state and local and foreign income taxes, we are subject to a number of 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, 2018 and 2017, we had accrued $5.1 million and $2.8 million, respectively, for the outcomes of non-income-based tax audits and had related indemnification receivables from Archrock of $2.8 million and $1.5 million, respectively. 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 do not have any unasserted claims from non-income-based tax audits that we have determined are probable of assertion. We also believe the likelihood is remote that the impact of potential unasserted claims from non-income-based tax audits could be material to our financial position, but it is possible that the resolution of future audits could be material to our results of operations or cash flows for the period in which the resolution occurs. 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, 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. F-42 Litigation and Claims In the ordinary course of business, we are involved in various pending or threatened legal actions. While management is unable to predict the ultimate outcome of these actions, it believes that any ultimate liability arising from any of these actions will not have a material adverse effect on our financial position, results of operations or cash flows. 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 financial position, results of operations or cash flows. Contemporaneously with filing the Form 8-K on April 26, 2016, we self-reported the errors and possible irregularities at Belleli EPC to the SEC. Since then, we have been cooperating with the SEC in its investigation of this matter. The SEC’s investigation related to the circumstances giving rise to the restatement is continuing, and we are presently unable to predict the duration, scope or results or whether the SEC will commence any legal action. Indemnifications In conjunction with, and effective as of the completion of, the Spin-off, we entered into the separation and distribution agreement with Archrock, which governs, among other things, the treatment between Archrock and us relating to certain aspects of indemnification, insurance, confidentiality and cooperation. Generally, the separation and distribution agreement provides for cross-indemnities principally designed to place financial responsibility for the obligations and liabilities of our business with us and financial responsibility for the obligations and liabilities of Archrock’s business with Archrock. Pursuant to the agreement, we and Archrock will generally release the other party from all claims arising prior to the Spin-off that relate to the other party’s business, subject to certain exceptions. Additionally, in conjunction with, and effective as of the completion of, the Spin-off, we entered into the tax matters agreement with Archrock. Under the tax matters agreement and subject to certain exceptions, we are generally liable for, and indemnify Archrock against, taxes attributable to our business, and Archrock is generally liable for, and indemnify us against, all taxes attributable to its business. We are generally liable for, and indemnify Archrock against, 50% of certain taxes that are not clearly attributable to our business or Archrock’s business. Any payment made by us to Archrock, or by Archrock to us, is treated by all parties for tax purposes as a nontaxable distribution or capital contribution, respectively, made immediately prior to the Spin-off. Note 22. Reportable Segments and Geographic Information Our chief operating decision maker manages business operations, evaluates performance and allocates resources based upon the type of product or service provided. We have three reportable segments: contract operations, aftermarket services and product sales. In our contract operations segment, we provide compression and processing and treating services through the operation of our natural gas compression equipment and crude oil and natural gas production and process equipment for our customers. In our aftermarket services segment, we sell parts and components and provide operations, maintenance, repair, overhaul, upgrade, startup and commissioning and reconfiguration services to customers who own their own oil and natural gas compression, production, processing, treating and related equipment. In our product sales segment, we design, engineer, manufacture, install and sell natural gas compression packages as well as equipment used in the treating and processing of crude oil and natural gas to our customers throughout the world and for use in our contract operations business line. We evaluate the performance of our segments based on gross margin for each segment. Revenue only includes sales to external customers. We do not include intersegment sales when we evaluate our segments’ performance. During the year ended December 31, 2018, MPLX LP (“MPLX”) accounted for approximately 15% of our total revenue. During the year ended December 31, 2017, Archrock accounted for approximately 12% of our total revenue and during the year ended December 31, 2016, Petroleo Brasileiro S.A. accounted for approximately 10% of our total revenue. No other customer accounted for more than 10% of our total revenue in 2018, 2017 and 2016. F-43 The following table presents revenue and other financial information by reportable segment for the years ended December 31, 2018, 2017 and 2016 (in thousands): 2018: Revenue Gross margin (3) Total assets Capital expenditures 2017: Revenue Gross margin (3) Total assets Capital expenditures 2016: Revenue Gross margin (3) Total assets Capital expenditures Contract Operations Aftermarket Services Product Sales Reportable Segments Total Other (1) Total (2) $ 360,973 $ 120,676 $ 238,835 860,896 197,025 31,010 28,071 474 879,207 113,583 205,302 7,552 $ 1,360,856 383,428 $ — $ 1,360,856 383,428 — 1,094,269 205,051 459,519 10,057 1,553,788 215,108 $ 375,269 $ 107,063 $ 732,962 241,889 783,340 123,842 28,842 22,882 339 76,409 139,454 2,712 $ 1,215,294 347,140 $ — $ 1,215,294 347,140 — 945,676 126,893 487,680 1,433,356 4,780 131,673 $ 392,463 $ 120,550 $ 392,384 $ 905,397 $ 248,793 745,752 69,946 33,208 28,421 332 26,990 169,525 1,371 308,991 943,698 71,649 — $ — 905,397 308,991 381,266 1,324,964 2,021 73,670 (1) (2) (3) Includes corporate related items. Totals exclude assets, capital expenditures and the operating results of discontinued operations. Gross margin is defined as revenue less cost of sales (excluding depreciation and amortization expense). The following table presents assets from reportable segments reconciled to total assets as of December 31, 2018 and 2017 (in thousands): Assets from reportable segments Other assets (1) Assets associated with discontinued operations Total assets (1) Includes corporate related items. December 31, 2018 1,094,269 $ $ 459,519 13,266 2017 945,676 487,680 27,451 $ 1,567,054 $ 1,460,807 The following tables present geographic data by country as of and for the years ended December 31, 2018, 2017 and 2016 (in thousands): Revenue: U.S. Argentina Brazil Mexico Other international Total Years Ended December 31, 2018 2017 2016 $ $ 789,528 $ 648,290 $ 139,987 94,619 68,745 267,977 1,360,856 $ 156,340 98,419 75,388 236,857 1,215,294 $ 335,268 151,374 85,831 90,876 242,048 905,397 F-44 Property, plant and equipment, net: U.S. Argentina Brazil Mexico Oman Other international Total 2018 December 31, 2017 2016 $ 112,420 $ 76,562 $ 197,669 105,979 121,312 174,165 190,032 219,840 138,835 148,405 110,115 128,522 $ 901,577 $ 822,279 $ 84,669 222,548 157,139 167,279 23,560 135,727 790,922 The following table reconciles income (loss) before income taxes to total gross margin (in thousands): Income (loss) before income taxes Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges (recoveries), net Restructuring and other charges Interest expense Equity in income of non-consolidated affiliates Other (income) expense, net Total gross margin Years Ended December 31, 2018 2017 2016 $ 39,825 $ 16,839 $ 178,401 123,922 3,858 (276) 1,997 29,217 — 6,484 $ 383,428 $ 176,318 107,824 5,700 3,419 3,189 34,826 — (975) 347,140 $ (47,524) 157,485 132,886 14,495 18,879 22,038 34,181 (10,403) (13,046) 308,991 Note 23. Selected Quarterly Financial Data (Unaudited) In management’s opinion, the summarized quarterly financial data below (in thousands, except per share amounts) contains all appropriate adjustments, all of which are normally recurring adjustments, considered necessary to present fairly our financial position and results of operations for the respective periods. First Quarter Second Quarter Third Quarter Fourth Quarter Year Ended December 31, 2018: Revenue Gross profit (1) Income (loss) from continuing operations Income from discontinued operations, net of tax Net income Net income per common share: Basic Diluted $ 350,383 66,059 3,938 1,399 5,337 $ 343,471 68,598 (1,469) 1,544 75 $ 334,849 66,723 3,196 2,173 5,369 332,153 66,172 (5,273) 19,346 14,073 $ 0.15 0.15 — $ — $ 0.15 0.15 0.40 0.40 $ $ F-45 Year Ended December 31, 2017: Revenue Gross profit (1) Income (loss) from continuing operations Income from discontinued operations, net of tax Net income Net income per common share: Basic Diluted First Quarter Second Quarter Third Quarter Fourth Quarter $ $ $ 245,425 56,537 (12,323) 32,644 20,321 $ 317,701 63,289 3,170 374 3,544 $ 314,479 62,962 1,214 2,139 3,353 337,689 61,621 2,083 4,579 6,662 $ 0.58 0.58 $ 0.10 0.10 $ 0.09 0.09 0.18 0.18 (1) Gross profit is defined as revenue less cost of sales, direct depreciation and amortization expense and direct long-lived asset impairment charges. Additional Notes: • During the fourth quarter of 2018 and the first quarter of 2017, we received installment payments, including an annual charge, of $19.8 million and $19.7 million, respectively, from PDVSA Gas in respect to our Venezuelan subsidiary’s sale of its previously nationalized assets (see Note 4). F-46 Note 24. Supplemental Guarantor Financial Information In April 2017, our 100% owned subsidiaries EESLP and EES Finance Corp. (together, the “Issuers”) issued the 2017 Notes, which consists of $375.0 million aggregate principal amount senior unsecured notes. The 2017 Notes are fully and unconditionally guaranteed on a joint and several senior unsecured basis by Exterran Corporation (the “Parent Guarantor” or “Parent”). All other consolidated subsidiaries of Exterran are collectively referred to as the “Non-Guarantor Subsidiaries.” As a result of the Parent’s guarantee, we are presenting the following condensed consolidating financial information pursuant to Rule 3-10 of Regulation S-X, Financial Statements of Guarantors and Issuers of Guaranteed Securities Registered or Being Registered. These schedules are presented using the equity method of accounting for all periods presented. For purposes of the following condensed consolidating financial information, the Parent Guarantor’s investments in its subsidiaries, the Issuers’ investments in the Non-Guarantors Subsidiaries and the Non-Guarantor Subsidiaries’ investments in the Issuers are accounted for under the equity method of accounting. Under this method, investments in subsidiaries are recorded at cost and adjusted for our share in the subsidiaries’ cumulative results of operations, capital contributions and distributions and other changes in equity. Elimination entries relate primarily to the elimination of investments in subsidiaries and associated intercompany balances and transactions. F-47 Condensed Consolidating Balance Sheet December 31, 2018 (In thousands) ASSETS Cash and cash equivalents Restricted cash Accounts receivable, net Inventory, net Contract assets Intercompany receivables Other current assets Current assets associated with discontinued operations Total current assets Property, plant and equipment, net Investment in affiliates Deferred income taxes Intangible and other assets, net Long-term assets associated with discontinued operations Total assets LIABILITIES AND EQUITY Accounts payable, trade Accrued liabilities Contract liabilities Intercompany payables Current liabilities associated with discontinued operations Total current liabilities Long-term debt Deferred income taxes Long-term contract liabilities Other long-term liabilities Long-term liabilities associated with discontinued operations Total liabilities Total equity Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation $ $ $ 46 — — — — — — — 46 — 554,207 — — — $ 1,185 $ 18,069 $ — $ 19,300 — 92,880 87,972 67,323 158,977 7,744 — 416,081 303,813 870,959 5,493 32,046 — 178 155,587 62,717 24,279 379,628 36,490 11,605 688,553 597,764 — — — — (538,605) — — (538,605) — (316,752) (1,108,414) 5,877 54,325 1,661 — — — 178 248,467 150,689 91,602 — 44,234 11,605 566,075 901,577 — 11,370 86,371 1,661 554,253 $ 1,628,392 $ 1,031,428 $ (1,647,019) $ 1,567,054 — $ 133,291 $ 32,453 $ — $ 165,744 — — 1,432 — 1,432 — — — — — 1,432 552,821 47,012 82,367 379,628 — 642,298 403,810 — 17,226 10,851 — 1,074,185 554,207 76,323 71,116 157,545 14,767 352,204 — 6,005 84,137 28,961 5,914 477,221 554,207 — — (538,605) — (538,605) — — — — — 123,335 153,483 — 14,767 457,329 403,810 6,005 101,363 39,812 5,914 (538,605) 1,014,233 (1,108,414) 552,821 Total liabilities and equity $ 554,253 $ 1,628,392 $ 1,031,428 $ (1,647,019) $ 1,567,054 F-48 Condensed Consolidating Balance Sheet December 31, 2017 (In thousands) ASSETS Cash and cash equivalents Restricted cash Accounts receivable, net Inventory, net Costs and estimated earnings in excess of billings on uncompleted contracts Intercompany receivables Other current assets Current assets held for sale Current assets associated with discontinued operations Total current assets Property, plant and equipment, net Investment in affiliates Deferred income taxes Intangible and other assets, net Long-term assets held for sale $ $ Long-term assets associated with discontinued operations Total assets LIABILITIES AND EQUITY Accounts payable, trade Accrued liabilities Deferred revenue Billings on uncompleted contracts in excess of costs and estimated earnings Intercompany payables Current liabilities associated with discontinued operations Total current liabilities Long-term debt Deferred income taxes Long-term deferred revenue Other long-term liabilities Long-term liabilities associated with discontinued operations Total liabilities Total equity Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation $ 397 $ 24,195 $ 24,553 $ — $ 49,145 — — — — — — — — 397 — 555,735 — — — — — 123,362 50,528 33,439 158,296 6,095 15,761 — 411,676 288,670 831,097 5,452 12,218 4,732 — 546 142,690 57,381 7,256 359,766 32,612 — 23,751 648,555 533,609 — — — — (518,062) — — — (518,062) — (275,362) (1,111,470) 5,098 64,762 — 3,700 — — — — 546 266,052 107,909 40,695 — 38,707 15,761 23,751 542,566 822,279 — 10,550 76,980 4,732 3,700 556,132 $ 1,553,845 $ 980,362 $ (1,629,532) $ 1,460,807 — $ 115,273 $ 33,471 $ — $ 148,744 57 — — 1,289 — 1,346 — — — — — 1,346 554,786 54,724 2,162 89,002 359,766 — 620,927 368,472 — 629 8,082 — 998,110 555,735 59,555 21,740 563 — — — 157,007 (518,062) 31,971 304,307 — 9,746 91,856 12,190 6,528 424,627 555,735 — (518,062) — — — — — (518,062) (1,111,470) 114,336 23,902 89,565 — 31,971 408,518 368,472 9,746 92,485 20,272 6,528 906,021 554,786 Total liabilities and equity $ 556,132 $ 1,553,845 $ 980,362 $ (1,629,532) $ 1,460,807 F-49 Condensed Consolidating Statement of Operations and Comprehensive Income Year Ended December 31, 2018 (In thousands) Revenues $ — $ 927,849 $ 521,879 $ (88,872) $ 1,360,856 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Cost of sales (excluding depreciation and amortization expense) Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related recoveries, net Restructuring and other charges Interest expense Intercompany charges, net Equity in (income) loss of affiliates Other (income) expense, net Income before income taxes Provision for income taxes Income from continuing operations Income from discontinued operations, net of tax Net income Other comprehensive loss Comprehensive income attributable to Exterran stockholders — 1,285 — — — — — — (25,986) (153) 24,854 — 24,854 — 24,854 (7,476) 771,731 86,208 35,754 3,081 (276) — 28,763 6,647 (32,753) (4,625) 33,319 7,333 25,986 — 25,986 (7,476) 294,569 90,908 88,168 777 — 1,997 454 (6,647) 6,767 11,262 33,624 32,100 1,524 24,462 25,986 (7,476) (88,872) — — — — — — — 51,972 — (51,972) — (51,972) — (51,972) 14,952 977,428 178,401 123,922 3,858 (276) 1,997 29,217 — — 6,484 39,825 39,433 392 24,462 24,854 (7,476) $ 17,378 $ 18,510 $ 18,510 $ (37,020) $ 17,378 F-50 Condensed Consolidating Statement of Operations and Comprehensive Income Year Ended December 31, 2017 (In thousands) Revenues $ — $ 838,981 $ 495,262 $ (118,949) $ 1,215,294 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Cost of sales (excluding depreciation and amortization expense) Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges Restructuring and other charges Interest expense Intercompany charges, net Equity in (income) loss of affiliates Other (income) expense, net Income before income taxes Provision for income taxes Income (loss) from continuing operations Income from discontinued operations, net of tax Net income Other comprehensive loss Comprehensive income attributable to Exterran stockholders — 2,327 — — — — — — (36,207) — 33,880 — 33,880 — 33,880 (1,801) 716,002 84,111 35,749 5,700 3,250 2,145 32,399 6,355 (85,335) (2,577) 41,182 4,974 36,208 — 36,208 (1,801) 271,101 89,880 72,075 — 169 1,044 2,427 (6,355) 49,128 1,602 14,191 17,721 (3,530) 39,736 36,206 (1,801) (118,949) — — — — — — — 72,414 — (72,414) — (72,414) — (72,414) 3,602 868,154 176,318 107,824 5,700 3,419 3,189 34,826 — — (975) 16,839 22,695 (5,856) 39,736 33,880 (1,801) $ 32,079 $ 34,407 $ 34,405 $ (68,812) $ 32,079 F-51 Condensed Consolidating Statement of Operations and Comprehensive Loss Year Ended December 31, 2016 (In thousands) Revenues $ — $ 493,428 $ 503,643 $ (91,674) $ 905,397 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Cost of sales (excluding depreciation and amortization expense) Selling, general and administrative Depreciation and amortization Long-lived asset impairment Restatement related charges Restructuring and other charges Interest expense Intercompany charges, net Equity in (income) loss of affiliates Other (income) expense, net Loss before income taxes Provision for income taxes Loss from continuing operations Loss from discontinued operations, net of tax Net loss Other comprehensive income — 912 — — 141 — — — 226,873 — 399,800 84,550 56,043 11,414 18,574 18,640 33,751 3,576 22,869 (1,056) 288,280 72,023 76,843 3,081 164 3,398 430 (3,576) 204,004 (11,990) (91,674) — — — — — — — (464,149) — (227,926) (154,733) (129,014) 464,149 11 72,139 (227,937) (226,872) — — (227,937) (226,872) 18,310 18,310 52,092 (181,106) (56,171) (237,277) 18,310 — 464,149 — 464,149 (36,620) 596,406 157,485 132,886 14,495 18,879 22,038 34,181 — (10,403) (13,046) (47,524) 124,242 (171,766) (56,171) (227,937) 18,310 Comprehensive loss attributable to Exterran stockholders $ (209,627) $ (208,562) $ (218,967) $ 427,529 $ (209,627) F-52 (86,064) (139,613) 35,108 (190,569) Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2018 (In thousands) Cash flows from operating activities: Net cash provided by (used in) continuing operations $ (494) $ 21,192 $ 132,598 $ — $ 153,296 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Net cash provided by discontinued operations Net cash provided by (used in) operating activities — (494) — 21,192 4,004 136,602 — — — — — 35,108 35,108 — 4,004 157,300 (215,108) 2,530 5,000 — (207,578) 17,009 — — (35,108) — — — — (35,108) — — — 585,014 (550,497) — (18,744) (4,801) 548 (4,623) 6,897 (3,841) (30,213) 49,691 19,478 Cash flows from investing activities: Capital expenditures Proceeds from sale of property, plant and equipment Proceeds from sale of business Intercompany transfers Net cash used in continuing operations Net cash provided by discontinued operations Net cash used in investing activities Cash flows from financing activities: Proceeds from borrowings of debt Repayments of debt Intercompany transfers Cash transfer to Archrock, Inc. Payments for debt issuance costs Proceeds from stock options exercised Purchases of treasury stock Net cash provided by financing activities — — — — — — — — — 143 — — — — 143 (91,027) (124,081) 106 5,000 (143) 2,424 — (34,965) (86,064) (156,622) — 17,009 585,014 (550,497) 34,965 (18,744) (4,801) 548 (4,623) 41,862 — — — — — — — — Effect of exchange rate changes on cash, cash equivalents and restricted cash Net decrease in cash, cash equivalents and restricted cash Cash, cash equivalents and restricted cash at beginning of period — (351) — (23,010) (3,841) (6,852) 397 24,195 25,099 Cash, cash equivalents and restricted cash at end of period $ 46 $ 1,185 $ 18,247 $ — $ F-53 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2017 (In thousands) Cash flows from operating activities: Net cash provided by (used in) continuing operations $ (476) $ 74,003 $ 76,893 $ — $ 150,420 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Net cash used in discontinued operations Net cash provided by (used in) operating activities — (476) — 74,003 (1,794) 75,099 (54,527) (77,146) 3,809 894 (742) (50,566) — (50,566) 501,088 (476,503) 16,267 (44,720) (7,911) 684 (4,792) (15,887) 5,057 — (16,267) (88,356) 19,575 (68,781) — — — — — — — — — 7,550 (792) 5,526 16,645 19,573 — — — — — 17,009 17,009 — (1,794) 148,626 (131,673) 8,866 894 — (121,913) 19,575 17,009 (102,338) — — (17,009) — — — — (17,009) — — — 501,088 (476,503) — (44,720) (7,911) 684 (4,792) (32,154) (792) 13,342 36,349 49,691 $ 24,195 $ 25,099 $ — $ Cash flows from investing activities: Capital expenditures Proceeds from sale of property, plant and equipment Proceeds from sale of business Intercompany transfers Net cash used in continuing operations Net cash provided by discontinued operations Net cash used in investing activities Cash flows from financing activities: Proceeds from borrowings of debt Repayments of debt Intercompany transfers Cash transfer to Archrock, Inc. Payments for debt issuance costs Proceeds from stock options exercised Purchases of treasury stock Net cash provided by (used in) financing activities Effect of exchange rate changes on cash, cash equivalents and restricted cash Net increase in cash, cash equivalents and restricted cash Cash, cash equivalents and restricted cash at beginning of period Cash, cash equivalents and restricted cash at end of period $ — — — — — — — — — 742 — — — — 742 — 266 131 397 F-54 Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 (In thousands) Cash flows from operating activities: Net cash provided by (used in) continuing operations $ (53) $ 84,164 $ 178,378 $ — $ 262,489 Parent Guarantor Issuers Non- Guarantor Subsidiaries Eliminations Consolidation Net cash provided by discontinued operations Net cash provided by (used in) operating activities — (53) — 84,164 1,016 179,394 Cash flows from investing activities: Capital expenditures Proceeds from sale of property, plant and equipment Intercompany transfers Return of investments in non-consolidated affiliates Settlement of foreign currency derivatives Net cash used in continuing operations Net cash provided by discontinued operations Net cash used in investing activities Cash flows from financing activities: Proceeds from borrowings of debt Repayments of debt Intercompany transfers Cash transfer to Archrock, Inc. Payments for debt issuance costs Proceeds from stock options exercised Purchases of treasury stock Net cash provided by (used in) financing activities Effect of exchange rate changes on cash, cash equivalents and restricted cash Net increase (decrease) in cash, cash equivalents and restricted cash Cash, cash equivalents and restricted cash at beginning of period — — — — — — — — — — 147 — — — — 147 — 94 37 — — — — (26,670) (47,000) 1,326 1,488 (147) — (709) (188,180) 188,327 10,403 — — — (26,038) (223,451) 188,327 — 36,079 — (26,038) (187,372) 188,327 430,758 (610,261) 188,180 (49,176) (779) 786 (2,091) (42,583) — — — — — — — — — — (188,327) — — — — — (1,832) 15,543 (9,810) 1,102 29,383 — — — 1,016 263,505 (73,670) 2,814 — 10,403 (709) (61,162) 36,079 (25,083) 430,758 (610,261) — (49,176) (779) 786 (2,091) (1,832) 5,827 30,522 36,349 (188,327) (230,763) Cash, cash equivalents and restricted cash at end of period $ 131 $ 16,645 $ 19,573 $ — $ F-55 Note 25. Subsequent Event On February 20, 2019, our board of directors approved a share repurchase program, under which the Company is authorized to purchase up to $100.0 million of its outstanding common stock through February 2022. F-56 EXTERRAN CORPORATION SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS (In thousands) Description Allowance for doubtful accounts deducted from accounts receivable in the balance sheets December 31, 2018 December 31, 2017 December 31, 2016 Allowance for obsolete and slow moving inventory deducted from inventories in the balance sheets December 31, 2018 December 31, 2017 December 31, 2016 Allowance for deferred tax assets not expected to be realized December 31, 2018 December 31, 2017 December 31, 2016 Balance at Beginning of Period Charged to Costs and Expenses Deductions Balance at End of Period $ 5,388 $ 5,383 2,868 $ 10,351 $ 12,877 14,486 86 863 2,972 87 1,276 756 $ 222,049 $ 276,230 142,960 12,648 4,343 144,852 $ $ $ $ $ — 858 (1) 457 (1) 392 (2) 3,802 (2) 2,365 (2) 5,474 5,388 5,383 10,046 10,351 12,877 34,592 (3) 58,524 (3) 11,582 (3) $ 200,105 222,049 276,230 (1) (2) (3) Uncollectible accounts written off. Obsolete inventory written off at cost, net of value received. Reflects expected realization of deferred tax assets and amounts credited to other accounts for stock-based compensation excess tax benefits, expiring net operating losses, changes in tax rates and changes in currency exchange rates. S-1 DIRECTORS Mark R. Sotir Executive Chairman of the Board Andrew J. Way President and Chief Executive Officer EXECUTIVE OFFICERS Andrew J. Way President and Chief Executive Officer William M. Goodyear Christopher T. Seaver James C. Gouin John P. Ryan Ieda Gomes Yell Valerie L. Banner Senior Vice President General Counsel and Corporate Secretary Girish K. Saligram Senior Vice President and Chief Operating Officer Mark R. Sotir Executive Chairman of the Board Roger George Senior Vice President Global Engineering and Product Lines PRINCIPAL ACCOUNTING OFFICER David A. Barta Senior Vice President and Chief Financial Officer Christine M. Michel Senior Vice President Global Human Resources and Communications Michael W. Sanders Vice President and Chief Accounting Officer CORPORATE INFORMATION Annual Meeting The 2019 Annual Meeting will be held April 25, 2019, jointly by tele-video conferencing at 9:00 a.m. Central Daylight Time at Baker McKenzie LLP, Bank of America Center, 700 Louisiana Street, Suite 3000, Houston, Texas, USA and at 11:00 a.m. Argentina Standard Time at Baker McKenzie LLP, Cecilia Grierson 255, 6th Floor, Buenos Aires, Argentina Stock Trading New York Stock Exchange symbol: EXTN Stockholder Information Website information on Exterran, Additional including filings, press securities releases, Code of Conduct, Corporate Governance Principles and Board Committee Charters is available on our website at www.exterran.com. 10-K/Investor Contact Stockholders may obtain a copy, without charge, of Exterran’s 2018 Form 10-K filed with the Securities and Exchange Commission, by visiting our website at www.exterran.com or by requesting a copy to or investor.relations@exterran.com Exterran’s Corporate Office, Attention: Investor Relations. in writing 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 2018 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 Exterran of NYSE Corporate Listing Standards. Governance Contact Board of Directors relevant To report a concern about Exterran’s internal controls or accounting, auditing matters, or any other matter, to the Audit Committee or non- management members of the Board of Directors, send a detailed note, to with Exterran’s Office, Attention: Mark R. Sotir, Executive Chairman of the Board, or leave a message at 1-800-281-5439 (U.S. and Canada), or 1-832-554-4859 (outside U.S. and Canada) request reverse charges. www.exterranethicshelpline.com documents, Corporate Transfer Agent and Registrar American Stock Transfer and Trust Company LLC 6201 15th Avenue Brooklyn, New York 11219 USA (800) 937-5449 or (718) 921-8124 CORPORATE AND NORTH AMERICA HEADQUARTERS Houston, Texas U.S.A. MIDDLE EAST AFRICA HEADQUARTERS Hamriyah, U.A.E. LATIN AMERICA HEADQUARTERS Buenos Aires, Argentina ASIA PACIFIC HEADQUARTERS Kuala Lumpur, Malaysia 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 2018 Form 10-K filed on February 27, 2019. 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 or otherwise. — — — A GLOBAL SYSTEMS AND PROCESS COMPANY — — — – oil – gas – water – power – Published March 2019  © 2019 Exterran Corporation all rights reserved  Printed on recycled paper 

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