10-K

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

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

For the fiscal year ended December 31, 2015

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 number: 001-35779

USA Compression Partners, LP

(Exact Name of Registrant as Specified in its Charter)

Delaware	75-2771546
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

100 Congress Avenue, Suite 450 Austin, TX	78701
(Address of Principal Executive Offices)	(Zip Code)

(512) 473-2662

(Registrant’s telephone number, including area code)

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

Title of each class	Name of each exchange on which registered
Common Units Representing Limited Partner Interests	New York Stock Exchange

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

None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.Yes☐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☒

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 90days.Yes☒No☐

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  Yes ☒    No ☐

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the 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.  ☒

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

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

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

The aggregate market value of common units held by non-affiliates of the registrant (treating directors and executive officers of the registrant’s general partner and holders of 5% or more of the common units outstanding, for this purpose, as if they were affiliates of the registrant) as of June 30, 2015, the last business day of the registrant’s most recently completed second fiscal quarter was $303,972,286. This calculation does not reflect a determination that such persons are affiliates for any other purpose.

As of February 9, 2016, there were 38,556,245 common units and 14,048,588 subordinated units outstanding.

DOCUMENTS INCORPORATED BY REFERENCE: NONE

Table of Contents

PART I			1
	Item 1.	Business	2
	Item 1A.	Risk Factors	14
	Item 1B.	Unresolved Staff Comments	35
	Item 2.	Properties	35
	Item 3.	Legal Proceedings	35
	Item 4.	Mine Safety Disclosures	35
PART II			35
	Item 5.	Market For Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	35
	Item 6.	Selected Financial Data	38
	Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	45
	Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	58
	Item 8.	Financial Statements and Supplementary Data	59
	Item 9.	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure	59
	Item 9A.	Controls and Procedures	59
	Item 9B.	Other Information	60
PART III			61
	Item 10.	Directors, Executive Officers and Corporate Governance	61
	Item 11.	Executive Compensation	66
	Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters	74
	Item 13.	Certain Relationships and Related Transactions, and Director Independence	77
	Item 14.	Principal Accountant Fees and Services	79
PART IV			80
	Item 15.	Exhibits and Financial Statement Schedules	80

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PART I

DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS

This report contains “forward-looking statements.” All statements other than statements of historical fact contained in this report are forward-looking statements, including, without limitation, statements regarding our plans, strategies, prospects and expectations concerning our business, results of operations and financial condition. You can identify many of these statements by looking for words such as “believe,” “expect,” “intend,” “project,” “anticipate,” “estimate,” “continue” or similar words or the negative thereof.

Known material factors that could cause our actual results to differ from those in these forward-looking statements are 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”). Important factors that could cause our actual results to differ materially from the expectations reflected in these forward-looking statements include, among other things:

· changes in general economic conditionsandchanges in economic conditions of the crude oil and natural gas industry specifically;

· competitive conditions in our industry;

· changes in the long-term supply of and demand for crude oil and natural gas;

· our ability to realize the anticipated benefits of acquisitions and to integrate the acquired assets with our existing fleet;

· actions taken by our customers, competitors and third-party operators;

· the deterioration of the financial condition of our customers;

· changes in the availability and cost of capital;

· operating hazards, natural disasters, weather-related delays, casualty losses and other matters beyond our control;

· the effects of existing and future laws and governmental regulations; and

· the effects of future litigation.

All forward-looking statements included in this report are based on information available to us on the date of this report and speak only as of 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 foregoing cautionary statements.

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ITEM 1.Business

References in this report to “USA Compression,” “we,” “our,” “us,” “the Partnership” or like terms refer to USA Compression Partners, LP and its wholly owned subsidiaries, including USA Compression Partners, LLC (“USAC Operating”) and USAC OpCo 2, LLC (“OpCo 2” and together with USAC Operating, the “Operating Subsidiaries”). References to our “general partner” refer to USA Compression GP, LLC. References to “USA Compression Holdings” refer to USA Compression Holdings, LLC, the owner of our general partner. References to “USAC Management” refer to USA Compression Management Services, LLC, a wholly owned subsidiary of our general partner.  References to “Riverstone” refer to Riverstone/Carlyle Global Energy and Power Fund IV, L.P., and affiliated entities, including Riverstone Holdings, LLC. References to “Argonaut” refer to Argonaut Private Equity, L.L.C. and, where applicable, related entities.

Overview

We are a growth-oriented Delaware limited partnership and we believe that we are one of the largest independent providers of compression services in the U.S. in terms of total compression fleet horsepower. We have been providing compression services since 1998 and completed our initial public offering in January 2013. As of December 31, 2015, we had 1,712,196 horsepower in our fleet and 15,400 horsepower on order for expected delivery during 2016.  We provide compression services to our customers primarily in connection with infrastructure applications, including both allowing for the processing and transportation of natural gas through the domestic pipeline system and enhancing crude oil production through artificial lift processes. As such, our compression services play a critical role in the production,  processing and transportation of both natural gas and crude oil.

We provide compression services in a number of shale plays throughout the U.S., including the Utica, Marcellus, Permian Basin, Delaware Basin, Eagle Ford, Mississippi Lime, Granite Wash, Woodford, Barnett, Haynesville, Niobrara and Fayetteville shales. The demand for our services is driven by the domestic production of natural gas and crude oil; as such, we have focused our activities in areas with attractive natural gas and crude oil production growth, which are generally found in these shale and unconventional resource plays.  According to recent studies promulgated by the Energy Information Agency (“EIA”), the production and transportation volumes in these shale plays are expected to increase over the long term due to the comparatively attractive economic returns versus returns achieved in many conventional basins. Furthermore, the changes in production volumes and pressures of shale plays over time require a wider range of compression services than in conventional basins. We believe the flexibility of our compression units positions us well to meet these changing operating conditions. While our business focuses largely on compression services serving infrastructure installations, including centralized natural gas gathering systems and processing facilities, which utilize large horsepower compression units, typically in shale plays, we also provide compression services in more matureconventional basins, including gas lift applicationson crude oil wells targeted by horizontal drilling techniques.  Gas lift and other artificial lift technologies are critical to the enhancement of production of oil from horizontal wells operating in tight shale plays. Gas lift is a process by which natural gas is injected into the production tubing of an existing producing well, thus reducing the hydrostatic pressure and allowing the oil to flow at a higher rate.

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

As part of our services, we engineer, design, operate, service and repair our compression units and maintain related support inventory and equipment. The compression units in our modern fleet are designed to be easily adaptable to fit our customers’ changing compression requirements. Focusing on the needs of our customers and providing them with

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reliable and flexible compression services in geographic areas of attractive growth helps us to generate stable cash flows for our unitholders.

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

We provide compression services to major oil companies and independent producers, processors, gatherers and transporters of natural gas and crude oil.  Regardless of the application for which our services are provided, our customers rely upon the availability of the equipment used to provide compression services and our expertise to help generate the maximum throughput of product, reduce fuel costs and minimize emissions. While we are currently focused on our existing service areas, our customers have compression demands in other areas of the U.S. in conjunction with their field development projects. We continually consider expansion of our areas of operation in the U.S. based upon the level of customer demand. Our modern, flexible fleet of compression units, which have been designed to be rapidly deployed and redeployed throughout the country, provides us with opportunities to expand into other areas with both new and existing customers. 

Our assets and operations are organized into a single reportable segment and are all located and conducted in the United States. See our consolidated financial statements, and the notes thereto, included elsewhere in this report for financial information on our operations and assets; such information is incorporated herein by reference.

Business Strategies

Our principal business objective is to increase the quarterly cash distributions that we pay to our unitholders over time while ensuring the ongoing stability and growth of our business. We expect to achieve this objective by executing on the following strategies:

· Capitalize on the increased need for natural gas compression in conventional and unconventional plays. We expect additional demand for compression services to result from the continuing shift of natural gas production to domestic shale plays as well as the declining production pressures of aging conventional basins. The EIA continues to expect overall natural gas production and transportation volumes, and in particular volumes from domestic shale plays, to increase over the long term. Furthermore, the changes in production volumes and pressures of shale plays over time require a wider range and increased level of compression services than in conventional basins. Additionally, while oil prices have decreased substantially, resulting in less new drilling activity, the EIA expects crude oil production in the economically attractive tight oil plays to continue due to the favorable economics of existing wells. As a result, the use of, and thus demand for, artificial lift techniques required in such production continues to be an attractive business for us. Our fleet of modern, flexible compression units is capable of being rapidly deployed and redeployed and designed to operate in multiple compression stages, which will enable us to capitalize on these opportunities both in emerging shale plays and conventional fields.

· Continue to execute on attractive organic growth opportunities. From 2005to 2015, we grew the horsepower in our fleet of compression units and our compression revenues at a compound annual growth rate of 21% and 26%, respectively, primarily through organic growth. We believe organic growth opportunities will continue to be our most attractive source of near-term growth, although we expect such organic growth will be reduced in 2016 compared to prior periods. We seek to achieve continued organic growth by (i) increasing our business with existing customers, (ii) obtaining new customers in our existing areas of operations and (iii) expanding our operations into new geographic areas.

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· Partner with customers who have significant compression needs. We actively seek to identify customers with meaningful acreage positions or significant infrastructure development in active and growing areas. We work with these customers to jointly develop long-term and adaptable solutions designed to optimize their lifecycle compression costs. We believe this is important in determining the overall economics of producing, gathering and transporting natural gas and crude oil. Our proactive and collaborative approach positions us to serve as our customers’ compression service provider of choice.

· Pursue accretive acquisition opportunities. While our principal growth strategy is to continue to grow organically, we may pursue accretive acquisition opportunities, including the acquisition of complementary businesses, participation in joint ventures or the purchase of compression units from existing or new customers in conjunction with providing compression services to them. We consider opportunities that (i) are in our existing geographic areas of operations or new, high-growth regions, (ii) meet internally established economic thresholds and (iii) may be financed on reasonable terms. For example in 2013, we completed the acquisition of assets and certain liabilities related to S&R Compression, LLC’s (“S&R”) business of providing gas lift compression services to third parties engaged in the exploration, production, gathering, processing, transportation or distribution of oil and gas (the “S&R Acquisition”).

· Focus on asset utilization.  We seek to actively manage our business in a manner that allows us to continue to achieve high utilization rates at attractive service rates while providing us with the most financial flexibility possible.  From time to time, we expect the crude oil and natural gas industry to be impacted by the cyclicality of commodity prices. During downturns in commodity prices, producers and midstream operators may reduce their capital spending, which in turn can hinder the demand for compression services. We have the ability, in response to industry conditions, to drastically and rapidly reduce our capital spending, which allows us to avoid financing organic growth with outside capital and aligns our capital spending with the demand for compression services. By reducing organic growth and avoiding new unit deliveries during downturns, we are able to conserve capital and instead focus on the deployment and re-deployment of our existing asset base. With higher utilization, we are better positioned to continue to generate attractive rates of return on our already-deployed capital.  

· Maintain financial flexibility. We intend to maintain financial flexibility to be able to take advantage of growth opportunities. Historically, we have utilized our cash flow from operations, borrowings under our revolving credit facility and issuances of equity securities to fund capital expenditures to expand our compression services business. This approach has allowed us to significantly grow our fleet and the amount of cash we generate, while maintaining our debt at levels we believe are manageable for our business. We believe the appropriate management of our financial position and the resulting access to capital positions us to take advantage of future growth opportunities as they arise.

Our Operations

Compression Services

We provide compression services for a monthly service fee. As part of our services, we engineer, design, operate, service and repair our fleet of compression units and maintain related support inventory and equipment. We have consistently provided average service run times at or above the levels required by our customers. In general, our team of field service technicians services only our compression fleet. In limited circumstances for established customers, we will agree to service third-party owned equipment. We do not own any compression fabrication facilities.

Our Compression Fleet

The fleet of compression units that we own and use to provide compression services consists of specially engineered compression units that utilize standardized components, principally engines manufactured by Caterpillar, Inc. and compressor frames and cylinders manufactured by Ariel Corporation. Our units can be rapidly and cost effectively modified for specific customer applications. Approximately 97% of our fleet horsepower as of December 31, 2015 was purchased new and the average age of our compression units was approximately four years. Our modern, standardized

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compression unit fleet is powered primarily by the Caterpillar 3400, 3500 and 3600 engine classes, which range from 401 to 4,735 horsepower per unit. These larger horsepower units, which we define as 400 horsepower per unit or greater, represented 80.4%  of our total fleet horsepower (including compression units on order) as of December 31, 2015. In addition, a portion of our fleet consists of smaller horsepower units ranging from 30 horsepower to 390 horsepower that are primarily used in gas lift applications. We believe the young age and overall composition of our compressor fleet results in fewer mechanical failures, lower fuel usage, and reduced environmental emissions.

The following table provides a summary of our compression units by horsepower as of December 31, 2015:

Unit Horsepower	Fleet Horsepower	Number of Units	Horsepower on Order (1)	Number of Units on Order	Total Horsepower	Number of Units	Percentage of Total Horsepower		Percentage of Total Units
Small horsepower
<400	338,988	2,149	-	-	338,988	2,149	19.6	%	65.9	%
Large horsepower
>400 and <1,000	167,189	296	-	-	167,189	296	9.7	%	9.1	%
>1,000	1,206,019	809	15,400	7	1,221,419	816	70.7	%	25.0	%
Total	1,712,196	3,254	15,400	7	1,727,596	3,261	100.0	%	100.0	%

(1) As of December 31, 2015, we had 15,400 horsepower on order for delivery during 2016.

The following table sets forth certain information regarding our compression fleet as of the dates and for the periods indicated:

	Year Ended						Percent
	December 31,						Change
Operating Data (unaudited):	2015		2014		2013		2015		2014
Fleet horsepower (at period end) (1)	1,712,196		1,549,020		1,202,374		10.5	%	28.8	%
Total available horsepower (at period end) (2)	1,712,196		1,623,400		1,278,829		5.5	%	26.9	%
Revenue generating horsepower (at period end) (3)	1,424,537		1,351,052		1,070,457		5.4	%	26.2	%
Average revenue generating horsepower (4)	1,408,689		1,200,851		902,168		17.3	%	33.1	%
Revenue generating compression units (at period end)	2,737		2,651		2,137		3.2	%	24.1	%
Average horsepower per revenue generating compression unit (5)	517		505		720		2.4	%	(29.9)	%
Horsepower utilization (6):
At period end	89.2	%	93.6	%	94.1	%	(4.7)	%	(0.5)	%
Average for the period (7)	90.5	%	94.0	%	93.8	%	(3.7)	%	0.2	%

(1) Fleet horsepower is horsepower for compression units that have been delivered to us (and excludes units on order). As of December 31, 2015, we had 15,400 horsepower on order for delivery during 2016.

(2) Total available horsepower is revenue generating horsepower under contract for which we are billing a customer, horsepower in our fleet that is under contract but is not yet generating revenue, horsepower not yet in our fleet that is under contract but not yet generating revenue and that is subject to a purchase order and idle horsepower. Total available horsepower excludes new horsepower on order for which we do not have a compression services contract.

(3) Revenue generating horsepower is horsepower under contract for which we are billing a customer.

(4) Calculated as the average of the month-end revenue generating horsepower for each of the months in the period.

(5) Calculated as the average of the month-end revenue generating horsepower per revenue generating compression unit for each of the months in the period.

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(6) Horsepower utilization is calculated as (i) the sum of (a) revenue generating horsepower, (b) horsepower in our fleet that is under contract, but is not yet generating revenue and (c) horsepower not yet in our fleet that is under contract not yet generating revenue and that is subject to a purchase order, divided by (ii) total available horsepower less idle horsepower that is under repair. Horsepower utilization based on revenue generating horsepower and fleet horsepower at each applicable period end was 83.2%,  87.2%and 89.0% for the years ended December 31, 2015, 2014and 2013, respectively.

(7) Calculated as the average utilization for the months in the period based on utilization at the end of each month in the period. Average horsepower utilization based on revenue generating horsepower and fleet horsepower was 85.1%, 87.3% and 87.3% for each year ended December 31, 2015, 2014, and 2013, respectively.

A growing number of our compression units contain electronic control systems that enable us to monitor the units remotely by satellite or other means to supplement our technicians’ on-site monitoring visits. We intend to continue to selectively add remote monitoring systems to our fleet during 2016 where beneficial from an operating and financial standpoint. All of our compression units are designed to automatically shut down if operating conditions deviate from a pre-determined range. While we retain the care, custody, ongoing maintenance and control of our compression units, we allow our customers, subject to a defined protocol, to start, stop, accelerate and slow down compression units in response to field conditions.

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

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

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

General Compression Service Contract Terms

The following discussion describes the material terms generally common to our compression service contracts. We generally have separate contracts for each distinct location for which we will provide compression services.

Term and termination. Our contracts typically have an initial term of between six months and five years, depending on the application and location of the compression unit. After the expiration of the applicable term, the contract continues on a month-to-month or longer basis until terminated by us or our customer upon notice as provided for in the applicable contract.  As of December 31, 2015,  approximately 39% of our compression services on a horsepower basis (and 43% on a revenue basis for the year ended December 31, 2015) were provided on a month-to-month basis to customers who continue to utilize our services following expiration of the primary term of their contracts with us.

Availability. Our contracts often provide a guarantee of specified availability. We define availability as the percentage of time in a given period that our compression services are being provided or are capable of being provided.

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Availability is reduced by instances of “down-time” that are attributable to anything other than events of force majeure or acts or failures to act by the customer. Down-time under our contracts usually begins when our services stop being provided or when we receive notice from the customer of the problem. Down-time due to scheduled maintenance is also excluded from our availability commitment. Our failure to meet a stated availability guarantee may result in a service fee credit to the customer. As a consequence of our availability guarantee, we are incentivized to perform predictive and preventive maintenance on our fleet as well as promptly respond to a problem to meet our contractual commitments and ensure our customers the compression availability on which their business and our service relationship are based. For service contracts that do not have a stated availability guarantee, we work with those customers to ensure that our compression services meet their operational needs.

Fees and expenses. Our customers pay a fixed monthly fee for our services. Compression services generally are billed monthly in advance of the service period, except for certain customers, which are billed at the beginning of the service month, and they are generally due 30 days from the date of the invoice. We are not responsible for acts of force majeure, and our customers generally are required to pay our monthly fee even during periods of limited or disrupted throughput. We are generally responsible for the costs and expenses associated with operation and maintenance of our compression equipment, although certain fees and expenses are the responsibility of our customers under the terms of their contracts. For example, all fuel gas is provided by our customers without cost to us, and in many cases customers are required to provide all water and electricity. At the customer’s option, we can provide fluids necessary to run the unit to the customer for an additional fee.  We provide such fluids for a substantial majority of the compression units deployed in gas lift applications. We are also reimbursed by our customers for certain ancillary expenses such as trucking and crane operation, depending on the terms agreed to in the applicable contract, resulting in little to no gross operating margin.

Service standards and specifications. We commit to provide compression services under service contracts that typically provide that we will supply all compression equipment, tools, parts, field service support and engineering in order to meet our customers’ requirements. Our contracts do not specify the specific compression equipment we will use; instead, in consultation with the customer, we determine what equipment is necessary to perform our contractual commitments.

Title; Risk of loss. We own all of the compression equipment in our fleet that we use to provide compression services, and we normally bear the risk of loss or damage to our equipment and tools and injury or death to our personnel.

Insurance. Our contracts typically provide that both we and our customers are required to carry general liability, workers’ compensation, employers’ liability, automobile and excess liability insurance.

Marketing and Sales

Our marketing and client service functions are performed on a coordinated basis by our sales team and field technicians. Salespeople and field technicians qualify, analyze and scope new compression applications as well as regularly visit our customers to ensure customer satisfaction, to determine a customer’s needs related to existing services being provided and to determine the customer’s future compression service requirements. This ongoing communication allows us to quickly identify and respond to our customers’ compression requirements. We currently focus on geographic areas where we can achieve economies of scale through high-density operations.

Customers

Our customers consist of more than 250 companies in the energy industry, including major integrated oil companies, public and private independent exploration and production companies and midstream companies. We did not have revenue from any single customer greater than 10% of total revenue for the year ended December 31, 2015.  Southwestern Energy Corporation and its subsidiaries accounted for 11.6% of our revenue for the year ended December 31, 2014.  No other customer accounted for greater than 10% of total revenue for the year ended December 31, 2014.  Our ten largest customersaccounted for 45% and 46% of our revenue for the years ended December 31, 2015 and 2014, respectively.

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Suppliers and Service Providers

The principal manufacturers of components for our natural gas compression equipment include Caterpillar, Inc., Cummins Inc., and Arrow Engine Company for engines, Air-X-Changers and Air Cooled Exchangers for coolers, and Ariel Corporation, GE Oil & Gas Gemini products and Arrow Engine Company for compressor frames and cylinders. We also rely primarily on four vendors, A G Equipment Company, Alegacy Equipment, LLC, Standard Equipment Corp. and S&R, to package and assemble our compression units. Although we rely primarily on these suppliers, we believe alternative sources for natural gas compression equipment are generally available if needed. However, relying on alternative sources may increase our costs and change the standardized nature of our fleet. We have not experienced any material supply problems to date. Although lead-times for new Caterpillar engines and new Ariel compressor frames have in the past been in excess of one year due to increased demand and supply allocations imposed on equipment packagers and end-users, lead-times for such engines and frames are currently substantially shorter. Please read Part I, Item 1A (“Risk Factors—Risks Related to Our Business—We depend on a limited number of suppliers and are vulnerable to product shortages and price increases, which could have a negative impact on our results of operations”).

Competition

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

Seasonality

Our results of operations have not historically reflected any material seasonality, and we do not currently have reason to believe seasonal fluctuations will have a material impact in the foreseeable future.

Insurance

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

Environmental and Safety Regulations

We are subject to stringent and complex federal, state and local laws and regulations governing the discharge of materials into the environment or otherwise relating to protection of human health, safety and the environment. These regulations include compliance obligations for air emissions, water quality, wastewater discharges and solid and hazardous waste disposal, as well as regulations designed for the protection of human health and safety and threatened or

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endangered species. Compliance with these environmental laws and regulations may expose us to significant costs and liabilities and cause us to incur significant capital expenditures in our operations. We are often obligated to assist customers in obtaining permits or approvals in our operations from various federal, state and local authorities. Permits and approvals can be denied or delayed, which may cause us to lose potential and current customers, interrupt our operations and limit our growth and revenue. Moreover, failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of remedial obligations and the issuance of injunctions delaying or prohibiting operations. Private parties may also have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage. While we believe that our operations are in substantial compliance with applicable environmental laws and regulations and that continued compliance with current requirements would not have a material adverse effect on us, there is no assurance that this trend of compliance will continue in the future. In addition, the clear trend in environmental regulation is to place more restrictions on activities that may adversely affect the environment.  Thus, any changes in, or more stringent enforcement of, these laws and regulations that result in more stringent and costly pollution control equipment, waste handling, storage, transport, disposal or remediation requirements could have a material adverse effect on our operations and financial position.

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

Air emissions. The Clean Air Act (“CAA”) and comparable state laws regulate emissions of air pollutants from various industrial sources, including natural gas compressors, and impose certain monitoring and reporting requirements. Such emissions are regulated by air emissions permits, which are applied for and obtained through the various state or federal regulatory agencies. Our standard natural gas compression contract provides that the customer is responsible for obtaining air emissions permits and assuming the environmental risks related to site operations. Increased obligations of operators to reduce air emissions of nitrogen oxides and other pollutants from internal combustion engines in transmission service have been enacted by governmental authorities. For example, in 2010, the U.S. Environmental Protection Agency (“EPA”) published new regulations under the CAA to control emissions of hazardous air pollutants from existing stationary reciprocal internal combustion engines, also known as Quad Z regulations. In 2012, the EPA proposed amendments to the final rule in response to several petitions for reconsideration, which were finalized and became effective in 2013. The rule requires us to undertake certain expenditures and activities, including purchasing and installing emissions control equipment on certain compressor engines and generators.

In 2012, the EPA proposed minor amendments to the CAA regulations applicable to the manufacturers, owners and operators of new, modified and reconstructed stationary reciprocating internal combustion engines, also known as Quad J regulations, in order to conform the final rule to the amendments to the Quad Z regulations discussed above. These amendments were finalized and became effective in 2013.These modifications do not impose material unbudgeted costs on operations.

On October 26, 2015, the EPA published the finalized rule strengthening the National Ambient Air Quality Standard (“NAAQs”) for ground level ozone. The rule became effective on December 28, 2015. The final rule updates both the primary ozone standard and the secondary standard. Both standards are 8-hour concentration standards of 70 parts per billion (“ppb”). In addition, in 2013, the EPA promulgated a final rule revising the annual standard for fine particulate matter, or PM 2.5, by lowering the level from 15 to 12 micrograms per cubic meter. On December 18, 2014, the EPA issued final area designations for the 2012 NAAQs for PM 2.5. Designation of new non-attainment areas for the revised ozone or PM 2.5 NAAQS may result in additional federal and state regulatory actions that may impact our customers’ operations and increase the cost of additions to property, plant, and equipment.

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In 2012, the EPA finalized rules that establish new air emission controls for oil and natural gas production and natural gas processing operations. Specifically, the EPA’s rule package included New Source Performance Standards to address emissions of sulfur dioxide and volatile organic compounds (“VOCs”) and a separate set of emission standards to address hazardous air pollutants frequently associated with oil and natural gas production and processing activities. The rules established specific new requirements regarding emissions from compressors and controllers at natural gas processing plants, dehydrators, storage tanks and other production equipment as well as the first federal air standards for natural gas wells that are hydraulically fractured. In addition, the rules established leak detection requirements for natural gas processing plants at 500 ppm. In 2013, the EPA issued a final update to the VOC performance standards for storage tanks used in crude oil and natural gas production and transmission. On July 31, 2015, the EPA finalized amendments to the definition of low-pressure wells and references to tanks connected to one another in the 2012 New Source Performance Standards. On August 18, 2015, the EPA also proposed updates to the New Source Performance Standards and Draft Control Techniques Guidelines in addition to proposing a Source Determination Rule, all of which are intended to cut methane and VOC emissions from the oil and natural gas industry. These rules may require a number of modifications to our operations, including the installation of new equipment to control emissions from our compressors at initial startup. Compliance with such rules may result in significant costs, including increased capital expenditures and operating costs, and could adversely impact our business.

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

A ruling by a panel of administrative law judges in a case before the Pennsylvania Environmental Hearing Board, to which we are not a party, may have implications for the permitting of projects where our customers seek to use our services. In this case, National Fuel Gas Midstream Corporation et al. v. Commonwealth of Pennsylvania, a panel of administrative law judges on December 29, 2015, dismissed an appeal from a determination by the Pennsylvania Department of Environmental Protection that the operations of two separate companies on parcels of land that were not adjoining and were actually separated by forest land but were in close proximity should be aggregated as a single source under the state air permitting regime. The implications of aggregating different sources into a single source is that the overall emissions increase and may increase enough to trigger a more onerous permitting regime and require more stringent controls. The court determined that this outcome was appropriate because, among other reasons, the two companies were owned by a common parent and had several interlocking officers and directors. But it was unclear whether the common parent in fact exercised control over the two companies’ operations. Unless this ruling is overturned on further appeal, application of this ruling to other permit applications where the parties intend to use our services may lead to a permitting regime that is more burdensome, time-consuming and costly to our customers, who typically obtain permits. Moreover, we may be required to install lower emission engines or additional pollution controls and may not be able to recoup all of the associated costs from our customers.

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

Climate change. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are examples of greenhouse gases. In recent years, the U.S. Congress has considered legislation to reduce emissions of greenhouse gases. It presently appears unlikely that comprehensive climate legislation will be passed by either house of Congress in the near future, although energy legislation and other initiatives are expected to be proposed that may be relevant to greenhouse gas emissions issues. However, almost half of the states have begun to address greenhouse gas emissions, primarily through the planned development of emission inventories or regional greenhouse

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gas cap and trade programs. Depending on the particular program, we could be required to control greenhouse gas emissions or to purchase and surrender allowances for greenhouse gas emissions resulting from our operations.

Independent of Congress, the EPA is beginning to adopt regulations controlling greenhouse gas emissions under its existing CAA authority. For example, on December 15, 2009, the EPA officially published its findings that emissions of carbon dioxide, methane and other greenhouse gases endanger human health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. These findings by the EPA allowed the agency to proceed with the adoption and implementation of regulations that restrict emissions of greenhouse gases under existing provisions of the CAA. In 2009, the EPA adopted rules regarding regulation of greenhouse emissions from motor vehicles. In addition, on September 22, 2009, the EPA issued a final rule requiring the reporting of greenhouse gas emissions in the United States beginning in 2011 for emissions occurring in 2010 from specified large greenhouse gas emission sources. On November 30, 2010, the EPA published a final rule expanding its existing greenhouse gas emissions reporting rule for petroleum and natural gas facilities, including natural gas transmission compression facilities that emit 25,000 metric tons or more of carbon dioxide equivalent per year. The rule, which went into effect on December 30, 2010, requires reporting of greenhouse gas emissions by such regulated facilities to the EPA by September 2012 for emissions during 2011 and annually thereafter. In 2010, the EPA also issued a final rule, known as the “Tailoring Rule,” that made certain large stationary sources and modification projects subject to permitting requirements for greenhouse gas emissions under the CAA.

Both the Tailoring Rule and the EPA’s endangerment finding were challenged in federal court and were upheld by the D.C. Court of Appeals.  In July 2014, the United States Supreme Court invalidated the Tailoring Rule but it refused to consider other issues such as whether greenhouse gases endanger public health. As a result, under federal law, a source is no longer required to meet the PSD and Title V permitting requirements based solely on its greenhouse gas emissions.

The EPA has also sought to directly regulate methane emissions by proposing regulations to expand on Subpart OOOO of the CAA and target methane emissions from new and modified sources, including hydraulically fractured wells. If the final rule is promulgated along the lines of the proposal, these requirements may add to our costs of doing business and we may not be able to recoup all of these costs from our customers.

On August 3, 2015, the EPA published standards of performance for greenhouse gas emissions from new power plants. The final rule establishes a performance standard for integrated gasification combined cycled units and utility boilers based on the use of the best system of emission reduction that EPA has determined has been adequately demonstrated for each type of unit. The rule also sets limits for stationary natural gas combustion turbines based on the use of natural gas combined cycle technology.

Finally, on June 2, 2014, the EPA proposed the Clean Power Plan rule, which is intended to reduce carbon emissions from existing power plants by 32 percent from 2005 levels by 2030. Twenty-nine states and various industry groups have challenged the EPA’s authority to regulate carbon dioxide emissions from existing coal-fired power plants under Section 111(d) of the Clean Air Act in the United States Court of Appeals in Washington, D.C. (the “Circuit Court”).  In January 2016, the parties asked the United States Supreme Court to stay the plan while the lawsuit proceeds through the court appeals. On February 9, 2016, the U.S. Supreme Court granted a stay of the implementation of the Clean Power Plan before the Circuit Court even issued a decision.  By its terms, this stay will remain in effect throughout the pendency of the appeals process including at the Circuit Court and the Supreme Court through any certiorari petition that may be granted.  The stay suspends the rule, including the requirement that states must start submitting implementation plans by 2018.  It is not yet clear how the either the Circuit Court or the Supreme Court will ultimately rule on the legality of the Clean Power Plan. 

In addition to the EPA, the Bureau of Land Management (“BLM”) also promulgated rules to regulate hydraulic fracturing.  The BLM rule establishes new requirements relating to well construction, water management, and chemical disclosure for companies drilling on federal and tribal land. This rule has been challenged in the District of Wyoming. The District Court issued a preliminary ruling enjoining enforcement of the BLM rule and holding that the agency lacked authority to regulate hydraulic fracturing. Environmental groups have appealed this ruling to the Court of Appeals for the Tenth Circuit.  The case is likely to be heard in 2016.

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Although it is not currently possible to predict with specificity how any proposed or future greenhouse gas legislation or regulation will impact our business, any legislation or regulation of greenhouse gas emissions that may be imposed in areas in which we conduct business could result in increased compliance costs or additional operating restrictions or reduced demand for our services, and could have a material adverse effect on our business, financial condition and results of operations.

Water discharge. The Clean Water Act (“CWA”) and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. The CWA and regulations implemented thereunder also prohibit the discharge of dredge and fill material into regulated waters, including jurisdictional wetlands, unless authorized by an appropriately issued permit. The CWA also requires the development and implementation of spill prevention, control and countermeasures, including the construction and maintenance of containment berms and similar structures, if required, to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak at such facilities. In addition, the CWA and analogous state laws require individual permits or coverage under general permits for discharges of storm water runoff from certain types of facilities. Federal and state regulatory agencies can impose administrative, civil and criminal penalties as well as other enforcement mechanisms for non-compliance with discharge permits or other requirements of the CWA and analogous state laws and regulations. Our compression operations do not generate process wastewaters that are discharged to waters of the U.S. In any event, our customers assume responsibility under the majority of our standard natural gas compression contracts for obtaining any discharge permits that may be required under the CWA.

Safe Drinking Water Act. A significant portion of our customers’ natural gas production is developed from unconventional sources that require hydraulic fracturing as part of the completion process. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into the formation to stimulate gas production. Legislation to amend the Safe Drinking Water Act (“SDWA”) to repeal the exemption for hydraulic fracturing from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, have been proposed and the U.S. Congress continues to consider legislation to amend the Safe Drinking Water Act. Scrutiny of hydraulic fracturing activities continues in other ways, with the EPA having commenced a multi-year study of the potential environmental impacts of hydraulic fracturing, preliminary results of which were released for public comment in June 2015, which stated that EPA had not found evidence of widespread, systemic impacts on drinking water resources from hydraulic fracturing operations. This report has not yet been finalized, and the EPA’s ultimate conclusions may be impacted by recent comments from the EPA’s Science Advisory Board regarding the sufficiency of the data underlying some of the EPA’s conclusions.  The EPA also has announced that it believes hydraulic fracturing using fluids containing diesel fuel can be regulated under the SDWA notwithstanding the SDWA’s general exemption for hydraulic fracturing. Several states have also proposed or adopted legislative or regulatory restrictions on hydraulic fracturing, including prohibitions on the practice. We cannot predict the future of such legislation and what additional, if any, provisions would be included. If additional levels of regulation, restrictions and permits were required through the adoption of new laws and regulations at the federal or state level or the development of new interpretations of those requirements by the agencies that issue the permits, that could lead to delays, increased operating costs and process prohibitions that could reduce demand for our compression services, which would materially adversely affect our revenue and results of operations.

Solid waste. The Resource Conservation and Recovery Act (“RCRA”) and comparable state laws control the management and disposal of hazardous and non-hazardous waste. These laws and regulations govern the generation, storage, treatment, transfer and disposal of wastes that we generate including, but not limited to, used oil, antifreeze, filters, sludges, paint, solvents and sandblast materials. The EPA and various state agencies have limited the approved methods of disposal for these types of wastes.

Site remediation. The Comprehensive Environmental Response Compensation and Liability Act (“CERCLA”) and comparable state laws impose strict, joint and several liability without regard to fault or the legality of the original conduct on certain classes of persons that contributed to the release of a hazardous substance into the environment. These

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persons include the owner and operator of a disposal site where a hazardous substance release occurred and any company that transported, disposed of or arranged for the transport or disposal of hazardous substances released at the site. Under CERCLA, such persons may be liable for the costs of remediating the hazardous substances that have been released into the environment, for damages to natural resources, and for the costs of certain health studies. In addition, where contamination may be present, it is not uncommon for the neighboring landowners and other third parties to file claims for personal injury, property damage and recovery of response costs. While we generate materials in the course of our operations that may be regulated as hazardous substances, we have not received notification that we may be potentially responsible for cleanup costs under CERCLA at any site.

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

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

Employees

USAC Management, a wholly owned subsidiary of our general partner, performs certain management and other administrative services for us, such as accounting, corporate development, finance and legal.  All of our employees, including our executive officers, are employees of USAC Management. As of December 31, 2015, USAC Management had 478 full time employees. None of our employees are subject to collective bargaining agreements. We consider our employee relations to be good.

Available Information

Our website address is usacompression.com. We make available, free of charge at the “Investor Relations” portion of our website, our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and all amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), as soon as reasonably practicable after such reports are electronically filed with, or furnished to, the SEC. The information contained on our website does not constitute part of this report.

The SEC maintains a website that contains these reports at sec.gov. Any materials we file with the SEC also may be read or copied at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. Information concerning the operation of the Public Reference Room may be obtained by calling the SEC at (800) 732-0330.

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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. If any of the following risks were to occur, our business, financial condition or results of operations could be materially and adversely affected. In that case, we might not be able to pay our minimum quarterly distribution on our common units or grow such distributions and the trading price of our common units could decline.Although the risk factors described below discuss potential risks and factors related to our outstanding subordinated units, all of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.

Risks Related to Our Business

We may not have sufficient cash from operations following the establishment of cash reserves and payment of fees and expenses, including cost reimbursements to our general partner, to enable us make cash distributions at our current distribution rate to our unitholders.

In order to make cash distributions at our current distribution rate of $0.525 per unit per quarter, or $2.10 per unit per year, we will require available cash of $28.0 million per quarter, or $112.1 million per year, based on the number of common units, subordinated units and the 1.46% general partner interest outstanding as ofFebruary 9, 2016. Under our cash distribution policy, the amount of cash we can distribute to our unitholders principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:

· the level of production of, demand for, and price of natural gas and crude oil, particularly the level of production in the locations where we provide compression services;

· the fees we charge, and the margins we realize, from our compression services;

· the cost of achieving organic growth in current and new markets;

· the level of competition from other companies; and

· prevailing global and regional economic and regulatory conditions, and their impact on us and our customers.

In addition, the actual amount of cash we will have available for distribution will depend on other factors, including:

· the levels of our maintenance capital expenditures and expansion capital expenditures;

· the level of our operating costs and expenses;

· our debt service requirements and other liabilities;

· fluctuations in our working capital needs;

· restrictions contained in our revolving credit facility;

· the cost of acquisitions;

· fluctuations in interest rates;

· the financial condition of our customers;

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· our ability to borrow funds and access the capital markets; and

· the amount of cash reserves established by our general partner.

A long-term reduction in the demand for, or production of, natural gas or crude oil in the locations where we operate could adversely affect the demand for our services or the prices we charge for our services, which could result in a decrease in our revenues and cash available for distribution to unitholders.

The demand for our compression services depends upon the continued demand for, and production of, natural gas and crude oil. Demand may be affected by, among other factors, natural gas prices, crude oil prices, weather, availability of alternative energy sources, governmental regulation and general demand for energy. Any prolonged, substantial reduction in the demand for natural gas or crude oil would likely depress the level of production activity and result in a decline in the demand for our compression services, which could result in a reduction in our revenues and our cash available for distribution.

In particular, lower natural gas or crude oil prices over the long term could result in a decline in the production of natural gas or crude oil, respectively, resulting in reduced demand for our compression services. For example, the North American rig count, as measured by Baker Hughes, hit a 2014 peak of 1,931 rigs on September 12, 2014, and at that time, Henry Hub natural gas spot prices were $3.82 per MMBtu and West Texas Intermediate (“WTI”) crude oil spot prices were $92.18 per barrel. By December 31, 2014, Henry Hub natural gas prices had decreased by 18% while WTI crude prices decreased by 42%; however the total rig count only decreased by 6% to 1,811 rigs. Over the course of the year ended December 31, 2015, commodity prices deteriorated further (natural gas prices and crude oil prices were 27% and 31% lower than at December 31, 2014, respectively). This continued decline in commodity prices had a more pronounced effect on drilling activity levels, as the total rig count decreased 61% to a total of 698 rigs over the same time period.  As a result of the slowdown in new drilling activity in certain operating areas, as well as slowing or flattening of production growth in other areas, we expect to see and are experiencing pressure on service rates for new and existing services and a decline in utilization relative to the recent past. In addition, a small portion of our fleet is used in connection with crude oil production using horizontal drilling techniques.  Given the more pronounced decrease in the price of crude oil, we have also experienced pressure on service rates from our customers in gas lift applications, and expect that this trend could continue if prices remain depressed and activity levels remain low.

Additionally, an increasing percentage of natural gas and crude oil production comes from unconventional sources, such as shales, tight sands and coalbeds. Such sources can be less economically feasible to produce in low commodity price environments, in part due to costs related to compression requirements, and a reduction in demand for natural gas or gas lift for crude oil may cause such sources of natural gas or crude oil to be uneconomic to drill and produce, which could in turn negatively impact the demand for our services. Further, if demand for our services decreases, we may be asked to renegotiate our service contracts at lower rates. In addition, governmental regulation and tax policy may impact the demand for natural gas or crude oil or impact the economic feasibility of development of new fields or production of existing fields, which are important components of our ability to expand.

We have several key customers. The loss of any of these customers would result in a decrease in our revenues and cash available for distribution.

We provide compression services under contracts with several key customers. The loss of one of these key customers may have a greater effect on our financial results than for a company with a more diverse customer base. We did not have revenue from any single customer greater than 10% of total revenue for the year ended December 31, 2015. Southwestern Energy Corporation and its subsidiaries accounted for 11.6% of our revenue for the year ended December 31, 2014.  No other customer accounted for greater than 10% of total revenue for the year ended December 31, 2014.  Our ten largest customersaccounted for 45% and 46% of our revenue for the years ended December 31, 2015 and 2014, respectively.The loss of all or even a portion of the compression services we provide to our key customers, as a result of competition or otherwise, could have a material adverse effect on our business, results of operations, financial condition and cash available for distribution.

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The deterioration of the financial condition of our customers could adversely affect our business.

During times when the natural gas or crude oil markets weaken, our customers are more likely to experience financial difficulties, including being unable to access debt or equity financing, which could result in a reduction in our customers’ spending for our services. For example, our customers could seek to preserve capital by using lower cost providers, not renewing month-to-month contracts or determining not to enter into any new compression service contracts. The significant decline in commodity prices has caused many of our customers to reconsider near-term capital budgets, which may impact large-scale natural gas infrastructure and crude oil production activities. We expect the drop in commodity prices will cause a  delay or cancellation of some customers’ projects.Reduced demand for our services could adversely affect our business, results of operations, financial condition and cash flows. In addition, in the course of our business we hold accounts receivable from our customers.  In the event that any such customer was to enter into bankruptcy, we could lose all or a portion of such outstanding accounts receivable associated with that customer.  Further, if a customer was to enter into bankruptcy, it could also result in the cancellation of all or a portion of our service contracts with such customer at significant expense to us.

We face significant competition that may cause us to lose market share and reduce our cash available for distribution.

The compression business is highly competitive. Some of our competitors have a broader geographic scope, as well as greater financial and other resources than we do. Our ability to renew or replace existing contracts with our customers at rates sufficient to maintain current revenue and cash flows could be adversely affected by the activities of our competitors and our customers. If our competitors substantially increase the resources they devote to the development and marketing of competitive services or substantially decrease the prices at which they offer their services, we may be unable to compete effectively. Some of these competitors may expand or construct newer, more powerful or more flexible compression fleets that would create additional competition for us. All of these competitive pressures could have a material adverse effect on our business, results of operations, financial condition and reduce our cash available for distribution.

Our customers may choose to vertically integrate their operations by purchasing and operating their own compression fleet, expanding the amount of compression units they currently own or using alternative technologies for enhancing crude oil production.

Our customers that are significant producers, processors, gatherers and transporters of natural gas and crude oil may choose to vertically integrate their operations by purchasing and operating their own compression fleets in lieu of using our compression services. The historical availability of attractive financing terms from financial institutions and equipment manufacturers facilitates this possibility by making the purchase of individual compression units increasingly affordable to our customers. In addition, there are many technologies available for the artificial enhancement of crude oil production, and our customers may elect to use these alternative technologies instead of the gas lift compression services we provide. Such vertical integration, increases in vertical integration or use of alternative technologies could result in decreased demand for our compression services, which may have a material adverse effect on our business, results of operations, financial condition and reduce our cash available for distribution.

A significant portion of our services are provided to customers on a month-to-month basis, and we cannot be sure that such customers will continue to utilize our services.

Our contracts typically have an initial term of between six months and five years, depending on the application and location of the compression unit. After the expiration of the applicable term, the contract continues on a month-to-month or longer basis until terminated by us or our customers upon notice as provided for in the applicable contract. As of December 31, 2015,  approximately 39% of our compression services on a horsepower basis (and 43% on a revenue basis for the year ended December 31, 2015) were provided on a month-to-month basis to customers who continue to utilize our services following expiration of the primary term of their contracts with us. These customers can generally terminate their month-to-month compression services contracts on 30-days’ written notice. If a significant number of these customers were to terminate their month-to-month services, or attempt to renegotiate their month-to-month contracts at substantially lower rates, it could have a material adverse effect on our business, results of operations, financial condition and cash available for distribution.

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We may be unable to grow our cash flows if we are unable to expand our business, which could limit our ability to maintain or increase distributions to our unitholders.

A principal focus of our strategy is to continue to grow the per unit distribution on our units by expanding our business over time. Our future growth will depend upon a number of factors, some of which we cannot control. These factors include our ability to:

· develop new business and enter into service contracts with new customers;

· retain our existing customers and maintain or expand the services we provide them;

· maintain or increase the fees we charge, and the margins we realize, from our compression services;

· recruit and train qualified personnel and retain valued employees;

· expand our geographic presence;

· effectively manage our costs and expenses, including costs and expenses related to growth;

· consummate accretive acquisitions;

· obtain required debt or equity financing on favorable terms for our existing and new operations; and

· meet customer specific contract requirements or pre-qualifications.

If we do not achieve our expected growth, we may not be able to maintain or increase distributions to our unitholders, in which event the market price of our units will likely decline materially.

We may be unable to grow successfully through acquisitions, and we may not be able to integrate effectively the businesses we may acquire, which may impact our operations and limit our ability to increase distributions to our unitholders.

From time to time, we may choose to make business acquisitions to pursue market opportunities, increase our existing capabilities and expand into new areas of operations. While we have reviewed acquisition opportunities in the past and will continue to do so in the future, we may not be able to identify attractive acquisition opportunities or successfully acquire identified targets. In addition, we may not be successful in integrating any future acquisitions into our existing operations, which may result in unforeseen operational difficulties or diminished financial performance or require a disproportionate amount of our management’s attention. Even if we are successful in integrating future acquisitions into our existing operations, we may not derive the benefits, such as operational or administrative synergies, that we expected from such acquisitions, which may result in the commitment of our capital resources without the expected returns on such capital. Furthermore, competition for acquisition opportunities may escalate, increasing our cost of making acquisitions or causing us to refrain from making acquisitions. Our inability to make acquisitions, or to integrate acquisitions successfully into our existing operations, may adversely impact our operations and limit our ability to increase distributions to our unitholders.

Our ability to grow in the future is dependent on our ability to access external expansion capital.

Our partnership agreement requires us to distribute to our unitholders all of our available cash, which excludes prudent operating reserves. We expect that we will rely primarily upon cash generated by operating activities and, where necessary, borrowings under our revolving credit facility and the issuance of debt and equity securities, to fund expansion capital expenditures. However, we may not be able to obtain equity or debt financing on terms favorable to us, or at all. To the extent we are unable to efficiently finance growth externally, our ability to increase distributions to our unitholders could be significantly impaired. In addition, because we distribute all of our available cash, which excludes prudent operating reserves, we may not grow as quickly as businesses that reinvest their available cash to expand ongoing operations. To the extent we issue additional units in connection with other expansion capital expenditures, the payment of distributions on those additional units may increase the risk that we will be unable to maintain or increase our per unit distribution level. There are no limitations in our partnership agreement on our ability to issue additional units,

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including units ranking senior to the common units. Similarly, the incurrence of borrowings or other debt by us to finance our growth strategy would result in interest expense, which in turn would affect our cash available for distribution.

Our debt levels may limit our flexibility in obtaining additional financing, pursuing other business opportunities and paying distributions.

We have a $1.1 billion revolving credit facility that matures in January 2020. In addition, we have the option to increase the amount of total commitments under the revolving credit facility by $200 million, subject to receipt of lender commitments and satisfaction of other conditions. As of December 31, 2015, we had outstanding borrowings of$729.2 million with a leverage ratio of 4.8x, borrowing base availability (based on our borrowing base) of $370.8 million and, subject to compliance with the applicable financial covenants, available borrowing capacity under the revolving credit facility of $101.0 million. Financial covenants permit a maximum leverage ratio of 5.50 to 1.0 through the end of the fiscal quarter ending June 30, 2016 and 5.00 to 1.0 thereafter.  As of February 9, 2016, we had outstanding borrowings of $740.2 million. 

Our ability to incur additional debt is subject to limitations in our revolving credit facility, including certain financial covenants. Our level of debt could have important consequences to us, including the following:

· our ability to obtain additional financing, if necessary, for working capital, capital expenditures, acquisitions or other purposes may not be available or such financing may not be available on favorable terms;

· we will need a portion of our cash flow to make payments on our indebtedness, reducing the funds that would otherwise be available for operating activities, future business opportunities and distributions; and

· our debt level will make us more vulnerable, than our competitors with less debt, to competitive pressures or a downturn in our business or the economy generally.

Our ability to service our debt will depend upon, among other things, our future financial and operating performance, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, some of which are beyond our control. In addition, our ability to service our debt under the revolving credit facility could be impacted by market interest rates, as all of our outstanding borrowings are subject to interest rates that fluctuate with movements in interest rate markets. A substantial increase in the interest rates applicable to our outstanding borrowings could have a material impact on our cash available for distribution. If our operating results are not sufficient to service our current or future indebtedness, we could be forced to take actions such as reducing distributions, reducing or delaying our business activities, acquisitions, investments or capital expenditures, selling assets, restructuring or refinancing our debt or seeking additional equity capital. We may be unable to effect any of these actions on terms satisfactory to us, or at all.

Restrictions in our revolving credit facility may limit our ability to make distributions to our unitholders and may limit our ability to capitalize on acquisition and other business opportunities.

The operating and financial restrictions and covenants in our revolving credit facility and any future financing agreements could restrict our ability to finance future operations or capital needs or to expand or pursue our business activities. Our revolving credit facility restricts or limits our ability (subject to exceptions) to:

· grant liens;

· make certain loans or investments;

· incur additional indebtedness or guarantee other indebtedness;

· enter into transactions with affiliates;

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· merge or consolidate;

· sell our assets; or

· make certain acquisitions.

Furthermore, our revolving credit facility contains certain operating and financial covenants. Our ability to comply with these covenants and restrictions may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our ability to comply with these covenants may be impaired. If we violate any of the restrictions, covenants, ratios or other tests in our revolving credit facility, a significant portion of our indebtedness may become immediately due and payable, our lenders’ commitment to make further loans to us may terminate, and we may be prohibited from making distributions to our unitholders. We might not have, or be able to obtain, sufficient funds to make these accelerated payments. We may not be able to replace such revolving credit facility, or if we are, any subsequent replacement of our revolving credit facility or any new indebtedness could have similar or greater restrictions. Please read Part II, Item 7 (“Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Description of Revolving Credit Facility”).

An impairment of goodwill or other intangible assets could reduce our earnings.

We have recorded $35.9 million of goodwill and $78.8million of other intangible assets as of December 31, 2015. Goodwill is recorded when the purchase price of a business exceeds the fair market value of the tangible and separately measurable intangible net assets. Generally accepted accounting principles of the United States (“GAAP”) requires us to test goodwill for impairment on an annual basis or when events or circumstances occur indicating that goodwill might be impaired. Any event that causes a reduction in demand for our services could result in a reduction of our estimates of future cash flows and growth rates in our business. These events could cause us to record impairments of goodwill or other intangible assets. If we determine that any of our goodwill or other intangible assets are impaired, we will be required to take an immediate charge to earnings with a corresponding reduction of partners’ capital resulting in an increase in balance sheet leverage as measured by debt to total capitalization. For the year ended December 31, 2015, we recognized a $172.2 million impairment of goodwill due primarily to the decline in our unit price, the sustained decline in global commodity prices, expected reduction in the capital budgets of certain of our customers and the impact these factors have on our expected future cash flows (see Note 2 of our consolidated financial statements).  There was no impairment recorded for other intangible assets for the year ended December 31, 2015. There was no impairment recorded for goodwill or other intangible assets for the years ended December 31, 2014.

Impairment in the carrying value of long-lived assets could reduce our earnings.

We have a significant amount of long-lived assets on our consolidated balance sheet. Under GAAP, long-lived assets are required to be reviewed for impairment when events or circumstances indicate that its carrying value may not be recoverable or will no longer be utilized in the operating fleet. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset.  If business conditions or other factors cause the expected undiscounted cash flows to decline, we may be required to record non-cash impairment charges. Events and conditions that could result in impairment in the value of our long-lived assets include changes in the industry in which we operate, competition,advances in technology, adverse changes in the regulatory environment, or other factors leading to reduction in expected long-term profitability. For example, during the fiscal year ended December 31, 2015, we evaluated the future deployment of our idle fleet under then-current market conditions and determined to retire and either sell or re-utilize the key components of 166 compressor units, or approximately 58,000 horsepower, that were previously used to provide services in our business, resulting in approximately  $27.3 million impairment of long-lived assets.

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Our ability to manage and grow our business effectively may be adversely affected if we lose management or operational personnel.

We depend on the continuing efforts of our executive officers. The departure of any of our executive officers could have a significant negative effect on our business, operating results, financial condition and on our ability to compete effectively in the marketplace.

Additionally, our ability to hire, train and retain qualified personnel will continue to be important and could become more challenging as we grow and to the extent energy industry market conditions are competitive. When general industry conditions are good, the competition for experienced operational and field technicians increases as other energy and manufacturing companies’ needs for the same personnel increases. Our ability to grow or even to continue our current level of service to our current customers could be adversely impacted if we are unable to successfully hire, train and retain these important personnel.

We depend on a limited number of suppliers and are vulnerable to product shortages and price increases, which could have a negative impact on our results of operations.

The substantial majority of the components for our natural gas compression equipment are supplied by Caterpillar Inc., Cummins Inc. and Arrow Engine Company for engines, Air-X-Changers and Air Cooled Exchangers for coolers, and Ariel Corporation, GE Oil & Gas Gemini products and Arrow Engine Company for compressor frames and cylinders.  Our reliance on these suppliers involves several risks, including price increases and a potential inability to obtain an adequate supply of required components in a timely manner. We also rely primarily on four vendors, A G Equipment Company, Alegacy Equipment, LLC, Standard Equipment Corp. and S&R, to package and assemble our compression units. We do not have long-term contracts with these suppliers or packagers, and a partial or complete loss of any of these sources could have a negative impact on our results of operations and could damage our customer relationships. Some of these suppliers manufacture the components we purchase in a single facility and any damage to that facility could lead to significant delays in delivery of completed units.

We are subject to substantial environmental regulation, and changes in these regulations could increase our costs or liabilities.

We are subject to stringent and complex federal, state and local laws and regulations, including laws and regulations regarding the discharge of materials into the environment, emission controls and other environmental protection and occupational health and safety concerns. Environmental laws and regulations may, in certain circumstances, impose strict liability for environmental contamination, which may render us liable for remediation costs, natural resource damages and other damages as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by, prior owners or operators or other third parties. In addition, where contamination may be present, it is not uncommon for neighboring land owners and other third parties to file claims for personal injury, property damage and recovery of response costs. Remediation costs and other damages arising as a result of environmental laws and regulations, and costs associated with new information, changes in existing environmental laws and regulations or the adoption of new environmental laws and regulations could be substantial and could negatively impact our financial condition or results of operations. Moreover, failure to comply with these environmental laws and regulations may result in the imposition of administrative, civil and criminal penalties and the issuance of injunctions delaying or prohibiting operations.

We conduct operations in a wide variety of locations across the continental U.S. These operations require U.S. federal, state or local environmental permits or other authorizations. Our operations may require new or amended facility permits or licenses from time to time with respect to storm water discharges, waste handling or air emissions relating to equipment operations, which subject us to new or revised permitting conditions that may be onerous or costly to comply with. Additionally, the operation of compression units may require individual air permits or general authorizations to operate under various air regulatory programs established by rule or regulation. These permits and authorizations frequently contain numerous compliance requirements, including monitoring and reporting obligations and operational restrictions, such as emission limits. Given the wide variety of locations in which we operate, and the numerous environmental permits and other authorizations that are applicable to our operations, we may occasionally identify or be

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notified of technical violations of certain requirements existing in various permits or other authorizations. We could be subject to penalties for any noncompliance in the future.

In our business, we routinely deal with natural gas, oil and other petroleum products at our worksites. Hydrocarbons or other hazardous substances or wastes may have been disposed or released on, under or from properties used by us to provide compression services or inactive compression unit storage or on or under other locations where such substances or wastes have been taken for disposal. These properties may be subject to investigatory, remediation and monitoring requirements under federal, state and local environmental laws and regulations.

The modification or interpretation of existing environmental laws or regulations, the more vigorous enforcement of existing environmental laws or regulations, or the adoption of new environmental laws or regulations may also negatively impact oil and natural gas exploration and production, gathering and pipeline companies, including our customers, which in turn could have a negative impact on us.

New regulations, proposed regulations and proposed modifications to existing regulations under the Clean Air Act, if implemented, could result in increased compliance costs.

In August 2010, the EPA published new regulations under the CAA to control emissions of hazardous air pollutants from existing stationary reciprocating internal combustion engines. In June, 2012, the EPA proposed amendments to the final rule in response to several petitions for reconsideration, and EPA finalized the proposed amendments in January 2013. The final rule was effective in 2013. The rule requires us to undertake certain expenditures and activities, including purchasing and installing emissions control equipment on a portion of our engines located at major sources of hazardous air pollutants, following prescribed maintenance practices for engines (which are consistent with our existing practices), and implementing additional emissions testing and monitoring. If we were unable to maintain compliance with the final rule, our business, financial condition, results of operations or cash available for distribution could be impacted.

On October 26, 2015, the EPA published the finalized rule strengthening the NAAQs for ground level ozone. The rule became effective on December 28, 2015. The final rule updates both the primary ozone standard and the secondary standard. Both standards are 8-hour concentration standards of 70 ppb.  In addition, in 2013, the EPA promulgated a final rule revising the annual standard for fine particulate matter, or PM 2.5, by lowering the level from 15 to 12 micrograms per cubic meter. On December 18, 2014, the EPA issued final area designations for the 2012 NAAQs for PM 2.5. Designation of new non-attainment areas for the revised ozone or PM 2.5 NAAQS may result in additional federal and state regulatory actions that may impact our customers’ operations and increase the cost of additions to property, plant and equipment.

In 2012, the EPA finalized rules that establish new air emission controls for oil and natural gas production and natural gas processing operations. Specifically, the EPA’s rule package included New Source Performance Standards to address emissions of sulfur dioxide and VOCs and a separate set of emission standards to address hazardous air pollutants frequently associated with oil and natural gas production and processing activities. The rules established specific new requirements regarding emissions from compressors and controllers at natural gas processing plants, dehydrators, storage tanks and other production equipment as well as the first federal air standards for natural gas wells that are hydraulically fractured. In addition, the rules established leak detection requirements for natural gas processing plants at 500 ppm. In 2013, the EPA issued a final update to the VOC performance standards for storage tanks used in crude oil and natural gas production and transmission. On July 31, 2015, the EPA finalized amendments to the definition of low-pressure wells and references to tanks connected to one another in the 2012 New Source Performance Standards. On August 18, 2015, the EPA also proposed updates to the New Source Performance Standards and Draft Control Techniques Guidelines in addition to proposing a Source Determination Rule, all of which are intended to cut methane and VOC emissions from the oil and natural gas industry. These rules may require a number of modifications to our operations, including the installation of new equipment to control emissions from our compressors at initial startup. Compliance with such rules could result in significant costs, including increased capital expenditures and operating costs, and could adversely impact our business.

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

 A ruling by a panel of administrative law judges in a case before the Pennsylvania Environmental Hearing Board, to which we are not a party, may have implications for the permitting of projects where our customers seek to use our services. In this case, National Fuel Gas Midstream Corporation et al. v. Commonwealth of Pennsylvania, a panel of administrative law judges on December 29, 2015, dismissed an appeal from a determination by the Pennsylvania Department of Environmental Protection that the operations of two separate companies on parcels of land that were not adjoining and were actually separated by forest land but were in close proximity should be aggregated as a single source under the state air permitting regime. The implications of aggregating different sources into a single source is that the overall emissions increase and may increase enough to trigger a more onerous permitting regime and require more stringent controls. The court determined that this outcome was appropriate because, among other reasons, the two companies were owned by a common parent and had several interlocking officers and directors. But it was unclear whether the common parent in fact exercised control over the two companies’ operations. Unless this ruling is overturned on further appeal, application of this ruling to other permit applications where the parties intend to use our services may lead to a permitting regime that is more burdensome, time-consuming and costly to our customers, who typically obtain permits. Moreover, we may be required to install lower emission engines or additional pollution controls and may not be able to recoup all of the associated costs from our customers.

These new regulations and proposals, when finalized, and any other new regulations requiring the installation of more sophisticated pollution control equipment could have a material adverse impact on our business, results of operations, financial condition and cash available for distribution. 

Climate change legislation and regulatory initiatives could result in increased compliance costs.

Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are examples of greenhouse gases. In recent years, the U.S. Congress has considered legislation to reduce emissions of greenhouse gases. It presently appears unlikely that comprehensive climate legislation will be passed by either house of Congress in the near future, although energy legislation and other initiatives are expected to be proposed that may be relevant to greenhouse gas emissions issues. However, almost half of the states have begun to address greenhouse gas emissions, primarily through the planned development of emission inventories or regional greenhouse gas cap and trade programs. Depending on the particular program, we could be required to control greenhouse gas emissions or to purchase and surrender allowances for greenhouse gas emissions resulting from our operations.

Independent of Congress, the EPA is beginning to adopt regulations controlling greenhouse gas emissions under its existing CAA authority. For example, in December 2009, the EPA officially published its findings that emissions of carbon dioxide, methane, and other greenhouse gases endanger human health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. These findings by the EPA allowed the agency to proceed with the adoption and implementation of regulations that restrict emissions of greenhouse gases under existing provisions of the CAA. In 2009, the EPA adopted rules regarding regulation of greenhouse emissions from motor vehicles. In addition, on September 2009, the EPA issued a final rule requiring the reporting of greenhouse gas emissions in the United States beginning in 2011 for emissions occurring in 2010 from specified large greenhouse gas emission sources. In November 2010, the EPA published a final rule expanding its existing greenhouse gas emissions reporting rule for petroleum and natural gas facilities, including natural gas transmission compression facilities that emit 25,000 metric tons or more of carbon dioxide equivalent per year. The rule, which went into effect in December 2010, requires reporting of greenhouse gas emissions by such

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regulated facilities to the EPA by September 2012 for emissions during 2011 and annually thereafter. In 2010, the EPA also issued a final rule, known as the “Tailoring Rule,” that makes certain large stationary sources and modification projects subject to permitting requirements for greenhouse gas emissions under the CAA.

Both the Tailoring Rule and the EPA’s endangerment finding were challenged in federal court and were upheld by the D.C. Court of Appeals.  In July 2014, the United States Supreme Court invalidated the Tailoring Rule but it refused to consider other issues such as whether greenhouse gases endanger public health.  As a result, under federal law, a source is no longer required to meet the PSD and Title V permitting requirements based solely on its greenhouse gas emissions.

The EPA has also sought to directly regulate methane emissions by proposing regulations to expand on Subpart OOOO of the CAA and target methane emissions from new and modified sources, including hydraulically fractured wells. If the final rule is promulgated along the lines of the proposal, these requirements may add to our costs of doing business and we may not be able to recoup all of these costs from our customers.

Finally, on June 2, 2014, the EPA proposed the Clean Power Plan rule, which is intended to reduce carbon emissions from existing power plants by 32 percent from 2005 levels by 2030. Twenty-nine states and various industry groups have challenged the EPA’s authority to regulate carbon dioxide emissions from existing coal-fired power plants under Section 111(d) of the Clean Air Act in the Circuit Court.  In January 2016, the parties asked the United States Supreme Court to stay the plan while the lawsuit proceeds through the court appeals. On February 9, 2016, the U.S. Supreme Court granted a stay of the implementation of the Clean Power Plan before the Circuit Court even issued a decision.  By its terms, this stay will remain in effect throughout the pendency of the appeals process including at the Circuit Court and the Supreme Court through any certiorari petition that may be granted.  The stay suspends the rule, including the requirement that states must start submitting implementation plans by 2018.  It is not yet clear how the either the Circuit Court or the Supreme Court will ultimately rule on the legality of the Clean Power Plan.  While not directly applicable to our operations, in the near term this rule may have the effect of expanding the use of natural gas to produce electricity.  Any such expansion of the use of natural gas for this purpose may increase the need for additional infrastructure, which may increase demand for our products.  In the longer term, however, the Clean Power Plan rule may also lead to reductions in the use of fossil fuels including natural gas, which may have adverse effects on our business.

Although it is not currently possible to predict with specificity how any proposed or future greenhouse gas legislation or regulation will impact our business, any legislation or regulation of greenhouse gas emissions that may be imposed in areas in which we conduct business could result in increased compliance costs or additional operating restrictions or reduced demand for our services, and could have a material adverse effect on our business, financial condition and results of operations.

Increased regulation of hydraulic fracturing could result in reductions or delays in natural gas production by our customers, which could adversely impact our revenue.

A significant portion of our customers’ natural gas production is from unconventional sources that require hydraulic fracturing as part of the completion process. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into the formation to stimulate gas production. Legislation to amend the SDWA to repeal the exemption for hydraulic fracturing from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, were proposed in past sessions of Congress. The U.S. Congress continues to consider legislation to amend the SDWA. Scrutiny of hydraulic fracturing activities continues in other ways, with the EPA having commenced a multi-year study of the potential environmental impacts of hydraulic fracturing, the preliminary results of which were released for public comment in June 2015.  While the EPA stated that it had found no evidence of widespread systemic impacts on drinking water sources from hydraulic fracturing operations, the draft report has not been finalized yet. The EPA also has announced that it believes hydraulic fracturing using fluids containing diesel fuel can be regulated under the SDWA notwithstanding the SDWA’s general exemption for hydraulic fracturing. Several states have also proposed or adopted legislative or regulatory restrictions on hydraulic fracturing, including prohibitions on the practice. We cannot predict if additional legislation will be enacted and if so, what its provisions would be. If additional levels of regulation, restriction and permits are required through the adoption of new laws and

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regulations, or the development of new regulatory interpretations at the federal or state level, that could lead to delays, increased operating costs and process prohibitions for our customers that could reduce demand for our compression services, which could have a material adverse effect on our business, financial condition, results of operations and cash available for distribution.

We do not insure against all potential losses and could be seriously harmed by unexpected liabilities.

Our operations are subject to inherent risks such as equipment defects, malfunction and failures, and natural disasters that can result in uncontrollable flows of gas or well fluids, fires and explosions. These risks could expose us to substantial liability for personal injury, death, property damage, pollution and other environmental damages. Our insurance may be inadequate to cover our liabilities. Further, insurance covering the risks we face or in the amounts we desire may not be available in the future or, if available, the premiums may not be commercially justifiable. If we were to incur substantial liability and such damages were not covered by insurance or were in excess of policy limits, or if we were to incur liability at a time when we are not able to obtain liability insurance, our business, results of operations and financial condition could be adversely affected.

Terrorist attacks, the threat of terrorist attacks or other sustained military campaigns may adversely impact our results of operations.

The long-term impact of terrorist attacks and the magnitude of the threat of future terrorist attacks on the energy industry in general and on us in particular are not known at this time. Uncertainty surrounding sustained military campaigns may affect our operations in unpredictable ways, including disruptions of crude oil and natural gas supplies and markets for crude oil, natural gas and natural gas liquids and the possibility that infrastructure facilities could be direct targets of, or indirect casualties of, an act of terror. Changes in the insurance markets attributable to terrorist attacks may make certain types of insurance more difficult for us to obtain, if we choose to do so. Moreover, the insurance that may be available to us may be significantly more expensive than our existing insurance coverage. Instability in the financial markets as a result of terrorism or war could also affect our ability to raise capital.

If we fail to develop or maintain an effective system of internal controls, we may not be able to report our financial results accurately or prevent fraud, which would likely have a negative impact on the market price of our units.

In connection with the closing of our initial public offering, we became subject to the public reporting requirements of the Exchange Act. Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and to operate successfully as a publicly traded partnership. We continue to evaluate the effectiveness of and improve upon our internal controls. Our efforts to develop and maintain our internal controls may not be successful, and we may be unable to maintain effective controls over our financial processes and reporting in the future or to comply with our obligations under Section 404 of the Sarbanes Oxley Act of 2002 (“Section 404”). For example, Section 404 requires us, among other things, to review and report annually on the effectiveness of our internal control over financial reporting. We were required to comply with Section 404(a) beginning with our fiscal year ended December 31, 2013. In addition, our independent registered public accountants will be required to assess the effectiveness of internal control over financial reporting at the end of the fiscal year after we are no longer an “emerging growth company” under the Jumpstart Our Business Startups Act, which may be for up to five fiscal years after the date we completed our initial public offering, which was in January 2013. Any failure to develop, implement or maintain effective internal controls or to improve our internal controls could harm our operating results or cause us to fail to meet our reporting obligations. Given the difficulties inherent in the design and operation of internal controls over financial reporting, we can provide no assurance as to our independent registered public accounting firm’s conclusions about the effectiveness of our internal controls, and we may incur significant costs in our efforts to comply with Section 404. Ineffective internal controls will subject us to regulatory scrutiny and a loss of confidence in our reported financial information, which could have an adverse effect on our business and would likely have a negative effect on the trading price of our units.

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Risks Inherent in an Investment in Us

Holders of our common units have limited voting rights and are not entitled to elect our general partner or its directors.

Unlike the holders of common stock in a corporation, our unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders have no right to elect our general partner or its board of directors. USA Compression Holdings is the sole member of our general partner and has the right to appoint our general partner’s entire board of directors, including its independent directors. If the unitholders are dissatisfied with the performance of our general partner, they have little ability to remove our general partner. As a result of these limitations, the price of our common units may be diminished because of the absence or reduction of a takeover premium in the trading price. Furthermore, our partnership agreement also contains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions limiting the unitholders’ ability to influence the manner or direction of management.

USA Compression Holdings owns and controls our general partner, which has sole responsibility for conducting our business and managing our operations. Our general partner and its affiliates, including USA Compression Holdings, have conflicts of interest with us and limited fiduciary duties and they may favor their own interests to the detriment of us and our unitholders.

USA Compression Holdings, which is principally owned and controlled by Riverstone, owns and controls our general partner and appointed all of the officers and directors of our general partner, some of whom are also officers and directors of USA Compression Holdings. Although our general partner has a fiduciary duty to manage us in a manner that is beneficial to us and our unitholders, the directors and officers of our general partner have a fiduciary duty to manage our general partner in a manner that is beneficial to its owners. Conflicts of interest will arise between USA Compression Holdings, Riverstone and our general partner, on the one hand, and us and our unitholders, on the other hand. In resolving these conflicts of interest, our general partner may favor its own interests and the interests of USA Compression Holdings and the other owners of USA Compression Holdings over our interests and the interests of our unitholders. These conflicts include the following situations, among others:

· neither our partnership agreement nor any other agreement requires USA Compression Holdings to pursue a business strategy that favors us;

· our general partner is allowed to take into account the interests of parties other than us, such as USA Compression Holdings, in resolving conflicts of interest;

· our partnership agreement limits the liability of and reduces the fiduciary duties owed by our general partner, and also restricts the remedies available to our unitholders for actions that, without such limitations, might constitute breaches of fiduciary duty;

· except in limited circumstances, our general partner has the power and authority to conduct our business without unitholder approval;

· our general partner determines the amount and timing of asset purchases and sales, borrowings, issuance of additional partnership interests and the creation, reduction or increase of reserves, each of which can affect the amount of cash that is distributed to our unitholders;

· our general partner determines the amount and timing of any capital expenditures and whether a capital expenditure is classified as a maintenance capital expenditure, which reduces operating surplus, or an expansion capital expenditure, which does not reduce operating surplus. This determination can affect the amount of cash that is distributed to our unitholders and to our general partner and the ability of the subordinated units to convert to common units;

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· our general partner determines which costs incurred by it are reimbursable by us;

· our general partner may cause us to borrow funds in order to permit the payment of cash distributions, even if the purpose or effect of the borrowing is to make a distribution on the subordinated units, to make incentive distributions or to accelerate the expiration of the subordination period;

· our partnership agreement permits us to classify up to $36.6 million as operating surplus, even if it is generated from asset sales, non-working capital borrowings or other sources that would otherwise constitute capital surplus. This cash may be used to fund distributions as operating surplus from non-operating sources on our subordinated units or to our general partner in respect of its General Partner Interest (as defined under Part II, Item 5 (“Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities”) or the incentive distribution rights (or “IDRs”);

· our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered to us or entering into additional contractual arrangements with any of these entities on our behalf;

· our general partner intends to limit its liability regarding our contractual and other obligations;

· our general partner may exercise its right to call and purchase all of the common units not owned by it and its affiliates if they own more than 80% of the common units;

· our general partner controls the enforcement of the obligations that it and its affiliates owe to us;

· our general partner decides whether to retain separate counsel, accountants or others to perform services for us; and

· our general partner may elect to cause us to issue common units to it in connection with a resetting of the target distribution levels related to the IDRs without the approval of the conflicts committee of the board of directors of our general partner or our unitholders. This election may result in lower distributions to our common unitholders in certain situations.

Our general partner’s liability regarding our obligations is limited.

Our general partner has included, and will continue to include, provisions in its and our contractual arrangements that limit its liability under such contractual arrangements so that the counterparties to such arrangements have recourse only against our assets, and not against our general partner or its assets. Our general partner may therefore cause us to incur indebtedness or other obligations that are nonrecourse to our general partner. Our partnership agreement provides that any action taken by our general partner to limit its liability is not a breach of our general partner’s fiduciary duties, even if we could have obtained more favorable terms without the limitation on liability. In addition, we are obligated to reimburse or indemnify our general partner to the extent that it incurs obligations on our behalf. Any such reimbursement or indemnification payments would reduce the amount of cash otherwise available for distribution.

Our partnership agreement limits our general partner’s fiduciary duties to our unitholders.

Our partnership agreement contains provisions that modify and reduce the fiduciary standards to which our general partner would otherwise be held by state fiduciary duty law. For example, our partnership agreement permits our general partner to make a number of decisions in its individual capacity, as opposed to its capacity as our general partner, or otherwise free of fiduciary duties to us and our unitholders. This entitles our general partner to consider only the interests and factors that it desires and relieves it of any duty or obligation to give any consideration to any interest of, or factors affecting, us, our affiliates or our limited partners. Examples of decisions that our general partner may make in its individual capacity include:

· how to allocate business opportunities among us and its affiliates;

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· whether to exercise its limited call right;

· how to exercise its voting rights with respect to the units it owns;

· whether to elect to reset target distribution levels; and

· whether or not to consent to any merger or consolidation of the Partnership or amendment to the partnership agreement.

By purchasing a unit, a unitholder agrees to become bound by the provisions in the partnership agreement, including the provisions discussed above.

Even if holders of our common units are dissatisfied, they currently cannot remove our general partner without USA Compression Holdings’ consent.

The unitholders are currently unable to remove our general partner because our general partner and its affiliates own sufficient units to be able to prevent its removal. The vote of the holders of at least 662/3% of all outstanding common and subordinated units voting together as a single class is required to remove our general partner. USA Compression Holdings owns an aggregate of 41% of our outstanding common and subordinated units. Also, if our general partner is removed without cause during the subordination period and no units held by the holders of the subordinated units or their affiliates (including our general partner and its affiliates) are voted in favor of that removal, all subordinated units will automatically be converted into common units. A removal of our general partner under these circumstances would adversely affect our common units by prematurely eliminating their distribution and liquidation preference over our subordinated units, which would otherwise have continued until we had met certain distribution and performance tests (upon the payment of our quarterly distribution on February 12, 2016, we will meet these distribution and performance tests and all of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016). Cause is narrowly defined in our partnership agreement to mean that a court of competent jurisdiction has entered a final, non-appealable judgment finding our general partner liable for actual fraud or willful misconduct in its capacity as our general partner. Generally, poor management of our business by our general partner does not constitute “cause”.

Our partnership agreement restricts the remedies available to holders of our common units for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.

Our partnership agreement contains provisions that restrict the remedies available to unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty under state fiduciary duty law. For example, our partnership agreement:

· provides that whenever our general partner makes a determination or takes, or declines to take, any other action in its capacity as our general partner, our general partner is required to make such determination, or take or decline to take such other action, in good faith, and will not be subject to any higher standard imposed by our partnership agreement, Delaware law, or any other law, rule or regulation, or at equity;

· provides that our general partner will not have any liability to us or our unitholders for decisions made in its capacity as a general partner so long as such decisions are made in good faith, meaning that it believed that the decisions were in the best interest of our partnership;

· provides that our general partner and its officers and directors will not be liable for monetary damages to us, our limited partners or their assignees resulting from any act or omission unless there has been a final and non-appealable judgment entered by a court of competent jurisdiction determining that our general partner or its officers and directors, as the case may be, acted in bad faith or engaged in fraud or willful misconduct or, in the case of a criminal matter, acted with knowledge that the conduct was criminal; and

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· provides that our general partner will not be in breach of its obligations under the partnership agreement or its fiduciary duties to us or our unitholders if a transaction with an affiliate or the resolution of a conflict of interest is:

(a) approved by the conflicts committee of the board of directors of our general partner, although our general partner is not obligated to seek such approval;

(b) approved by the vote of a majority of the outstanding common units, excluding any common units owned by our general partner and its affiliates;

(c) on terms no less favorable to us than those generally being provided to or available from unrelated third parties; or

(d) fair and reasonable to us, taking into account the totality of the relationships among the parties involved, including other transactions that may be particularly favorable or advantageous to us.

In connection with a situation involving a transaction with an affiliate or a conflict of interest, any determination by our general partner must be made in good faith. If an affiliate transaction or the resolution of a conflict of interest is not approved by our common unitholders or the conflicts committee and the board of directors of our general partner determines that the resolution or course of action taken with respect to the affiliate transaction or conflict of interest satisfies either of the standards set forth in subclauses (c) and (d) above, then it will conclusively be deemed that, in making its decision, the board of directors of our general partner acted in good faith.

Our general partner may elect to cause us to issue common units to it in connection with a resetting of the target distribution levels related to its IDRs, without the approval of the conflicts committee of its board of directors of our general partner or the holders of our common units. This could result in lower distributions to holders of our common units.

Our general partner has the right, at any time when there are no subordinated units outstanding and it has received incentive distributions at the highest level to which it is entitled (48.0%) for each of the prior four consecutive fiscal quarters, to reset the initial target distribution levels at higher levels based on our distributions at the time of the exercise of the reset election. Following a reset election by our general partner, the minimum quarterly distribution will be adjusted to equal the reset minimum quarterly distribution, and the target distribution levels will be reset to correspondingly higher levels based on percentage increases above the reset minimum quarterly distribution.

If our general partner elects to reset the target distribution levels, it will be entitled to receive a number of common units and to maintain its general partner interest. The number of common units to be issued to our general partner will equal the number of common units which would have entitled the holder to an average aggregate quarterly cash distribution in the prior two quarters equal to the average of the distributions to our general partner on the IDRs in the prior two quarters. Our general partner’s general partner interest in us (currently 1.46%) will be maintained at the percentage that existed immediately prior to the reset election. Our general partner could exercise this reset election at a time when it is experiencing, or expects to experience, declines in the cash distributions it receives related to its IDRs and may, therefore, desire to be issued common units rather than retain the right to receive incentive distributions based on the initial target distribution levels. As a result, a reset election may cause our common unitholders to experience a reduction in the amount of cash distributions that our common unitholders would have otherwise received had we not issued new common units to our general partner in connection with resetting the target distribution levels.

Our partnership agreement restricts the voting rights of unitholders owning 20% or more of our common units.

Unitholders’ voting rights are further restricted by a provision of our partnership agreement providing that any units held by a person or group that owns 20% or more of any class of units then outstanding, other than our general partner, its affiliates, their direct transferees and their indirect transferees approved by our general partner (which approval may be granted in its sole discretion) and persons who acquired such units with the prior approval of our general partner, cannot vote on any matter.

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Our general partner interest or the control of our general partner may be transferred to a third party without unitholder consent.

Our general partner may transfer its general partner interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent of the unitholders. Furthermore, our partnership agreement does not restrict the ability of USA Compression Holdings to transfer all or a portion of its ownership interest in our general partner to a third party. The new owner of our general partner would then be in a position to replace the board of directors and officers of our general partner with its own designees and thereby exert significant control over the decisions made by the board of directors and officers of our general partner.

An increase in interest rates may cause the market price of our common units to decline.

Like all equity investments, an investment in our common units is subject to certain risks. In exchange for accepting these risks, investors may expect to receive a higher rate of return than would otherwise be obtainable from lower-risk investments. Accordingly, as interest rates rise, the ability of investors to obtain higher risk-adjusted rates of return by purchasing government-backed debt securities may cause a corresponding decline in demand for riskier investments generally, including yield based equity investments such as publicly traded partnership interests. Reduced demand for our common units resulting from investors seeking other more favorable investment opportunities may cause the trading price of our common units to decline.

We may issue additional units without your approval, which would dilute your existing ownership interests.

Our partnership agreement does not limit the number or timing of additional limited partner interests that we may issue without the approval of our unitholders. The issuance by us of additional common units, including pursuant to our Distribution Reinvestment Plan (“DRIP”) or our continuous offering program, or other equity securities of equal or senior rank, will have the following effects:

· our existing unitholders’ proportionate ownership interest in us will decrease;

· the amount of cash available for distribution on each unit may decrease;

· because a lower percentage of total outstanding units will be subordinated units during the subordination period, the risk that a shortfall in the payment of the minimum quarterly distribution will be borne by our common unitholders will increase;

· the ratio of taxable income to distributions may increase;

· the relative voting strength of each previously outstanding unit may be diminished;

· the market price of the common units may decline; and

· assuming the distribution per unit remains unchanged or increases, the cash distributions to the holder of the IDRs will increase.

USA Compression Holdings and Argonaut may sell units in the public or private markets, and such sales could have an adverse impact on the trading price of the common units.

USA Compression Holdings holds an aggregate of 7,267,511 common units and 14,048,588 subordinated units. All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.  Argonaut holds an aggregate of 7,715,948 common units. In addition, USA Compression Holdings and Argonaut may acquire additional common units in connection with our DRIP. We have agreed to provide USA Compression Holdings and Argonaut with certain registration rights for any

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common and subordinated units they own, as applicable. The sale of these units in the public or private markets could have an adverse impact on the price of the common units or on any trading market that may develop.

Our general partner has a call right that may require you to sell your units at an undesirable time or price.

If at any time our general partner and its affiliates own more than 80% of the common units, our general partner will have the right, which it may assign to any of its affiliates or to us, but not the obligation, to acquire all, but not less than all, of the common units held by unaffiliated persons at a price that is not less than their then-current market price, as calculated pursuant to the terms of our partnership agreement. As a result, you may be required to sell your common units at an undesirable time or price. You may also incur a tax liability upon a sale of your units. USA Compression Holdings owns an aggregate of approximately 19% of our outstanding common units. At the end of the subordination period, assuming no additional issuances of common units (other than upon the conversion of the subordinated units), USA Compression Holdings will own an aggregate of approximately 41% of our outstanding common units.  All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.

Your liability may not be limited if a court finds that unitholder action constitutes control of our business.

A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of the partnership that are expressly made without recourse to our general partner. Our partnership is organized under Delaware law, and we conduct business in a number of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership have not been clearly established in some of the other states in which we do business. You could be liable for any and all of our obligations as if you were a general partner if a court or government agency were to determine that:

· we were conducting business in a state but had not complied with that particular state’s partnership statute; or

· your right to act with other unitholders to remove or replace our general partner, to approve some amendments to our partnership agreement or to take other actions under our partnership agreement constitute “control” of our business.

Unitholders may have liability to repay distributions that were wrongfully distributed to them.

Under certain circumstances, unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 17-607 of the Delaware Revised Uniform Limited Partnership Act (the “Delaware Act”), we may not make a distribution to you if the distribution would cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of an impermissible distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to the limited partnership for the distribution amount. Substituted limited partners are liable both for the obligations of the assignor to make contributions to the partnership that were known to the substituted limited partner at the time it became a limited partner and for those obligations that were unknown if the liabilities could have been determined from the partnership agreement. Neither liabilities to partners on account of their partnership interest nor liabilities that are non-recourse to the partnership are counted for purposes of determining whether a distribution is permitted.

The NYSE does not require a publicly traded partnership like us to comply with certain of its corporate governance requirements.

Our common units are listed on the NYSE. Because we are a publicly traded partnership, the NYSE does not require us to have a majority of independent directors on our general partner’s board of directors or to establish a compensation committee or a nominating and corporate governance committee. Accordingly, unitholders do not have the same protections afforded to investors in certain corporations that are subject to all of the NYSE corporate governance requirements. Please read Part III, Item 10 (“Directors, Executive Officers and Corporate Governance”).

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Pursuant to certain federal securities laws, our independent registered public accounting firm will not be required to attest to the effectiveness of our internal control over financial reporting pursuant to Section 404 of the Sarbanes Oxley Act of 2002 for so long as we are an emerging growth company.

We are required to disclose changes made in our internal control over financial reporting on a quarterly basis, and we are required to assess the effectiveness of our controls annually. However, for as long as we are an “emerging growth company” under federal securities laws, our independent registered public accounting firm will not be required to attest to the effectiveness of our internal control over financial reporting pursuant to Section 404. We could be an emerging growth company for up to five years from the date of our initial public offering, which occurred on January 18, 2013. Even if we conclude that our internal control over financial reporting is effective, our independent registered public accounting firm may still decline to attest to our assessment or may issue a report that is qualified if it is not satisfied with our controls or the level at which our controls are documented, designed, operated or reviewed, or if it interprets the relevant requirements differently from us.

Tax Risks to Common Unitholders

Our tax treatment depends on our status as a partnership for federal income tax purposes. If the IRS were to treat us as a corporation for federal income tax purposes, then our cash available for distribution would be substantially reduced.

The anticipated after-tax economic benefit of an investment in the common units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested a ruling from the IRS on this or any other tax matter affecting us.

Despite the fact that we are a limited partnership under Delaware law, it is possible in certain circumstances for a partnership such as ours to be treated as a corporation for federal income tax purposes. Although we do not believe based upon our current operations that we are or will be so treated, a change in our business or a change in current law could cause us to be treated as a corporation for federal income tax purposes or otherwise subject us to taxation as an entity.

If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 35%, and would likely pay state and local income tax at varying rates. Distributions would generally be taxed again as corporate dividends (to the extent of our current and accumulated earnings and profits), and no income, gains, losses, deductions or credits would flow through to you. Because a tax would be imposed upon us as a corporation, our cash available for distribution would be substantially reduced. Therefore, if we were treated as a corporation for federal income tax purposes, there would be a material reduction in the anticipated cash flow and after-tax return to our unitholders, likely causing a substantial reduction in the value of our common units.

Our partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity level taxation for federal, state or local income tax purposes, the minimum quarterly distribution amount and the target distribution amounts may be adjusted to reflect the impact of that law on us.

If we were subjected to a material amount of additional entity level taxation by individual states, it would reduce our cash available for distribution.

Changes in current state law may subject us to additional entity level taxation by individual states. Because of widespread state budget deficits and other reasons, several states are evaluating ways to subject partnerships to entity level taxation through the imposition of state income, franchise and other forms of taxation. For example, we are required to pay the Revised Texas Franchise Tax each year at a maximum effective rate of 0.75% of our “margin”, as defined in the law, apportioned to Texas in the prior year. Imposition of any similar taxes by any other state may substantially reduce the cash available for distribution and, therefore, negatively impact the value of an investment in our common units.

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The tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial or administrative changes or differing interpretations, possibly applied on a retroactive basis.

The present federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial changes or differing interpretation at any time. For example, the Obama administration’s budget proposal for fiscal year 2017 recommends that certain publicly traded partnerships earning income from activities related to fossil fuels be taxed as corporations beginning in 2022. From time to time, members of the U.S. Congress propose and consider such substantive changes to the existing federal income tax laws that affect publicly traded partnerships. If successful, the Obama administration’s proposal or other similar proposals could eliminate the qualifying income exception to the treatment of all publicly-traded partnerships as corporations upon which we rely for our treatment as a partnership for U.S. federal income tax purposes.

In addition, the Internal Revenue Service, on May 5, 2015, issued proposed regulations concerning which activities give rise to qualifying income within the meaning of Section 7704 of the Internal Revenue Code.  We do not believe the proposed regulations affect our ability to qualify as a publicly traded partnership.  However, finalized regulations could modify the amount of our gross income that we are able to treat as qualifying income for the purposes of the qualifying income requirement.

Any modification to the U.S. federal income tax laws may be applied retroactively and could make it more difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax purposes. We are unable to predict whether any of these changes or other proposals will ultimately be enacted. Any such changes could negatively impact the value of an investment in our common units.

Our unitholders’ share of our income will be taxable to them for federal income tax purposes even if they do not receive any cash distributions from us.

Because a unitholder will be treated as a partner to whom we will allocate taxable income that could be different in amount than the cash we distribute, a unitholder’s allocable share of our taxable income will be taxable to it, which may require the payment of federal income taxes and, in some cases, state and local income taxes, on its share of our taxable income even if it receives no cash distributions from us. Our unitholders may not receive cash distributions from us equal to their share of our taxable income or even equal to the actual tax liability that results from that income.

We may engage in transactions to de-lever the Partnership and manage our liquidity that may result in income and gain to our unitholders.   For example, if we sell assets and use the proceeds to repay existing debt or fund capital expenditures, you may be allocated taxable income and gain resulting from the sale.  Further, taking advantage of opportunities to reduce our existing debt, such as debt exchanges, debt repurchases, or modifications of our existing debt could result in “cancellation of indebtedness income” (also referred to as “COD income”) being allocated to our unitholders as taxable income. Unitholders may be allocated COD income, and income tax liabilities arising therefrom may exceed cash distributions. The ultimate effect of any such allocations will depend on the unitholder's individual tax position with respect to its units. Unitholders are encouraged to consult their tax advisors with respect to the consequences of potential COD income or other transactions that may result in income and gain to unitholders.

If the IRS contests the federal income tax positions we take, the market for our common units may be adversely impacted and the cost of any IRS contest will reduce our cash available for distribution. Recently enacted legislation alters the procedures for assessing and collecting taxes due for taxable years beginning after December 31, 2017, in a manner that could substantially reduce cash available for distribution to you.

We have not requested a ruling from the IRS with respect to our treatment as a partnership for federal income tax purposes or any other matter affecting us. The IRS may adopt positions that differ from the positions we take, and the IRS’s positions may ultimately be sustained.

It may be necessary to resort to administrative or court proceedings to sustain some or all of the positions we take. A court may not agree with some or all of the positions we take. Any contest with the IRS, and the outcome of any IRS contest, may have a materially adverse impact on the market for our common units and the price at which they trade. In addition, our costs of any contest with the IRS will be borne indirectly by our unitholders and our general partner because the costs will reduce our cash available for distribution.

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Recently enacted legislation applicable to us for taxable years beginning after December 31, 2017 alters the procedures for auditing large partnerships and also alters the procedures for assessing and collecting taxes due (including applicable penalties and interest) as a result of an audit. Unless we are eligible to (and choose to) elect to issue revised Schedules K-1 to our partners with respect to an audited and adjusted return, the IRS may assess and collect taxes (including any applicable penalties and interest) directly from us in the year in which the audit is completed under the new rules. If we are required to pay taxes, penalties and interest as the result of audit adjustments, cash available for distribution to our unitholders may be substantially reduced. In addition, because payment would be due for the taxable year in which the audit is completed, unitholders during that taxable year would bear the expense of the adjustment even if they were not unitholders during the audited taxable year.

Tax gain or loss on the disposition of our common units could be more or less than expected.

If our unitholders sell common units, they will recognize a gain or loss for federal income tax purposes equal to the difference between the amount realized and their tax basis in those common units. Because distributions in excess of their allocable share of our net taxable income decrease their tax basis in their common units, the amount, if any, of such prior excess distributions with respect to the common units a unitholder sells will, in effect, become taxable income to the unitholder if it sells such common units at a price greater than its tax basis in those common units, even if the price received is less than its original cost. Furthermore, a substantial portion of the amount realized on any sale of common units, whether or not representing gain, may be taxed as ordinary income due to potential recapture items, including depreciation recapture. In addition, because the amount realized includes a unitholder’s share of our nonrecourse liabilities, a unitholder that sells common units may incur a tax liability in excess of the amount of cash received from the sale.

Tax-exempt entities and non-U.S. persons face unique tax issues from owning our common units that may result in adverse tax consequences to them.

Investment in common units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (“IRAs”), and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from federal income tax, including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will be subject to withholding taxes imposed at the highest tax rate applicable to such non-U.S. persons, and each non-U.S. person will be required to file U.S. federal income tax returns and pay tax on its share of our taxable income. If you are a tax-exempt entity or a non-U.S. person, you should consult a tax advisor before investing in our common units.

We will treat each purchaser of common units as having the same tax benefits without regard to the actual common units purchased. The IRS may challenge this treatment, which could adversely affect the value of the common units.

Because we cannot match transferors and transferees of common units and because of other reasons, we will adopt depreciation and amortization positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to you. It also could affect the timing of these tax benefits or the amount of gain from your sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to your tax returns.

We prorate our items of income, gain, loss and deduction for federal income tax purposes between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The IRS may challenge this treatment, which could change the allocation of items of income, gain, loss and deduction among our unitholders.

We will prorate our items of income, gain, loss and deduction for federal income tax purposes between transferors and transferees of our units each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred. The U.S. Department of the Treasury recently adopted final Treasury Regulations allowing a similar monthly simplifying convention for taxable years beginning on or after August 3, 2015. However, such regulations do not specifically authorize the use of the proration method we have adopted for our 2015 taxable year and may not specifically authorize all aspects of our proration method thereafter. If the IRS were to

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challenge our proration method, we may be required to change the allocation of items of income, gain, loss and deduction among our unitholders.

A unitholder whose common units are the subject of a securities loan (e.g., a loan to a “short seller” to effect a short sale of common units) may be considered as having disposed of those common units. If so, he would no longer be treated for federal income tax purposes as a partner with respect to those common units during the period of the loan and may recognize gain or loss from the disposition.

Because there are no specific rules governing the federal income tax consequences of loaning a partnership interest, a unitholder whose common units are the subject of a securities loan may be considered as having disposed of the loaned common units, he may no longer be treated for federal income tax purposes as a partner with respect to those common units during the period of the loan to the short seller and the unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan, any of our income, gain, loss or deduction with respect to those common units may not be reportable by the unitholder and any cash distributions received by the unitholder as to those common units could be fully taxable as ordinary income. Unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a securities loan are urged to consult a tax advisor to discuss whether it is advisable to modify any applicable brokerage account agreements to prohibit their brokers from loaning their common units.

We have adopted certain valuation methodologies in determining unitholder’s allocations of income, gain, loss and deduction. The IRS may challenge these methods or the resulting allocations, and such a challenge could adversely affect the value of our common units.

In determining the items of income, gain, loss and deduction allocable to our unitholders, we must routinely determine the fair market value of our respective assets. Although we may from time to time consult with professional appraisers regarding valuation matters, we make many fair market value estimates using a methodology based on the market value of our common units as a means to measure the fair market value of our respective assets. The IRS may challenge these valuation methods and the resulting allocations of income, gain, loss and deduction.

A successful IRS challenge to these methods or allocations could adversely affect the amount, character and timing of taxable income or loss being allocated to our unitholders. It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.

The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the termination of our partnership for federal income tax purposes.

We will be considered to have technically terminated for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a twelve-month period. For purposes of determining whether the 50% threshold has been met, multiple sales of the same interest will be counted only once. Our technical termination would, among other things, result in the closing of our taxable year for all unitholders, which would result in us filing two tax returns (and our unitholders could receive two Schedules K-1 if relief was not available, as described below) for one calendar year and could result in a deferral of depreciation deductions allowable in computing our taxable income. In the case of a unitholder reporting on a taxable year other than a calendar year, the closing of our taxable year may also result in more than twelve months of our taxable income or loss being includable in his taxable income for the year of termination. A technical termination currently would not affect our classification as a partnership for federal income tax purposes, but instead we would be treated as a new partnership for such tax purposes. If treated as a new partnership, we must make new tax elections and could be subject to penalties if we are unable to determine that a termination occurred. The IRS has announced a publicly traded partnership technical termination relief program whereby a publicly traded partnership that technically terminated may request publicly traded partnership technical termination relief which, if granted by the IRS, among other things would permit the partnership to provide only one Schedule K-1 to unitholders for the year notwithstanding two partnership tax years.

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As a result of investing in our common units, you will likely become subject to state and local taxes and return filing requirements in jurisdictions where we operate or own or acquire properties.

In addition to federal income taxes, our unitholders will likely be subject to other taxes, including state and local taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we conduct business or control property now or in the future, even if they do not live in any of those jurisdictions. Our unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, our unitholders may be subject to penalties for failure to comply with those requirements. We currently conduct business in several states. Many of which currently impose a personal income tax on individuals. Many of these states also impose an income tax on corporations and other entities. As we make acquisitions or expand our business, we may control assets or conduct business in additional states or foreign jurisdictions that impose a personal income tax. It is your responsibility to file all foreign, federal, state and local tax returns.

ITEM 1B.Unresolved Staff Comments

None.

ITEM 2.Properties

We do not currently own or lease any material facilities or properties for storage or maintenance of our compression units. As of December 31, 2015, our headquarters consisted of 18,167 square feet of leased space located at 100 Congress Avenue, Austin, Texas 78701.

ITEM 3.Legal Proceedings

Please refer toNote  14 of our consolidated financial statements included in this report for a description of our Legal Proceedings.  

ITEM 4.Mine Safety Disclosures

None.

PART II

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

Our Partnership Interests

As of February 9, 2016, we had outstanding 38,556,245 common units, 14,048,588 subordinated units, a 1.46% general partner interest (“General Partner Interest”) and the IDRs. USA Compression Holdings owns  a 100% membership interest in our general partner.  As of February 9, 2016,  USA Compression Holdings owned approximately 19%  of our outstanding common units and 100% of our subordinated units, all of which will convert to common units on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.  Our general partner currently owns the General Partner Interest in us and all of the IDRs. As discussed below under “Selected Information from Our Partnership Agreement—General Partner Interest and IDRs,” the IDRs represent the right to receive increasing percentages, up to a maximum of 48%, of the cash we distribute from operating surplus (as defined below) in excess of $0.4888 per unit per quarter. Our common units, which represent limited partner interests in us, are listed on the New York Stock Exchange (“NYSE”) under the symbol “USAC.”

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The following table sets forth high and low sales prices per common unit and cash distributions per common unit to common unitholders for the periods indicated. The last reported sales price for our common units on February 9, 2016,  was $8.25.

					Cash
					Distribution
	Price Range				Declared Per
Period	High		Low		Common Unit		Date Paid
First Quarter 2014	$	28.73	$	25.71	$	0.490	May 15, 2014
Second Quarter 2014	$	28.29	$	24.52	$	0.500	August 14, 2014
Third Quarter 2014	$	26.44	$	23.17	$	0.505	November 14, 2014
Fourth Quarter 2014	$	24.82	$	14.45	$	0.510	February 13, 2015
First Quarter 2015	$	21.60	$	15.57	$	0.515	May 15, 2015
Second Quarter 2015	$	24.30	$	18.33	$	0.525	August 14, 2015
Third Quarter 2015	$	20.95	$	13.26	$	0.525	November 13, 2015
Fourth Quarter 2015	$	18.89	$	10.19	$	0.525	February 12, 2016

Holders

At the close of business on February 9,  2016, based on information received from the transfer agent of the common units, we had 57holders of record of our common units. The number of record holders does not include holders of common units in “street names” or persons, partnerships, associations, corporations or other entities identified in security position listings maintained by depositories.

Selected Information from our Partnership Agreement

Set forth below is a summary of the significant provisions of our partnership agreement that relate to available cash, minimum quarterly distributions, and the General Partner Interest and the IDRs.

Available Cash

Our partnership agreement requires that, within 45 days after the end of each quarter, we distribute all of our available cash to unitholders of record on the applicable record date. Our partnership agreement generally defines available cash, for each quarter, as cash on hand at the end of a quarter plus cash on hand resulting from working capital borrowings made after the end of the quarter less the amount of reserves established by our general partner to provide for the proper conduct of our business, comply with applicable law, our revolving credit facility or other agreements; and provide funds for distributions to our unitholders for any one or more of the next four quarters. Working capital borrowings are borrowings made under a credit facility, commercial paper facility or other similar financing arrangement, and in all cases are used solely for working capital purposes or to pay distributions to partners and with the intent of the borrower to repay such borrowings within twelve months from sources other than working capital borrowings.

Minimum Quarterly Distribution

Our partnership agreement provides that, during the subordination period, the common units will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.425 per common unit, which amount is defined in our partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions until the common units have received the minimum quarterly distribution plus any arrearages from prior quarters. Furthermore, no arrearages will be paid on the subordinated units. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be available cash to be distributed on the

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common units. On January 21, 2016, the Partnership announced a cash distribution of $0.525 per unit on its common and subordinated units. This fourth quarter distribution corresponds to an annualized distribution rate of $2.10 per unit. The distribution will be paid on February 12, 2016 to unitholders of record as of the close of business on February 2, 2016. USA Compression Holdings elected to reinvest all of this distribution with respect to their units pursuant to the DRIP. All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.

General Partner Interest and IDRs

Our partnership agreement provides that our general partner is entitled to its General Partner Interest of all distributions that we make. Our general partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its General Partner Interest if we issue additional units. Our general partner’s General Partner Interest, and the percentage of our cash distributions to which it is entitled, will be proportionately reduced if we issue additional units in the future (other than the issuance of common units upon conversion of outstanding subordinated units or the issuance of common units upon a reset of the IDRs) and our general partner does not contribute a proportionate amount of capital to us in order to maintain its  General Partner Interest. Our partnership agreement does not require that our general partner fund its capital contribution with cash and our general partner may fund its capital contribution by the contribution to us of common units or other property.

The IDRs represent the right to receive increasing percentages (13.0%, 23.0% and 48.0%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved. Our general partner currently holds the IDRs, but may transfer these rights separately from its General Partner Interest and without the consent of our limited partners.

Issuer Purchases of Equity Securities

None.

Sales of Unregistered Securities; Use of Proceeds from Sale of Securities

None.

Equity Compensation Plan

For disclosures regarding securities authorized for issuance under equity compensation plans, see Part III, Item 12 (“Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters”).

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ITEM 6.Selected Financial Data

SELECTED HISTORICAL FINANCIAL DATA

In the table below we have presented certain selected financial data for USA Compression Partners, LP for each of the five years in the period ended December 31, 2015, which has been derived from our audited consolidated financial statements. The following information should be read together with Management’s Discussion and Analysis of Financial Condition and Results of Operations and the Financial Statements contained in Part II, Item 7.

The following table includes the non-GAAP financial measure of gross operating margin, Adjusted EBITDA and Distributable Cash Flow (or “DCF”). For definitions of Gross Operating Margin, Adjusted EBITDA and DCF, and reconciliations to such measures to their most directly comparable financial measures calculated and presented in accordance with GAAP, please read “Non-GAAP Financial Measures” below.

	Year Ended December 31,
	2015		2014		2013		2012		2011
	(in thousands, except for unit amounts)
Revenues:
Contract operations	$	263,816	$	217,361	$	150,360	$	116,373	$	93,896
Parts and service		6,729		4,148		2,558		2,414		4,824
Total revenues		270,545		221,509		152,918		118,787		98,720
Costs of operations, exclusive of depreciation and amortization:
Cost of operations		81,539		74,035		48,097		37,796		39,605
Gross operating margin (1)		189,006		147,474		104,821		80,991		59,115
Other operating and administrative costs and expenses:
Selling, general and administrative		40,950		38,718		27,587		18,269		12,726
Restructuring charges (2)		—		—		—		—		300
Depreciation and amortization		85,238		71,156		52,917		41,880		32,738
Loss (gain) of sale of assets		(1,040)		(2,233)		284		266		178
Impairment of compression equipment		27,274		2,266		203		—		—
Impairment of goodwill		172,189		—		—		—		—
Total other operating and administrative costs and expenses		324,611		109,907		80,991		60,415		45,942
Operating income (loss)		(135,605)		37,567		23,830		20,576		13,173
Other income (expense):
Interest expense, net		(17,605)		(12,529)		(12,488)		(15,905)		(12,970)
Other		22		11		9		28		21
Total other expense		(17,583)		(12,518)		(12,479)		(15,877)		(12,949)
Income (loss) before income tax expense		(153,188)		25,049		11,351		4,699		224
Income tax expense		1,085		103		280		196		155
Net income (loss)		(154,273)		24,946		11,071		4,503		69
Adjusted EBITDA (1)	$	153,572	$	114,409	$	81,130	$	63,484	$	51,285
DCF (1)(3)	$	120,850	$	85,927	$	56,210	$	34,928	$	22,789
Net income (loss) per common unit:
Basic	$	(3.15)	$	0.60	$	0.32	$	—	$	—
Diluted	$	(3.15)	$	0.60	$	0.32	$	—	$	—
Cash distributions declared per common unit:	$	2.09	$	2.01	$	1.73	$	—	$	—
Other Financial Data:
Capital expenditures (4)		285,054		387,914		159,547		179,977		133,264
Cash flows provided by (used in):
Operating activities		117,401		101,891		68,190		41,974		33,782
Investing activities		(278,158)		(380,523)		(153,946)		(178,589)		(140,444)
Financing activities		160,758		278,631		85,756		136,618		106,662
Balance Sheet Data (at period end):
Working capital (5)	$	(8,455)	$	(44,064)	$	(24,177)	$	(12,076)	$	(11,295)
Total assets		1,509,771		1,516,482		1,185,884		872,645		727,876
Long-term debt		729,187		594,864		420,933		502,266		363,773
Partners' equity		718,288		839,520		707,727		343,526		339,023

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(1) Please refer to “—Non-GAAP Financial Measures” section below.

(2) During the year ended December 31, 2011, we incurred $0.3 million of restructuring charges for severance and retention benefits related to the termination of certain administrative employees. These charges are reflected as restructuring charges in our consolidated statement of operations. These restructuring charges were paid in 2012.  

(3) DCF was previously presented as Adjusted DCF.  The definition of DCF is identical to the definition of Adjusted DCF previously presented.  For the definition of DCF, please refer to “—Non-GAAP Financial Measures” section below.

(4) On December 15, 2011, we purchased all of the compression units previously leased from Caterpillar for $43 million and terminated all of the lease schedules and covenants under the operating lease facility with Caterpillar. This amount is included in capital expenditures for the year ended December 31, 2011. On December 16, 2011, the Partnership entered into an agreement with a compression equipment supplier to reduce certain previously made progress payments from $10 million to $2 million. The Partnership applied this $8 million credit to new compression unit purchases from this supplier in the year ended December 31, 2012. Before the application of this credit, capital expenditures were $188.0 million for the year ended December 31, 2012.

(5) Working capital is defined as current assets minus current liabilities.

Non-GAAP Financial Measures

Gross Operating Margin

Gross operating margin is a non-GAAP financial measure. We define gross operating margin as revenue less cost of operations, exclusive of depreciation and amortization expense. We believe that gross operating margin is useful as a supplemental measure of our operating profitability. Gross operating margin is impacted primarily by the pricing trends for service operations and cost of operations, including labor rates for service technicians, volume and per unit costs for lubricant oils, quantity and pricing of routine preventative maintenance on compression units and property tax rates on compression units.  Gross operating margin should not be considered an alternative to, or more meaningful than, operating income (loss) or any other measure of financial performance presented in accordance with GAAP. Moreover, gross operating margin as presented may not be comparable to similarly titled measures of other companies. Because we capitalize assets, depreciation and amortization of equipment is a necessary element of our costs. To compensate for the limitations of gross operating margin as a measure of our performance, we believe that it is important to consider operating income (loss) determined under GAAP, as well as gross operating margin, to evaluate our operating profitability.

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The following table reconciles gross operating margin to operating income (loss), its most directly comparable GAAP financial measure, for each of the periods presented (in thousands):

	Year Ended December 31,
	2015		2014		2013		2012		2011
Revenues:
Contract operations	$	263,816	$	217,361	$	150,360	$	116,373	$	93,896
Parts and service		6,729		4,148		2,558		2,414		4,824
Total revenues		270,545		221,509		152,918		118,787		98,720
Cost of operations, exclusive of depreciation and amortization		81,539		74,035		48,097		37,796		39,605
Gross operating margin		189,006		147,474		104,821		80,991		59,115
Other operating and administrative costs and expenses:
Selling, general and administrative		40,950		38,718		27,587		18,269		12,726
Restructuring charges		-		-		-		-		300
Depreciation and amortization		85,238		71,156		52,917		41,880		32,738
Loss (gain) on sale of assets		(1,040)		(2,233)		284		266		178
Impairment of compression equipment		27,274		2,266		203		-		-
Impairment of goodwill		172,189		-		-		-		-
Total other operating and administrative costs and expenses		324,611		109,907		80,991		60,415		45,942
Operating income (loss)	$	(135,605)	$	37,567	$	23,830	$	20,576	$	13,173

Adjusted EBITDA

We define EBITDA as net income (loss) before net interest expense, depreciation and amortization expense, and income taxes. We define Adjusted EBITDA as EBITDA plus impairment of compression equipment, impairment of goodwill, interest income, unit-based compensation expense, restructuring charges, management fees, expenses under our operating lease with Caterpillar, certain transaction fees, loss (gain) on sale of assets, and transaction expenses. We view Adjusted EBITDA as one of our primary management tools, and we track this item on a monthly basis both as an absolute amount and as a percentage of revenue compared to the prior month, year-to-date, prior year and to budget. Adjusted EBITDA is used as a supplemental financial measure by our management and external users of our financial statements, such as investors and commercial banks, to assess:

· the financial performance of our assets without regard to the impact of financing methods, capital structure or historical cost basis of our assets;

· the viability of capital expenditure projects and the overall rates of return on alternative investment opportunities;

· the ability of our assets to generate cash sufficient to make debt payments and to make distributions; and

· our operating performance as compared to those of other companies in our industry without regard to the impact of financing methods and capital structure.

We believe that Adjusted EBITDA provides useful information to investors because, when viewed with our GAAP results and the accompanying reconciliations, it provides a more complete understanding of our performance than GAAP results alone. We also believe that external users of our financial statements benefit from having access to the same financial measures that management uses in evaluating the results of our business.

Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income (loss), operating income (loss), cash flows from operating activities or any other measure of financial performance presented in

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accordance with GAAP as measures of operating performance and liquidity. Moreover, our Adjusted EBITDA as presented may not be comparable to similarly titled measures of other companies.

Because we use capital assets, depreciation, impairment of compression equipment and the interest cost of acquiring compression equipment are also necessary elements of our costs. Expense related to unit-based compensation expense related to equity awards to employees is also a necessary component of our business. Therefore, measures that exclude these elements have material limitations. To compensate for these limitations, we believe that it is important to consider both net income (loss) and net cash provided by operating activities determined under GAAP, as well as Adjusted EBITDA, to evaluate our financial performance and our liquidity. Our Adjusted EBITDA excludes some, but not all, items that affect net income (loss) and net cash provided by operating activities, and these measures may vary among companies. Management compensates for the limitations of Adjusted EBITDA as an analytical tool by reviewing the comparable GAAP measures, understanding the differences between the measures and incorporating this knowledge into management’s decision making processes.

The following table reconciles Adjusted EBITDA to net income (loss) and net cash provided by operating activities, its most directly comparable GAAP financial measures, for each of the periods presented (in thousands):

	Year Ended December 31,
	2015		2014		2013		2012		2011
Net income (loss)	$	(154,273)	$	24,946	$	11,071	$	4,503	$	69
Interest expense, net		17,605		12,529		12,488		15,905		12,970
Depreciation and amortization		85,238		71,156		52,917		41,880		32,738
Income taxes		1,085		103		280		196		155
EBITDA	$	(50,345)	$	108,734	$	76,756	$	62,484	$	45,932
Impairment of compression equipment (1)		27,274		2,266		203		-		-
Impairment of goodwill (2)		172,189		-		-		-		-
Interest income on capital lease		1,631		1,274		-		-		-
Unit-based compensation expense (3)		3,863		3,034		1,343		-		-
Equipment operating lease expense (4)		-		-		-		-		4,053
Riverstone management fee (5)		-		-		49		1,000		1,000
Restructuring charges (6)		-		-		-		-		300
Transaction expenses for acquisitions (7)		-		1,299		2,142		-		-
Loss (gain) on sale of assets and other		(1,040)		(2,198)		637		-		-
Adjusted EBITDA	$	153,572	$	114,409	$	81,130	$	63,484	$	51,285
Interest expense, net		(17,605)		(12,529)		(12,488)		(15,905)		(12,970)
Income tax expense		(1,085)		(103)		(280)		(196)		(155)
Interest income on capital lease		(1,631)		(1,274)		-		-		-
Equipment operating lease expense		-		-		-		-		(4,053)
Riverstone management fee		-		-		(49)		(1,000)		(1,000)
Restructuring charge		-		-		-		-		(300)
Transaction expenses for acquisitions		-		(1,299)		(2,142)		-		-
Amortization of deferred financing costs and other		1,702		1,189		1,839		(58)		(920)
Changes in operating assets and liabilities		(17,552)		1,498		180		(4,351)		1,895
Net cash provided by operating activities	$	117,401	$	101,891	$	68,190	$	41,974	$	33,782

(1) Represents non-cash charges incurred to write down long-lived assets with recorded values that are not expected to be recovered through future cash flows.

(2) For further discussion of our goodwill impairment recorded for the year ended December 31, 2015, please refer to Item 7 (“Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates—Goodwill Impairment Assessments”).

(3) For the years ended December 31, 2015, 2014 and 2013, unit-based compensation expense included $0.9 million, $0.5 million and $0, respectively, of cash payments related to quarterly payments of distribution equivalent rights on

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outstanding phantom unit awards and $0.2 million, $0.3 million and $0, respectively, related to the cash portion of any settlement of phantom unit awards upon vesting. The remainder of the unit-based compensation expense for 2015 and 2014 is related to non-cash adjustments to the unit-based compensation liability, and for 2013 is related to the non-cash amortization of unit-based compensation in equity.

(4) Represents expenses for the respective periods under the operating lease facility with Caterpillar, from whom we historically leased compression units and other equipment. On December 15, 2011, we purchased the compression units that were previously leased from Caterpillar for $43 million and terminated all the lease schedules and covenants under the operating lease facility. As such, we believe it is useful to investors to view our results excluding these lease payments.

(5) Represents management fees paid to Riverstone for services performed during 2013, 2012 and 2011. We are no longer responsible for these fees following the closing of our initial public offering in January 2013.  As such, we believe it is useful to investors to view our results excluding these fees.

(6) During the year ended December 31, 2011, we incurred $0.3 million of restructuring charges for severance and retention benefits related to the termination of certain administrative employees. These charges are reflected as restructuring charges in our consolidated statement of operations. These restructuring charges were paid in 2012. We believe that it is useful to investors to view our results excluding this non-core expense.

(7) Represents the S&R Acquisition expenses incurred along with certain transaction expenses related to potential acquisitions and other items. The Partnership believes it is useful to investors to exclude these fees. 

Distributable Cash Flow

We define DCF as net income (loss) plus non-cash interest expense, non-cash income tax expense, depreciation and amortization expense, unit-based compensation expense, impairment of compression equipment, impairment of goodwill, certain transaction fees, and (gain) loss on sale of equipment, less maintenance capital expenditures. The definition of DCF is identical to the definition of Adjusted DCF previously presented.

We believe DCF is an important measure of operating performance because it allows management, investors and others to compare basic cash flows we generate (prior to the establishment of any retained cash reserves by our general partner and the effect of the DRIP) to the cash distributions we expect to pay our unitholders. Using DCF, management can quickly compute the coverage ratio of estimated cash flows to planned cash distributions.

DCF should not be considered an alternative to, or more meaningful than, net income (loss), operating income (loss), cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP as measures of operating performance and liquidity. Moreover, our DCF as presented may not be comparable to similarly titled measures of other companies.

Because we use capital assets, depreciation and impairment of compression equipment, (gain) loss on sale of assets, and maintenance capital expenditures are necessary elements of our costs. Expense related to unit-based compensation expense related to equity awards to employees is also a necessary component of our business. Therefore, measures that exclude these elements have material limitations. To compensate for these limitations, we believe that it is important to consider both net income (loss) and net cash provided by operating activities determined under GAAP, as well as DCF, to evaluate our financial performance and our liquidity. Our DCF excludes some, but not all, items that affect net income (loss) and net cash provided by operating activities, and these measures may vary among companies. Management compensates for the limitations of DCF as an analytical tool by reviewing the comparable GAAP measures, understanding the differences between the measures and incorporating this knowledge into management’s decision making processes.

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The following table reconciles DCF to net income (loss) and net cash provided by operating activities, its most directly comparable GAAP financial measures, for each of the periods presented (in thousands):

	Year Ended December 31,
	2015		2014		2013		2012		2011
Net income (loss)	$	(154,273)	$	24,946	$	11,071	$	4,503	$	69
Plus: Non-cash interest expense		1,702		1,224		2,201		1,855		(1,057)
Plus: Non-cash income tax expense		874		-		-		-		-
Plus: Depreciation and amortization		85,238		71,156		52,917		41,880		32,738
Plus: Unit-based compensation expense (1)		3,863		3,034		1,343		-		-
Plus: Impairment of compression equipment		27,274		2,266		203		-		-
Plus: Impairment of goodwill		172,189		-		-		-		-
Plus: Transaction expenses for acquisitions (2)		-		1,299		2,142		-		-
Plus: Loss (gain) on sale of assets and other		117		(2,198)		637		-		-
Less: Maintenance capital expenditures (3)		(16,134)		(15,800)		(14,304)		(13,310)		(8,961)
DCF (4)	$	120,850	$	85,927	$	56,210	$	34,928	$	22,789
Plus: Maintenance capital expenditures		16,134		15,800		14,304		13,310		8,961
Plus: Net gain on change in fair value of interest rate swap		-		-		-		(2,180)		(2,629)
Plus: Change in working capital		(17,552)		1,498		180		(4,351)		1,897
Less: Transaction expenses for acquisitions		-		(1,299)		(2,142)		-		-
Less: Other		(2,031)		(35)		(362)		267		2,764
Net cash provided by operating activities	$	117,401	$	101,891	$	68,190	$	41,974	$	33,782

(1) For the years ended December 31, 2015, 2014 and 2013, unit-based compensation expense includes $0.9 million, $0.5 million and $0, respectively, of cash payments related to quarterly payments of distribution equivalent rights on phantom unit awards and $0.2 million, $0.3 million and $0, respectively, related to the cash portion of any settlement of phantom units upon vesting. The remainder of the unit-based compensation expense for 2015 and 2014 is related to non-cash adjustments to the unit-based compensation liability, and for 2013 is related to the non-cash amortization of unit-based compensation in equity.

(2) Represents the S&R Acquisition expenses incurred along with certain transaction expenses related to potential acquisitions and other items.  The Partnership believes it is useful to investors to exclude these fees.

(3) Reflects maintenance capital expenditures for the period presented. Maintenance capital expenditures are capital expenditures made to maintain the operating capacity of our assets and extend their useful lives, to replace partially or fully depreciated assets or other capital expenditures that are incurred in maintaining our existing business and related operating income.

(4) DCF was previously presented as Adjusted DCF. 

Coverage Ratios

DCF Coverage Ratio is defined as DCF less cash distributions to the Partnership’s general partner and IDRs, divided by distributions declared to limited partner unitholders for the period. Cash Coverage Ratio is defined as DCF less cash distributions to the Partnership’s general partner and IDRs divided by cash distributions paid to limited partner unitholders, after taking into account the non-cash impact of the DRIP. We believe DCF Coverage Ratio and Cash Coverage Ratio are important measures of operating performance because they allow management, investors and others to gauge our ability to pay cash distributions to limited partner unitholders using the cash flows that we generate. Our DCF Coverage Ratio and Cash Coverage Ratio as presented may not be comparable to similarly titled measures of other companies.

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The following table summarizes certain coverage ratios for the periods presented (dollars in thousands).

	Year Ended December 31,
	2015		2014		2013
DCF (1)	$	120,850	$	85,927	$	56,210
General partner interest in DCF		2,658		1,947		1,188
Pre-IPO DCF		-		-		2,323
DCF attributable to limited partner interest	$	118,192	$	83,980	$	52,699
Distributions for DCF coverage ratio (2)	$	101,266	$	85,098	$	55,961
Distributions reinvested in the DRIP (3)	$	55,489	$	52,556	$	36,694
Distributions for Cash Coverage Ratio (4)	$	45,777	$	32,542	$	19,267
DCF Coverage Ratio (5)		1.17		0.99		0.94
Cash Coverage Ratio (6)		2.58		2.58		2.74

(1) DCF was previously presented as Adjusted DCF. 

(2) Represents distributions to the holders of the Partnership’s units, after giving effect to the weighted average common units outstanding, due to our May 2014 and September 2015 public equity offerings and S&R Acquisition in August 2013, for the years ended December 31, 2015, 2014 and 2013, as applicable.  

(3) Represents distributions to holders enrolled in the DRIP as of the record date for each period.

(4) Represents cash distributions declared for common and subordinated units not participating in the DRIP, after giving effect to the weighted average of units outstanding for each period due to our May 2014 and September 2015 public equity offerings and the S&R Acquisition, as applicable, for the years ended December 31, 2015, 2014 and 2013.  

(5) For the years ended December 31, 2015,  2014 and 2013, the DCF Coverage Ratio based on units outstanding at the respective record dates was 1.15x, 0.97x and 0.91x, respectively.For the year ended December 31, 2013, pre-initial public offering DCF was not included in the calculation for the DCF Coverage Ratio.

(6) For the years ended December 31, 2015, 2014 and 2013, the Cash Coverage Ratio based on units outstanding at the respective record dates was 2.48x, 2.46x and 2.74x, respectively.  For the year ended December 31, 2013, pre-initial public offering DCF was not included in the calculation for the Cash Coverage Ratio.

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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 consolidated 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”).

Overview

We provide compression services in a number of shale plays throughout the U.S., including the Utica, Marcellus, Permian Basin, Delaware Basin, Eagle Ford, Mississippi Lime, Granite Wash, Woodford, Barnett, Haynesville, Niobrara and Fayetteville shales. The demand for our services is driven by the domestic production of natural gas and crude oil; as such, we have focused our activities in areas of attractive production growth, which are generally found in these shale and unconventional resource plays.  According to recent studies promulgated by the Energy Information Agency (“EIA”), the overall natural gas production and transportation volumes from domestic shale plays are expected to increase over the long term due to the comparably attractive economic returns versus returns achieved in many conventional basins. Furthermore, the changes in production volumes and pressures of shale plays over time require a wider range of compression services than in conventional basins. We believe the flexibility of our compression units positions us well to meet these changing operating conditions. While our business focuses largely on compression services serving infrastructure installations, including centralized natural gas gathering systems and processing facilities, which utilize large horsepower compression units, typically in shale plays, we also provide compression services in more mature conventional basins, including gas lift applications on crude oil wells targeted by horizontal drilling techniques. Gas lift and other artificial lift technologies are critical to the enhancement of production of oil from horizontal wells operating in tight shale plays. Gas lift is a process by which natural gas is injected into the production tubing of an existing producing well, thus reducing the hydrostatic pressure and allowing the oil to flow at a higher rate.

General Trends and Outlook

Since late 2014, both crude oil and natural gas prices have declined significantly and have remained depressed. Our business depends on the production of natural gas and crude oil. While our business does not have direct exposure to commodity prices, the current price environment has resulted in a slowdown in activity in many domestic producing regions, particularly in those plays where producers target oil or other liquids and natural gas plays with relatively higher production costs. We believe this decreased level of operating activity has led, and could continue to lead, to less, or more delayed, incremental demand for compression services than in the recent past. However, existing production will continue to require compression, so we expect our customers will continue to seek our infrastructure-oriented compression services.

A significant amount of our assets is utilized in natural gas infrastructure applications, primarily in centralized gathering systems and processing facilities. Given the project nature of these applications and long-term investment horizon of our customers, we have generally experienced stability in rates and higher sustained utilization rates relative to other businesses more tied to drilling activity and wellhead economics. As a result of the slowdown in new drilling activity in certain operating areas, as well as slowing or flattening of production growth in other areas, we expect to see and are experiencing pressure on service rates for new and existing services and a decline in utilization relative to the recent past. In addition, a small portion of our fleet is used in connection with crude oil production using horizontal drilling techniques.  Given the more pronounced decrease in the price of crude oil, we have also experienced pressure on service rates from our customers in gas lift applications, and expect that this trend could continue if prices remain depressed and activity levels remain low. For those gas lift contracts where we have made rate concessions, we have typically been able to secure some combination of future order commitments and exclusive service provider status agreements from our customers to help offset the decrease in pricing.

We continue to monitor developments in our customer base, and we believe that there will continue to be demand for our services given the necessity of compression services in allowing for the transportation and processing of natural gas as well as the production of crude oil, although management cannot predict any possible changes in such demand with reasonable certainty.  The steep decline in commodity prices has caused many of our customers to reconsider near-

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term capital budgets as well as to reexamine and optimize their compression needs, which impacts the associated demand for compression related to large-scale natural gas infrastructure and crude oil production activities. Due to the general slowdown in new activity and this lack of visibility as to our customers’ needs in 2016, we intend to significantly scale back capital spending for new compression units and continue to focus on keeping our existing fleet of infrastructure-oriented equipment highly utilized. We intend to direct our growth opportunities to the projects with the highest economic returns – typically represented by the large horsepower units that tend to generate higher margins and command longer contract terms. Additionally, we plan to utilize currently idle or recently-returned and refurbished compression units to meet customer demand, to the extent possible. However, in the event that commodity prices and activity levels rebound quickly, we believe we will be able to quickly respond to such changes in demand given current general compression equipment trends, including lead times and fabrication capacity. Although lead-times for new engines and new compressor frames have in the past been in excess of one year, lead-times for such components are currently substantially shorter, and our fabricators have generally had ample availability in their queues.

Our ability to increase our revenues is dependent in large part on our ability to add new revenue generating compression units to our fleet while maintaining our utilization and contract rates. For the year ended December 31, 2015, we increased our fleet size while maintaining high utilization and economically attractive service rates.  Revenue generating horsepower increased by 5.4% from December 31, 2014 to December 31, 2015.  Average revenue generating horsepower increased by 17.3% from the year ended December 31, 2014 to the year ended December 31, 2015.  Average revenue per revenue generating horsepower per month increased approximately 2% from the year ended December 31, 2014 to the year ended December 31, 2015. Average utilization decreased approximately 4% from the year ended December 31, 2014 to the year ended December 31, 2015.  The decrease in utilization is attributable to both an increase in the amount of time contracting new compression units and an increase in the amount of compression units returned to us.  We believe this is the result of a delay in planned projects of certain of our customers and continued optimization of existing compression service requirements.

The EIA has projected that natural gas production growth will continue in the coming years due to increases in drilling efficiencies as well as a backlog of drilled but uncompleted wells in major supply areas, such as the Marcellus Shale. Additionally, according to the EIA, domestic exports, both to Mexico and through the start-up of various liquefied natural gas (“LNG”) projects in late 2015 and beyond, will increase and this increased demand should keep pace with increasing supply growth. The EIA projects that approximately 70% of the increase in natural gas production through 2040 will come from shale plays, which typically require greater compression horsepower than conventional production.  We believe this long-term increasing demand for natural gas will create increasing demand for compression services, for both existing natural gas fields as they age and for the development of new natural gas fields. In the short-term, changes in natural gas pricing, based primarily upon the supply of natural gas, will affect the development activities of natural gas producers based upon the costs associated with finding and producing natural gas in the particular natural gas and oil fields in which they are active. Although declines in natural gas prices have a negative effect on the development activity in natural gas fields, periods of lower development activity tend to place emphasis on improving production efficiency. As a result of our commitment to providing a high level of availability of the equipment used to provide compression services, we believe our service run times position us to satisfy the needs of our customers.

The continued development of horizontal drilling, particularly in crude oil wells, has allowed producers to produce incremental volumes of crude oil from tight oil formations. We believe that our flexible fleet of smaller horsepower units that are primarily utilized in gas lift applications will enable us to capitalize on this market demand. While the sharp decline in global crude oil prices has led to a decline in overall drilling activity, domestic producers’ efficiency gains and drilling and completion cost reductions have resulted in a slower corresponding decline in crude oil production. After overall domestic crude oil production began to fall in mid-2015, the EIA now expects domestic crude production to continue to decline through 2017. However, it expects to see continued drilling activity in the core areas of the major tight oil plays in 2016, due to the economic benefit of the aforementioned efficiency gains and declines in drilling and completion costs.

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Operating Highlights

The following table summarizes certain horsepower and horsepower utilization percentages for the periods presented.

	Year Ended December 31,									Percent Change
Operating Data (unaudited):	2015			2014			2013			2015		2014
Fleet horsepower (at period end) (1)		1,712,196			1,549,020			1,202,374		10.5	%	28.8	%
Total available horsepower (at period end) (2)		1,712,196			1,623,400			1,278,829		5.5	%	26.9	%
Revenue generating horsepower (at period end) (3)		1,424,537			1,351,052			1,070,457		5.4	%	26.2	%
Average revenue generating horsepower (4)		1,408,689			1,200,851			902,168		17.3	%	33.1	%
Average revenue per revenue generating horsepower per month	$	15.90		$	15.57		$	14.15		2.1	%	10.0	%
Revenue generating compression units (at period end)		2,737			2,651			2,137		3.2	%	24.1	%
Average horsepower per revenue generating compression unit (5)		517			505			720		2.4	%	(29.9)	%
Horsepower utilization (6):
At period end		89.2	%		93.6	%		94.1	%	(4.7)	%	(0.5)	%
Average for the period (7)		90.5	%		94.0	%		93.8	%	(3.7)	%	0.2	%

(1) Fleet horsepower is horsepower for compression units that have been delivered to us (and excludes units on order). As of December 31, 2015, we had 15,400 horsepower on order for delivery during 2016.

(2) Total available horsepower is revenue generating horsepower under contract for which we are billing a customer, horsepower in our fleet that is under contract but is not yet generating revenue, horsepower not yet in our fleet that is under contract but not yet generating revenue and that is subject to a purchase order, and idle horsepower. Total available horsepower excludes new horsepower on order for which we do not have a compression services contract.

(3) Revenue generating horsepower is horsepower under contract for which we are billing a customer.

(4) Calculated as the average of the month-end revenue generating horsepower for each of the months in the period.

(5) Calculated as the average of the month-end revenue generating horsepower per revenue generating compression unit for each of the months in the period.

(6) Horsepower utilization is calculated as (i) the sum of (a) revenue generating horsepower, (b) horsepower in our fleet that is under contract but is not yet generating revenue, and (c) horsepower not yet in our fleet that is under contract, not yet generating revenue and that is subject to a purchase order, divided by (ii) total available horsepower less idle horsepower that is under repair. Horsepower utilization based on revenue generating horsepower and fleet horsepower at each applicable period end was 83.2%, 87.2% and 89.0%, for the years ended December 31, 2015, 2014 and 2013, respectively.

(7) Calculated as the average utilization for the months in the period based on utilization at the end of each month in the period.  Average horsepower utilization based on revenue generating horsepower was 85.1%, 87.3% and 87.3% for each year ended December 31, 2015, 2014 and 2013, respectively.

The 10.5% increase in fleet horsepower as of December 31, 2015 over the fleet horsepower as of December 31, 2014 was attributable to new compression units added to our fleet to meet anticipated demand by new and current customers. The 5.4% increase in revenue generating horsepower as of December 31, 2015 over December 31, 2014 was primarily due to organic growth in our active fleet. The 2.4% increase in average horsepower per revenue generating compression unit as of December 31, 2015 over December 31, 2014 was primarily due to the addition of large horsepower compression units in the operating fleet over the year ended December 31, 2015.

The 28.8% increase in fleet horsepower as of December 31, 2014 over the fleet horsepower as of December 31, 2013 was attributable to new compression units added to our fleet to meet the incremental demand by new and current

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customers.  The 26.2% increase in revenue generating horsepower as of December 31, 2014 over December 31, 2013 was primarily due to organic growth in our large horsepower fleet. The 29.9% decrease in average horsepower per revenue generating compression unit as of December 31, 2014 over December 31, 2013 was primarily due to the addition of a fleet of smaller horsepower units in connection with the S&R Acquisition in the fourth quarter of 2013, which had the effect of decreasing the average horsepower per revenue generating compression unit over the year ended December 31, 2014.

	Year Ended December 31,									Percent Change
Other Financial Data: (1)	2015			2014			2013			2015		2014
	(in thousands)
Gross operating margin	$	189,006		$	147,474		$	104,821		28.2	%	40.7	%
Gross operating margin percentage (2)		69.9	%		66.6	%		68.5	%	4.9	%	(2.9)	%
Adjusted EBITDA	$	153,572		$	114,409		$	81,130		34.2	%	41.0	%
Adjusted EBITDA percentage (2)		56.8	%		51.6	%		53.1	%	9.9	%	(2.6)	%
DCF (3)	$	120,850		$	85,927		$	56,210		40.6	%	52.9	%
DCF Coverage Ratio (3)		1.17	x		0.99	x		0.94		18.3	%	4.8	%
Cash Coverage Ratio		2.58	x		2.58	x		2.74		0.0	%	(5.6)	%

(1) Gross operating margin, Adjusted EBITDA, DCF,  DCF Coverage and Cash Coverage are all non-GAAP financial measures. Definitions of each measure, as well as reconciliations of each measure to its most directly comparable financial measurer(s) calculated and presented in accordance with GAAP, can be found under the caption “Non-GAAP Financial Measures” in Part II, Item 6.

(2) Gross operating margin percentage and Adjusted EBITDA percentage are calculated as a percentage of revenue.

(3) DCF and DCF Coverage Ratio were previously presented as Adjusted DCF and Adjusted DCF Coverage Ratio, respectively.  The definitions of DCF and DCF Coverage Ratio are identical to the definition of Adjusted DCF and Adjusted DCF Coverage Ratio, respectively, as previously presented.  Definitions of DCF and DCF Coverage Ratio can be found under the caption “Non-GAAP Financial Measures” in Part II, Item 6.

Adjusted EBITDA.The increase in Adjusted EBITDA during the year ended December 31, 2015 was primarily attributable to higher gross operating margin as a result of a 17.3% increase in average revenue generating horsepower during 2015 and an approximate 3.3% increase in gross operating margin percentage due primarily to certain cost savings initiatives, timing of certain preventative maintenance activities and lower fuel costs.

The increase in Adjusted EBITDA during the year ended December 31, 2014 was primarily attributable to higher gross operating margin as a result of a 33.1% increase in average revenue generating horsepower during 2014 and a full year impact of the horsepower added in 2013 both organically and through the S&R Acquisition, partially offset by higher selling, general and administrative expense.

Distributable Cash Flow.  The increase in DCF during the year ended December 31, 2015 was primarily due to increases in the gross operating margin as a result of a 17.3% increase in average revenue generating horsepower during 2015 and an approximate 3.3% increase in gross operating margin percentage due primarily to certain cost savings initiatives, timing of certain preventative maintenance activities and lower fuel costs, partiallyoffset by higher selling, general and administrative expense, higher maintenance capital expenditures, and higher cash interest expense, net.  

The increase in DCF during the year ended December 31, 2014 was primarily due to increases in the gross operating margin as a result of a 33.1% increase in average revenue generating horsepower during 2014 and a full year impact of the horsepower added in 2013 both organically and through the S&R Acquisition, partially offset by higher selling, general and administrative expense, higher maintenance capital expenditures, and higher cash interest expense, net.

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Financial Results of Operations

Year ended December 31, 2015 compared to the year ended December 31, 2014

The following table summarizes our results of operations for the periods presented (dollars in thousands):

	Year Ended December 31,				Percent
	2015		2014		Change
Revenues:
Contract operations	$	263,816	$	217,361		21.4	%
Parts and service		6,729		4,148		62.2	%
Total revenues		270,545		221,509		22.1	%
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		81,539		74,035		10.1	%
Gross operating margin		189,006		147,474		28.2	%
Other operating and administrative costs and expenses:
Selling, general and administrative		40,950		38,718		5.8	%
Depreciation and amortization		85,238		71,156		19.8	%
Loss (gain) on sale of assets		(1,040)		(2,233)		(53.4)	%
Impairment of compression equipment		27,274		2,266		1,103.6	%
Impairment of goodwill		172,189		-		*
Total other operating and administrative costs and expenses		324,611		109,907		195.4	%
Operating income (loss)		(135,605)		37,567		(461.0)	%
Other income (expense):
Interest expense, net		(17,605)		(12,529)		40.5	%
Other		22		11		100.0	%
Total other expense		(17,583)		(12,518)		40.5	%
Income (loss) before income tax expense		(153,188)		25,049		(711.6)	%
Income tax expense		1,085		103		953.4	%
Net income (loss)	$	(154,273)	$	24,946		(718.4)	%

* Not meaningful.

Contract operations revenue.  During 2015, we experienced an increase in demand for our compression services driven by an increase in overall natural gas production in the U.S., resulting in a 17.3% increase in average revenue generating horsepower and a $46.5 million increase in our contract operations revenue.  Average revenue per revenue generating horsepower per month increased from $15.57 for the year ended December 31, 2014 to $15.90 for the year ended December 31, 2015, an increase of 2.1%, attributable, in part, to growth in the small horsepower fleet, which earns higher revenue per horsepower, in addition to improved pricing in the large horsepower fleet. Because the demand for our services is driven primarily by production of natural gas, we focus our activities in areas of attractive growth, which are generally found in certain shale and unconventional resource plays, as discussed above under the heading “Overview.” 

Parts and service revenue.  Parts and service revenue was earned primarily on freight and crane charges that are directly reimbursable by our customers, for which we earnlittle to no margin, and maintenance work on units at our customers’ locations that are outside the scope of our core maintenance activities, for which we earn lower margins than our contract operations.  We offered these services as a courtesy to our customers and the demand fluctuates from period to period based on the varying needs of our customers.

Cost of operations, exclusive of depreciation and amortization. The $7.5 million increase in cost of operations was primarily attributable to the increase in our active fleet size due to organic growth. Certain cost increases consisted of (1) a $3.9 million increase in direct labor expenses, (2) a $3.1 million increase in direct expensessuch as parts and service expenses, which have a corresponding increase in parts and service revenue, and (3) a $1.9 million increase in indirect expenses, the majority of which were higher property taxes, offset by a $1.1 million decrease in fuel costs.

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Gross operating margin. The $41.5 million increase in gross operating margin was due to higher revenues partially offset by higher operating expenses during the year ended December 31, 2015. The 3.3% increase in gross operating margin percentage from 66.6% for the year ended December 31, 2014 to 69.9% for the year ended December 31, 2015 was attributable to (1) certain cost savings initiatives, (2) timing of certain preventative maintenance activities and (3) lower fuel costs.

Selling, general and administrative expense.  The $2.2 million increase in selling, general and administrative expense for the year ended December 31, 2015was primarily attributable to a $3.0 million increase in salaries and benefits expenses and a $1.5 million increase in bad debt expense offset by a $1.3 million decrease in transaction expenses and a $1.0 million decrease in professional fees. 

Depreciation and amortization expense. The $14.1 million increase in depreciation expense was related to an increase in gross property and equipment balances during the year ended December 31, 2015 compared to gross balances during the year ended December 31, 2014.  There is no variance in amortization expense between the periods, as intangible assets are amortized on a straight-line basis and there has been no change in gross identifiable intangible assets between the periods.

(Gain) on sale of assets.  The $1.0 million gain on sale of assets during the year ended December 31, 2015 was primarily attributable to $1.2 million cash insurance recoveries on previously impaired compression equipment received during the year and $1.1 million gain on sale of 18 units, or 7,200 horsepower, offset by $1.3 million of losses incurred in the disposal of various unit and non-unit assets.

Impairment of compression equipment.  A majority of the $27.3 million impairment charge during the year ended December 31, 2015 resulted from our evaluation of the future deployment of our current idle fleet under the current market conditions.  As a result of our evaluation during the second quarter of 2015, we determined to retire and either sell or re-utilize the key components of 166 compressor units, or approximately 58,000 horsepower, that had been previously used to provide compression services in our business. 

Goodwill impairment.During the fourth quarter of 2015, we recorded a $172.2 million impairment of goodwill due primarily to the decline in our unit price, the sustained decline in global commodity prices, expected reduction in the capital budgets of certain of our customers and the impact these factors have on our expected future cash flows.  There was no impairment of goodwill for the year ended December 31, 2014.

Interest expense, net.  The $5.1 million increase in interest expense, net was primarily attributable to the impact of an approximately  $224.6 million increase in average outstanding borrowings under our revolving credit facility,  in which average borrowings were $723.3 million for the year ended December 31, 2015 compared to $498.7 million for the year ended December 31, 2014.  Our revolving credit facility had an interest rate of 2.26% and 2.16%  at December 31, 2015 and 2014, respectively, and an average interest rate of 2.24% and 2.22% during December 31, 2015 and 2014, respectively.

Income tax expense.  This line item represents the Revised Texas Franchise Tax (“Texas Margin Tax”).  The increase in income tax expense for the year ended December 31, 2015 compared to December 31, 2014 was primarily associated with the establishment of a deferred tax liability reflecting the book/tax basis difference in our property and equipment. 

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Year ended December 31, 2014 compared to the year ended December 31, 2013

The following table summarizes our results of operations for the periods presented (dollars in thousands):

	Year Ended December 31,				Percent
	2014		2013		Change
Revenues:
Contract operations	$	217,361	$	150,360		44.6	%
Parts and service		4,148		2,558		62.2	%
Total revenues		221,509		152,918		44.9	%
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		74,035		48,097		53.9	%
Gross operating margin		147,474		104,821
Other operating and administrative costs and expenses:
Selling, general and administrative		38,718		27,587		40.3	%
Depreciation and amortization		71,156		52,917		34.5	%
Loss (gain) on sale of assets		(2,233)		284		(886.3)	%
Impairment of compression equipment		2,266		203		1,016.3	%
Total other operating and administrative costs and expenses		109,907		80,991		35.7	%
Operating income		37,567		23,830		57.6	%
Other income (expense):
Interest expense		(12,529)		(12,488)		0.3	%
Other		11		9		22.2	%
Total other expense		(12,518)		(12,479)		0.3	%
Income before income tax expense		25,049		11,351		120.7	%
Income tax expense		103		280		(63.2)	%
Net income	$	24,946	$	11,071		125.3	%

Contract operations revenue. During 2014, we saw an increase in overall natural gas activity in the U.S. and experienced an increase in demand for our compression services.  Because the demand for our services is driven primarily by production of natural gas, we focus our activities in areas of attractive growth, which are generally found in certain shale and unconventional resource plays, as discussed above under the heading “Overview.”  The 33.1% increase in average revenue generating horsepower was primarily due to organic growth along with the full year impact of the addition of assets in connection with the S&R Acquisition in August 2013. Average revenue per revenue generating horsepower per month increased by 10.0%, primarily due to higher revenue per horsepower per month from the full year impact of the addition of smaller horsepower compression units in connection with the S&R Acquisition and organic growth thereafter. Smaller horsepower compression units typically generate higher revenue per horsepower per month than large horsepower compression units. The 24.1% increase in revenue generating compression units and the 26.2% increase in revenue generating horsepower as of December 31, 2014 was primarily due to organic growth.

Parts and service revenue.Parts and service revenue was earned primarily on freight and crane charges that are directly reimbursable by our customers, for which we earnlittle to no margin, and maintenance work on units at our customers’ locations that are outside the scope of our core maintenance activities, for which we earn lower margins than our contract operations.  We offered these services as a courtesy to our customers and the demand fluctuates from period to period based on the varying needs of our customers.

Cost of operations, exclusive of depreciation and amortization. The increase in cost of operations was primarily attributable to the increase in our fleet size. Certain cost increases consisted of (1) a $9.2 million increase in direct labor expenses, (2) a $4.5 million increase in lubrication oil expenses due to an 88.3% increase in gallons consumed, partially offset by a 2.9% decrease in the average price per gallon paid, (3) a $3.1 million increase in property taxes, (4) a $2.7 million increase in maintenance parts, (5) a $2.0 million increase in retail parts and services, (6) a $1.7 million increase related to the vehicle fleet, and (7) a $0.9 million increase in training and safety expense. The 88.3% increase in gallons of lubrication oil consumed was a result of an increase in the number of smaller horsepower gas lift units within our fleet for which we are responsible for providing fluids.  The cost of fluids was generally included in service fees quoted to

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customers. These factors were primarily attributable to the increase in our fleet size due to organic growth, along with a full year of operations related to assets acquired in connection with the S&R Acquisition.

Gross operating margin. The $42.7 million increase in gross operating margin was due to higher revenues offset by higher operating expenses during the year. The 1.9% decrease in gross operating margin percentage from 68.5% for the year ended December 31, 2013 to 66.5% for the year ended December 31, 2014 was partially attributable to (1) an increase in property taxes for the units acquired in the S&R Acquisition, (2) higher parts costs associated with the larger horsepower units placed in late 2013 and throughout 2014, and (3) an increase in remote monitoring expenses as we continue to add the monitoring service to more compression units in our fleet.

Selling, general and administrative expense. Approximately $6.0 million of the increase in selling, general and administrative expense was related to a rise in salaries and benefits related to (i) an increase in employee headcount to support operations and sales management and (ii) the addition of certain additional executive positions. Additionally, we expensed an additional $1.7 million of unit-based compensation expense related to the issuance of phantom units in 2014 under our 2013 Long-Term Incentive Plan (the “LTIP”), along with a $0.5 million increase in professional fees. The selling, general and administrative employee headcount was 110 as of December 31, 2014, a 37.5% increase from December 31, 2013. The selling, general and administrative employee headcount increased to support the continued growth of the business, including growth resulting from the S&R Acquisition.

Depreciation and amortization expense. The $17.9 million increase in depreciation expense was related to an increase in gross property and equipment balances during 2014 and a full year impact of depreciation expense on assets acquired in connection with the S&R Acquisition.  The $0.4 million increase in amortization expense was primarily due to a full year of amortization expense on intangible assets acquired in connection with the S&R Acquisition.

Impairment of compression equipment.  During 2014 we evaluated the future deployment of our idle fleet and, as a result, recognized impairment on certain compression units and reduced the book value of each such unit to its estimated fair value.  The fair value of each such unit was estimated based on an analysis of the expected net sale proceeds compared to other recently sold compression units in our fleet, other units recently offered for sale by third parties, and the estimated component value of the compression units of a similar type remaining in our fleet.

Interest expense, net. The increase in net interest expense was attributable to the impact of a $127.9 million increase in average outstanding borrowings, offset by a $0.9 million decrease in amortization of deferred loan costs, $1.3 million of interest income related to the Capital Lease Transaction (as defined in Note 5 of our consolidated financial statements) and lower interest rates.  Average borrowings outstanding under our revolving credit facility were $498.7 million for the year ended December 31, 2014 compared to $370.8 million for the year ended December 31, 2013. Our revolving credit facility had an average interest rate of 2.22% and 2.43% during December 31, 2014 and 2013, respectively.

Income tax expense. This line item represents the Texas Margin Tax. We incurred $102,738 and $279,972 in Texas Margin Tax for the years ended December 31, 2014 and 2013, respectively.

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Liquidity and Capital Resources

Overview

We operate in a capital-intensive industry, and our primary liquidity needs are to finance the purchase of additional compression units and make other capital expenditures, service our debt, fund working capital, and pay distributions. Our principal sources of liquidity include cash generated by operating activities, borrowings under our revolving credit facility and issuances of debt and equity securities, including under the DRIP.

We believe cash generated by operating activities and, where necessary, borrowings under our revolving credit facility will be sufficient to service our debt, fund working capital, fund our estimated 2016 expansion capital expenditures and fund our maintenance capital expenditures.  Because we distribute all of our available cash, which excludes prudent operating reserves, we expect to fund any future expansion capital expenditures or acquisitions primarily with capital from external financing sources, such as borrowings under our revolving credit facility and issuances of debt and equity securities, including under the DRIP.  

We are not aware of any regulatory changes or environmental liabilities that we currently expect to have a material impact on our current or future operations. Please see “—Capital Expenditures” below.

Cash Flows

The following table summarizes our sources and uses of cash for the years ended December 31, 2015, 2014 and 2013 (in thousands):

	Year Ended December 31,
	2015		2014		2013
Net cash provided by operating activities	$	117,401	$	101,891	$	68,190
Net cash used in investing activities		(278,158)		(380,523)		(153,946)
Net cash provided by financing activities		160,758		278,631		85,756

Net cash provided by operating activities.  The $15.5 million increase in net cash provided by operating activities from the year ended December 31, 2014 to the year ended December 31, 2015 relates primarily to a  $41.5 million increase in gross operating margin, offset by a $9.4 million increase in inventory purchases, a $6.0 million increase in payroll and benefits payments,  a $4.6 million increase in cash interest paid, $3.9 million increase in property tax payments, and a $1.4 million increase in selling, general and administrative expenses, excluding unit-based compensation expense.

Net cash provided by operating activities increased for the year ended December 31, 2014 from the year ended December 31, 2013. The increase relates primarily to higher gross operating margin offset by higher selling, general and administrative expenses.

Net cash used in investing activities. For the year ended December 31, 2015, net cash used in investing activities relatedprimarily to purchases of new compression units and related equipment in response to increased demand for our services and maintenance capital expenditures made to maintain or replace existing assets and operating capacity, partially offset by $1.7 million of proceeds from the sale of equipment during 2015 and $1.2 million of proceeds from insurance recoveries on previously impaired compression units during 2015.

For the year ended December 31, 2014, net cash used in investing activities related primarily to the purchase of new compression units and related equipment in response to increased demand and maintenance capital expenditures made to maintain or replace existing assets and operating capacity, partially offset by $1.4 million of proceeds from the sale of equipment during 2014. 

For the year ended December 31, 2013, net cash used in investing activities related primarily to the purchase of new compression units and maintenance capital expenditures made to maintain or replace existing assets and operating

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capacity, partiallyoffset by $2.2 million of proceeds from the sale of equipment during 2013and cash received as part of a purchase price adjustment related to the S&R Acquisition of $3.4 million during2013. 

Net cash provided by financing activities.  During 2015, we borrowed $134.3 million, on a net basis, primarily to support our purchases of new compression units and related equipment, as described above.  During September 2015, we completed a public equity offering and utilized net proceeds of $75.1 million to reduce indebtedness outstanding under our revolving credit facility.  Additionally, in January 2015, we paid various loan fees and incurred costs of $3.4 million related to an amendment to our revolving credit facility.  During 2015, we made cash distributions to our unitholders of $45.1 million. 

For the year ended December 31, 2014, we borrowed $173.9 million, on a net basis, primarilyto support our purchases of new compression units and related equipment, as described above. During May 2014, we completed an equity offering and utilized the net proceeds of $138.0 million to reduce indebtedness outstanding under our revolving credit facility. Additionally during 2014, we also made distributions to our unitholders of $32.3 million.

For the year ended December 31, 2013, we borrowed $81.3 million, on a net basis, primarily to support our purchases of new compression units and related equipment.  We utilized $180.6 million in proceeds from our initial public offering to reduce indebtedness outstanding under our revolving credit facility. During 2013, we also made distributions to our unitholders of $14.7 million.

Equity Offerings

On September 15, 2015, the Partnership closed a public offering of 4,000,000 common units at a price to the public of $19.33 per common unit.  The Partnership used the net proceeds of $74.4 million (net of underwriting discounts and commission and offering expenses) to reduce the indebtedness outstanding under our revolving credit facility.

On May 21, 2015,we issued34,921 commonunits in a private placement to Argonaut for $0.7 million in a transaction that was exempt from registration under Section 4(a)(2) of the Securities Act of 1933, as amended (the “Securities Act”). We used the proceeds from the private placementfor general partnership purposes.  

In May 2014, the Partnership closed a public offering of 5,600,000 common units at a price to the public of $25.59 per common unit.  The Partnership used the net proceeds of $138.0 million(net of underwriting discounts and commission and offering expenses) to reduce the indebtedness outstanding under our revolving credit facility. In connection with this offering, certain selling unitholders, including USA Compression Holdings and Argonaut, sold a combined total of 1,990,000 common units. We did not receive any proceeds from the common units sold by such selling unitholders.

Capital Expenditures

The compression business is capital intensive, requiring significant investment to maintain, expand and upgrade existing operations. Our capital requirements have consisted primarily of, and we anticipate that our capital requirements will continue to consist primarily of, the following:

· maintenance capital expenditures, which are capital expenditures made to maintain the operating capacity of our assets and extend their useful lives, to replace partially or fully depreciated assets, or other capital expenditures that are incurred in maintaining our existing business and related operating income; and

· expansion capital expenditures, which are capital expenditures made to expand the operating capacity or operating income capacity of assets, including by acquisition of compression units or through modification of existing compression units to increase their capacity, or to replace certain partially or fully depreciated assets that were not currently generating operating income.

We classify capital expenditures as maintenance or expansion on an individual asset basis.Over the long term, we expect that our maintenance capital expenditure requirements will continue to increase as the overall size and age of our

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fleet increases. Our aggregate maintenance capital expenditures for the years ended December 31, 2015 and 2014 were $16.1 million and $15.8 million, respectively.  We currently plan to spend approximately $15 million in maintenance capital expenditures during 2016.

Given the recent downturn in the energy industry described above under the heading “—General Trends and Outlook,” we anticipate that we will significantly reduce our 2016 expansion capital expenditures in comparison to our 2014 and 2015 capital expenditures.  Without giving effect to any equipment we may acquire pursuant to any future acquisitions, we currently have budgetedbetween  $40 million and $50 million in expansion capital expenditures during 2016.  Our expansion capital expenditures for the years ended December 31, 2015 and 2014 were $268.9 million and $372.1 million, respectively.

Revolving Credit Facility

As of December 31, 2015, we were in compliance with all of our covenants under our revolving credit facility.  As of December 31, 2015, we had outstanding borrowings under our revolving credit facility of $729.2 million, $370.8 million of borrowing base availability and,subject to compliance with the applicable financial covenants, available borrowing capacityof  $101.0 million. The borrowing base consists of eligible accounts receivable, inventory and compression units. Financial covenants permit a maximum leverage ratio of 5.50 to 1.0 through the end of the fiscal quarter ending June 30, 2016 and 5.00 to 1.0 thereafter.  As of February 9, 2016, we had outstanding borrowings of $740.2 million.  We expect to remain in compliance with our covenants throughout 2016.  If our current cash flow projections prove to be inaccurate, we expect to be able to remain in compliance with such financial covenants by one or more of the following actions: issue equity in conjunction with the acquisition of another business; issue equity in a public or private offering; request a modification of our covenants from our bank group; reduce distributions from our current distribution rate or request an equity infusion pursuant to the terms of our revolving credit facility.

For a detailed description of our revolving credit facility including the covenants and restrictions contained therein, please refer to Note 8 to our consolidated financial statements.

Distribution Reinvestment Plan

During the year ended December 31, 2015, distributions of $56.9 million were reinvested under the DRIP resulting in the issuance of 3.1 million common units.  Such distributions are treated as non-cash transactions in the accompanying Consolidated Statements of Cash Flows included under Part IV, Item 15of this report. 

For a more detailed description of the DRIP, please refer to Note 9 to our consolidated financial statements.

Continuous Offering Program

On November 12, 2014, we entered into an Equity Distribution Agreement with the sales agents party thereto, which established our continuous offering program whereby we may issue common units having an aggregate offering amount of up to $150 million (the “COP”). We did not issue any common units or receive any proceeds under the COP in the year ended December 31, 2015.

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Total Contractual Cash Obligations

The following table summarizes our total contractual cash obligations as of December 31, 2015:

	Payments Due by Period
									More than
Contractual Obligations	Total		1 year		2 - 3 years		4 - 5 years		5 years
	(in thousands)
Long-term debt (1)	$	729,187	$	—	$	—	$	729,187	$	—
Interest on long-term debt obligations (2)		66,191		16,480		32,960		16,751		—
Equipment/capital purchases (3)		20,802		20,802		—		—		—
Operating lease obligations (4)		5,320		1,645		2,620		1,055		—
Total contractual cash obligations	$	821,500	$	38,927	$	35,580	$	746,993	$	—

(1) Represents future principal repayments under our revolving credit facility.

(2) Represents future interest payments under our revolving credit facility based on the interest rate as of December 31, 2015 of 2.26%.

(3) Represents commitments for new compression units that are being fabricated, and is a component of our overall projected expansion capital expenditures during 2016 of $40 million to $50 million.

(4) Represents commitments for future minimum lease payments on noncancelable leases.

Effects of Inflation. Our revenues and results of operations have not been materially impacted by inflation and changing prices in the past three fiscal years.

Off-Balance Sheet Arrangements

We have no off-balance sheet financing activities.Please refer to Note 14 of our consolidated financial statements included in this report for a description of our commitments and contingencies.  

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations is based upon our financial statements. These financial statements were prepared in conformity with GAAP. As such, we are required to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the periods presented. We base our estimates on historical experience, available information and various other assumptions we believe to be reasonable under the circumstances. On an ongoing basis, we evaluate our estimates; however, actual results may differ from these estimates under different assumptions or conditions. The accounting policies that we believe require management’s most difficult, subjective or complex judgments and are the most critical to its reporting of results of operations and financial position are as follows:

Revenue Recognition

We recognize revenue using the following criteria: (i) persuasive evidence of an arrangement, (ii) delivery has occurred or services have been rendered, (iii) the customer’s price is fixed or determinable and (iv) collectability is reasonably assured.

Revenue from compression services is recognized as earned under our fixed-fee contracts. Compression services generally are billed monthly in advance of the service period, except for certain customers which are billed at the beginning of the service month.  Revenues are recognized as deferred revenue on the balance sheet until earned.

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Business Combinations and Goodwill

Goodwill acquired in connection with business combinations represents the excess of consideration over the fair value of net assets acquired. Certain assumptions and estimates are employed in determining the fair value of assets acquired and liabilities assumed, as well as in determining the allocation of goodwill to the appropriate reporting unit. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of October 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.

Goodwill—Impairment Assessments

We evaluate goodwill for impairment annually on October 1 of the fiscal year and whenever events or changes indicate that it is more likely than not that the fair value of our single business reporting unit could be less than its carrying value (including goodwill). The timing of the annual test may result in charges to our statement of operations in our fourth fiscal quarter that could not have been reasonably foreseen in prior periods.

We estimate the fair value of our reporting unit based on a number of factors, including the potential value we would receive if we sold the reporting unit, enterprise value, discount rates and projected cash flows. Estimating projected cash flows requires us to make certain assumptions as it relates to future operating performance. When considering operating performance, various factors are considered such as current and changing economic conditions and the commodity price environment, among others. Due to the imprecise nature of these projections and assumptions, actual results can and often do, differ from our estimates. If the growth assumptions embodied in the current year impairment testing prove inaccurate, we could incur an impairment charge in the future.

On October 1, 2015, we performed our annual goodwill impairment test. We updated our impairment test as of December 31, 2015 as certain potential impairment indicators were identified during the fourth quarter, specifically (1) the decline in the market price of the Partnership’s common units, (2) the sustained decline in global commodity prices, and (3) the decline in performance of the Alerian MLP Index, which indicated the reporting unit had a fair value that was less than its carrying value as of December 31, 2015. As described in Note 2, “Summary of Significant Accounting Policies – Goodwill,” we prepared a quantitative assessment as of December 31, 2015 which indicated that the calculated fair value was less than the carrying value.  We subsequently performed “Step 2” impairment test for our reporting unit which requires us to treat the business as if it had been acquired in a business combination as of December 31, 2015 and assign the fair value of the reporting unit to all of its assets and liabilities. The carrying value of the goodwill is compared to the new implied fair value of goodwill and an impairment is recognized for any amount the carrying value exceeds the implied fair value.  Based on that step two impairment test, we recognized a non-cash impairment charge of $172.2 million.  We had approximately $35.9 of goodwill remaining on the balance sheet as of December 31, 2015.

As discussed above, estimates of fair value can be affected by a variety of external and internal factors. The recent crude oil price volatility has caused disruptions in global energy industries and markets. Potential events or circumstances that could reasonably be expected to negatively affect the key assumptions we used in estimating the fair value of our reporting unit include the consolidation or failure of crude oil and natural gas producers, which may result in a smaller market for services and may cause us to lose key customers, and cost-cutting efforts by crude oil and natural gas producers, which may cause us to lose current or potential customers or achieve less revenue per customer. We continue to monitor the remaining $35.9 million of goodwill and if the estimated fair value of our reporting unit declines due to any of these or other factors, we may be required to record future goodwill impairment charges.

Long-Lived Assets

Long-lived assets, which include property and equipment, and intangible assets, comprise a significant amount of our total assets. Long-lived assets to be held and used by us are reviewed to determine whether any events or changes in circumstances, including the removal of compression units from our active fleet, indicate the carrying amount of the asset may not be recoverable. For long-lived assets to be held and used, we base our evaluation on impairment indicators such as the nature of the assets, the future economic benefit of the assets, any historical or future profitability measurements and other external market conditions or factors that may be present. If such impairment indicators are

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present or other factors exist that indicate the carrying amount of the asset may not be recoverable, we determine whether an impairment has occurred through the use of an undiscounted cash flows analysis. If an impairment has occurred, we recognize a loss for the difference between the carrying amount and the estimated fair value of the asset. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows, the expected net sale proceeds compared to other similarly configured fleet units we recently sold, a review of other units recently offered for sale by third parties, or the estimated component value of similar equipment we plan to continue to use.  We recorded $27.3 million, $2.3 million and $0.2 million in impairment of compression equipment for the years ended December 31, 2015, 2014 and 2013, respectively.

Potential events or circumstances that could reasonably be expected to negatively affect the key assumptions we used in estimating whether or not the carrying value of our long-lived assets are recoverable include the consolidation or failure of crude oil and natural gas producers, which may result in a smaller market for services and may cause us to lose key customers, and cost-cutting efforts by crude oil and natural gas producers, which may cause us to lose current or potential customers or achieve less revenue per customer. If our projections of cash flows associated with our units decline, we may have to record an impairment of compression equipment in future periods.

Allowances and Reserves

We maintain an allowance for bad debts based on specific customer collection issues and historical experience. The determination of the allowance for doubtful accounts requires us to make estimates and judgments regarding our customers’ ability to pay amounts due.  On an ongoing basis, we conduct an evaluation of the financial strength of our customers based on payment history, the overall business climate in which our customers operate and specific identification of customer bad debt and make adjustments to the allowance as necessary. The allowance for doubtful accounts was $2.1 million, $0.4 million and $0.2 million as of December 31, 2015, 2014 and 2013, respectively.

Recent Accounting Pronouncements

We qualify as an emerging growth company under Section 109 of the Jumpstart Our Business Startups, (“JOBS”) Act. An emerging growth company can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an emerging growth company can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. However, we have chosen to “opt out” of such extended transition period, and as a result, are compliant with new or revised accounting standards on the relevant dates on which adoption of such standards is required for non-emerging growth companies. Section 108 of the JOBS Act provides that our decision to opt out of the extended transition period for complying with new or revised accounting standards is irrevocable.

For more discussion on specific recent accounting pronouncements affecting us, please see Note 13 to our consolidated financial statements.

ITEM 7A.Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk

Market risk is the risk of loss arising from adverse changes in market rates and prices. We do not take title to any natural gas or crude oil in connection with our services and, accordingly, have no direct revenue exposure to fluctuating commodity prices. However, the demand for our compression services depends upon the continued demand for, and production of, natural gas and crude oil. Lower natural gas prices or crude oil prices over the long term could result in a decline in the production of natural gas or crude oil, which could result in reduced demand for our compression services. Please read Part I, Item 1A (“Risk Factors—Risks Related to Our Business”). We do not intend to hedge our indirect exposure to fluctuating commodity prices.A 1% decrease in average revenue generating horsepower of our active fleet during the year ended December 31, 2015 would have resulted in a decrease of approximately $2.7 million and $1.9 million in our revenue and gross operating margin, respectively. Gross operating margin is a non-GAAP financial measure. For a reconciliation of gross operating margin to net income (loss), its most directly comparable financial measure, calculated and presented in accordance with GAAP, please read Part II, Item 6 (“—Non-GAAP Financial

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Measures”).Please also read Part I, Item 1A (“Risk Factors—Risks Related to Our Business—A long-term reduction in the demand for, or production of, natural gas or crude oil in the locations where we operate could adversely affect the demand for our services or the prices we charge for our services, which could result in a decrease in our revenues and cash available for distribution to unitholders”).

Interest Rate Risk

We are exposed to market risk due to variable interest rates under our financing arrangements.

As of December 31, 2015 we had approximately $729.2 million of variable-rate outstanding indebtedness at a weighted-average interest rate of 2.26%. A 1% increase in the effective interest rate on our variable-rate outstanding debt as of December 31, 2015 would result in an annual increase in our interest expense of approximately$7.3 million.

For further information regarding our exposure to interest rate fluctuations on our debt obligations, see Note 8 to our consolidated financial statements.  Although we do not currently hedge our variable rate debt, we may, in the future, hedge all or a portion of such debt.

Credit Risk

Our credit exposure generally relates to receivables for services provided. If any significant customer of ours should have credit or financial problems resulting in a delay or failure to repay the service fees owed to us, this could have a material adverse effect on our business, financial condition, results of operations or cash flows.

ITEM 8.Financial Statements and Supplementary Data

The financial statements and supplementary information specified by this Item are presented in Part IV, Item 15.

ITEM 9.Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

None.

ITEM 9A.Controls and Procedures

Disclosure Controls and Procedures

As required by Rule 13a-15(b) of the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our 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 period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures, and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC.  Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective as of December 31, 2015 at the reasonable assurance level.

Management’s Annual Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting for us. Our internal control system was designed to provide reasonable assurance regarding the preparation and fair presentation of our published financial statements.

There are inherent limitations to the effectiveness of any control system, however well designed, including the possibility of human error and the possible circumvention or overriding of controls. Further, the design of a control

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system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Management must make judgments with respect to the relative cost and expected benefits of any specific control measure. The design of a control system also is based in part upon assumptions and judgments made by management about the likelihood of future events, and there can be no assurance that a control will be effective under all potential future conditions. As a result, even an effective system of internal control over financial reporting can provide no more than reasonable assurance with respect to the fair presentation of financial statements and the processes under which they were prepared.

Our management assessed the effectiveness of our internal control over financial reporting as of December 31, 2015. In making this assessment, management used the criteria set forth by the 2013 Committee of Sponsoring Organizations of the Treadway Commission in Internal Control — Integrated Framework. Based on this assessment, our management believes that, as of December 31, 2015, our internal control over financial reporting was effective. This report does not include an attestation report of the company’s registered public accounting firm due to a transition period established by rules of the SEC for emerging growth companies.

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.

ITEM 9B.Other Information

None.

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PART III

ITEM 10.Directors, Executive Officers and Corporate Governance

Board of Directors

Our general partner, USA Compression GP, LLC, manages our operations and activities. Our general partner is not elected by our unitholders and is not subject to re-election on a regular basis in the future. Our general partner has a board of directors that manages our business.

The board of directors of our general partner is comprised of eight members, all of whom have been designated by USA Compression Holdings and three of whom are independent as defined under the independence standards established by the NYSE. The NYSE does not require a listed limited partnership like us to have a majority of independent directors on the board of directors of our general partner or to establish a compensation committee or a nominating committee.

The non-management directors regularly meet in executive session without management directors. Mr. Long is currently our only management director. Forrest E. Wylie presides at such meetings. Interested parties can communicate directly with non-management directors by mail in care of the General Counsel and Secretary at USA Compression Partners, LP, 100 Congress Avenue, Suite 450, Austin, Texas 78701. Such communications should specify the intended recipient or recipients. Commercial solicitations or communications will not be forwarded.

Independent Directors. The board of directors of our general partner has determined that Robert F. End, John D. Chandler and Forrest E. Wylie are independent directors under the standards established by the NYSE and the Exchange Act. The board of directors of our general partner considered all relevant facts and circumstances and applied the independent guidelines of the NYSE and the Exchange Act in determining that none of these directors has any material relationship with us, our management, our general partner or its affiliates or our subsidiaries.

In addition, in October 2014, Mr. Chandler was appointed to serve on the board of directors and the audit committee of one of our customers.  For the year ended December 31, 2015, subsidiaries of this customer made compression service payments to us of approximately $8.8 million.  The board of directors of our general partner made a determination that the relationship with this customer did not preclude the independence of Mr. Chandler.

Audit Committee. The board of directors of our general partner has appointed an audit committee comprised solely of directors who meet the independence and experience standards established by the NYSE and the Exchange Act. The audit committee consists of Robert F. End, John D. Chandler and Forrest E. Wylie. Mr. Chandler serves as chairman of the audit committee.  The board of directors of our general partner has determined that Mr. Chandler is an “audit committee financial expert” as defined in Item 407(d)(5)(ii) of SEC Regulation S-K, and that each of Messrs. End, Chandler and Wylie is “independent” within the meaning of the applicable NYSE and Exchange Act rules regulating audit committee independence. The audit committee assists the board of directors of our general partner in its oversight of the integrity of our financial statements and our compliance with legal and regulatory requirements and corporate policies and controls. The audit committee has the sole authority to retain and terminate our independent registered public accounting firm, approve all auditing services and related fees and the terms thereof, and pre-approve any non-audit services to be rendered by our independent registered public accounting firm. The audit committee is also responsible for confirming the independence and objectivity of our independent registered public accounting firm. Our independent registered public accounting firm will be given unrestricted access to the audit committee. A copy of the charter of the audit committee is available under the Investor Relations tab on our website at usacompression.com. We also will provide a copy of the charter of the audit committee to any of our unitholders without charge upon written request to Investor Relations, 100 Congress Avenue, Suite 450, Austin, TX 78701.

Compensation Committee. The NYSE does not require a listed limited partnership like us to have a compensation committee.  However, the board of directors of our general partner has established a compensation committee to, among other things, oversee the compensation plans described below in Part III, Item 11 (“Executive Compensation”). The

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compensation committee consists of Robert F. End, William H. Shea, Jr. and Olivia C. Wassenaar.  The compensation committee establishes and reviews general policies related to our compensation and benefits. The compensation committee has the responsibility to determine and make recommendations to the board of directors of our general partner with respect to, the compensation and benefits of the board of directors and executive officers of our general partner. A copy of the charter of the compensation committee is available under the Investor Relations tab on our website at usacompression.com. We also will provide a copy of the charter of the compensation committee to any of our unitholders without charge upon written request to Investor Relations, 100 Congress Avenue, Suite 450, Austin, TX 78701.

Conflicts Committee.  As set forth in the limited liability company agreement of our general partner, our general partner may, from time to time, establish a conflicts committee to which the board of directors of our general partner will appoint independent directors and which may be asked to review specific matters that the board of directors of our general partner believes may involve conflicts of interest between us, our limited partners and USA Compression Holdings. The conflicts committee will determine the resolution of the conflict of interest in any manner referred to it in good faith. The members of the conflicts committee may not be officers or employees of our general partner or directors, officers or employees of its affiliates, including USA Compression Holdings, and must meet the independence and experience standards established by the NYSE and the Exchange Act to serve on an audit committee of a board of directors of our general partner, and certain other requirements. Any matters approved by the conflicts committee in good faith will be conclusively deemed to be fair and reasonable to us, approved by all of our partners and not a breach by our general partner of any duties it may owe us or our unitholders.

Section 16(a) Beneficial Ownership Reporting Compliance

Section 16(a) of the Exchange Act requires the board of directors and executive officers of our general partner, and persons who own more than 10 percent of a registered class of our equity securities, to file with the SEC and any exchange or other system on which such securities are traded or quoted initial reports of ownership and reports of changes in ownership of our common units and other equity securities. Officers, directors and greater than 10 percent unitholders are required by the SEC’s regulations to furnish to us and any exchange or other system on which such securities are traded or quoted with copies of all Section 16(a) forms they filed with the SEC. To our knowledge, based solely on a review of the copies of such reports furnished to us, we believe that all reporting obligations of the officers and directors of our general partner and greater than 10 percent unitholders under Section 16(a) were satisfied during the year ended December 31, 2015.

Corporate Governance Guidelines and Code of Ethics

The board of directors of our general partner has adopted Corporate Governance Guidelines that outline important policies and practices regarding our governance and provide a framework for the function of the board of directors of our general partner and its committees. The board of directors of our general partner has also adopted a Code of Business Conduct and Ethics (the “Code”) that applies to our general partner and its subsidiaries and affiliates, including us, and to all of its and their directors, employees and officers, including its principal executive officer, principal financial officer and principal accounting officer. Copies of the Corporate Governance Guidelines and the Code are available under the Investor Relations tab on our website at usacompression.com. We also will provide copies of the Corporate Governance Guidelines and the Code to any of our unitholders without charge upon written request to Investor Relations, 100 Congress Avenue, Suite 450, Austin, TX 78701.

Reimbursement of Expenses of Our General Partner

Our general partner will not receive any management fee or other compensation for its management of us. Our general partner and its affiliates will be reimbursed for all expenses incurred on our behalf, including the compensation of employees of our general partner or its affiliates that perform services on our behalf. These expenses include all expenses necessary or appropriate to the conduct of our business and that are allocable to us. Our partnership agreement provides that our general partner will determine in good faith the expenses that are allocable to us. There is no cap on the amount that may be paid or reimbursed to our general partner or its affiliates for compensation or expenses incurred on our behalf.

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Directors and Executive Officers

The following table shows information as of February 9, 2016 regarding the current directors and executive officers of USA Compression GP, LLC.

Name	Age	Position with USA Compression GP, LLC
Eric D. Long	57	President and Chief Executive Officer and Director
Matthew C. Liuzzi	41	Vice President, Chief Financial Officer and Treasurer
J. Gregory Holloway	58	Vice President, General Counsel and Secretary
David A. Smith	53	Vice President and President, Northeast Region
William G. Manias	53	Vice President and Chief Operating Officer
John D. Chandler	46	Director
Jim H. Derryberry	71	Director
Robert F. End	60	Director
William H. Shea, Jr.	61	Director
Andrew W. Ward	49	Director
Olivia C. Wassenaar	36	Director
Forrest E. Wylie	52	Director

The directors of our general partner hold office until the earlier of their death, resignation, removal or disqualification or until their successors have been elected and qualified. Officers serve at the discretion of the board of directors of our general partner. There are no family relationships among any of the directors or executive officers of our general partner.

Eric D. Long has served as our President and Chief Executive Officer since September 2002 and has served as a director of USA Compression GP, LLC since June 2011. Mr. Long co-founded USA Compression in 1998 and has over 30 years of experience in the oil and gas industry. From 1980 to 1987, Mr. Long served in a variety of technical and managerial roles for several major pipeline and oil and natural gas producing companies, including Bass Enterprises Production Co. and Texas Oil & Gas. Mr. Long then served in a variety of senior officer level operating positions with affiliates of Hanover Energy, Inc., a company primarily engaged in the business of gathering, compressing and transporting natural gas. In 1993, Mr. Long co-founded Global Compression Services, Inc., a compression services company. Mr. Long was formerly on the board of directors of the Wiser Oil Company, an NYSE listed company from May 2001 until it was sold to Forest Oil Corporation in May 2004. Mr. Long received his bachelor’s degree, with honors, in Petroleum Engineering from Texas A&M University. He is a registered Professional Engineer in the state of Texas.

As a result of his professional background, Mr. Long brings to us executive level strategic, operational and financial skills. These skills, combined with his over 30 years of experience in the oil and natural gas industry, including in particular his experience in the compression services sector, make Mr. Long a valuable member of the board of directors of our general partner.

Matthew C. Liuzzi  has served as our Vice President, Chief Financial Officer and Treasurer since January 2015. Prior to such time, Mr. Liuzzi served as our Senior Vice President – Strategic Development since joining us in April 2013. Mr. Liuzzi joined us after nine years in investment banking, since 2008 at Barclays, where he was most recently a Director in the Global Natural Resources Group in Houston.  At Barclays, Mr. Liuzzi worked primarily with midstream clients on a variety of investment banking assignments, including initial public offerings, public and private debt and equity offerings, as well as strategic advisory assignments. He holds a B.A. and an M.B.A., both from the University of Virginia.

J. Gregory Holloway has served as our Vice President, General Counsel and Secretary since joining us in June 2011. From September 2005 through June 2011, Mr. Holloway was a partner at Thompson & Knight LLP in its Austin office. His areas of practice at the firm included corporate, securities and merger and acquisition law. Mr. Holloway received his B.A. from Rice University and his J.D., with honors, from the University of Texas School of Law.

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David A. Smith has served as our President, Northeast Region since joining us in November 1998 and was appointed corporate Vice President in June 2011. Mr. Smith has approximately 20 years of experience in the natural gas compression industry, primarily in operations and sales. From 1985 to 1989, Mr. Smith was a sales manager for McKenzie Corporation, a compression fabrication company. From 1989 to 1996, Mr. Smith held positions of General Manager and Regional Manager of Northeast Division with Compressor Systems Inc., a fabricator and supplier of compression services. Mr. Smith was the Regional Manager in the northeast for Global Compression Services, Inc., a compression services company, and served in that capacity from 1996 to 1998. Mr. Smith received an associates degree in Automotive and Diesel Technology from Rosedale Technical Institute.

William G. Manias has served as our Vice President and Chief Operating Officer since July 2013.  He served as a director of our general partner from February 2013 to July 2013. From October 2009 until January 2013, Mr. Manias served as Senior Vice President and Chief Financial Officer of Crestwood Midstream Partners LP and its affiliates, where his general responsibilities included managing the partnership’s financial and treasury activities. Before joining Crestwood in January 2009, Mr. Manias was the Chief Financial Officer of TEPPCO Partners, L.P. starting in January 2006. From September 2004 until January 2006, he served as Vice President of Business Development and Strategic Planning at Enterprise Product Partners L.P. He previously served as Vice President and Chief Financial Officer of GulfTerra Energy Partners, L.P. from February 2004 to September 2004 at which time GulfTerra Energy Partners, L.P. was merged with Enterprise Product Partners L.P. Prior to GulfTerra Energy Partners, L.P., Mr. Manias held several executive management positions with El Paso Corporation. Prior to El Paso, he worked as an energy investment banker for J.P. Morgan Securities Inc. and its predecessor companies from May 1992 to August 2001. Mr. Manias earned a B.S.E. in civil engineering from Princeton University in 1984, a M.S. in petroleum engineering from Louisiana State University in 1986 and an M.B.A. from Rice University in 1992.

John D. Chandler has served as a director of USA Compression GP, LLC since October 2013.  Mr. Chandler has also served on the board of directors and the audit committee of CONE Midstream GP, LLC since October 2014. From 2009 to March 2014, Mr. Chandler served as Senior Vice President and Chief Financial Officer of Magellan GP, LLC, the general partner of Magellan Midstream Partners, LP. From 2003 until 2009, he served in the same capacities for the general partner of Magellan Midstream Holdings, L.P. From 1999 to 2002, Mr. Chandler was Director of Financial Planning and Analysis and Director of Strategic Development for a subsidiary of The Williams Companies, Inc. From 1992 to 1999, Mr. Chandler held various accounting and finance positions with MAPCO Inc. Mr. Chandler received his B.S. and B.A. in accounting and finance from the University of Tulsa.

Mr. Chandler’s experience in the energy industry, particularly through his position as the Chief Financial Officer of the general partner of Magellan Midstream Partners, LP, will provide additional industry perspective to the board of directors of our general partner. He will bring us helpful perspective regarding company growth, having been an officer at Magellan since its spin-off from the Williams Companies in 2003. In addition, his understanding of the midstream master limited partnership sector in particular and of the unique issues related to operating publicly traded limited partnerships should help him make valuable contributions to us.

Jim H. Derryberry has served as a director of USA Compression GP, LLC since January 2013. From February 2005 to October 2006, Mr. Derryberry served on the board of directors of Magellan GP, LLC, the general partner of Magellan Midstream Partners, L.P. Mr. Derryberry served as chief operating officer and chief financial officer of Riverstone Holdings, LLC until 2006 and currently serves as a special advisor. Prior to joining Riverstone, Mr. Derryberry was a managing director of J.P. Morgan, where he served as head of the Natural Resources and Power Group. Before joining J.P. Morgan, Mr. Derryberry was in the Goldman Sachs Global Energy and Power Group where he was responsible for mergers and acquisitions, capital markets financing and the management of relationships with major energy companies. He has also served as an advisor to the Russian government for energy privatization. Mr. Derryberry has served as a member of the Board of Overseers for the Hoover Institution at Stanford University and is a member of the Engineering Advisory Board at the University of Texas at Austin. He received his B.S. and M.S. degrees in engineering from the University of Texas at Austin and earned an M.B.A. from Stanford University.

Mr. Derryberry brings significant knowledge and expertise to the board of directors of our general partner from his service on other boards and his years of experience in our industry including his useful insight into investments and

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proven leadership skills as a managing director of Riverstone Holdings, LLC. As a result of his experience and skills, we believe Mr. Derryberry is a valuable member of the board of directors of our general partner.

Robert F. End has served as a director of USA Compression GP, LLC since November 2012. Mr. End served as a director of Hertz Global Holdings, Inc. from December 2005 until August 2011. Mr. End was a Managing Director of Transportation Resource Partners (“TRP”), a private equity firm from 2009 through 2011. Prior to joining TRP in 2009, Mr. End had been a Managing Director of Merrill Lynch Global Private Equity Division (“MLGPE”), the private equity arm of Merrill Lynch & Co., Inc., where he served as Co-Head of the North American Region, and a Managing Director of Merrill Lynch Global Private Equity, Inc., the Manager of ML Global Private Equity Fund, L.P., a proprietary private equity fund which he joined in 2004. Previously, Mr. End was a founding Partner and Director of Stonington Partners Inc., a private equity firm established in 1994. Prior to leaving Merrill Lynch in 1994, Mr. End was a Managing Director of Merrill Lynch Capital Partners, Merrill Lynch’s private equity group. Mr. End joined Merrill Lynch in 1986 and worked in the Investment Banking Division before joining the private equity group in 1989. Mr. End received his A.B. from Dartmouth College and his M.B.A. from the Tuck School of Business Administration at Dartmouth College.

Mr. End brings significant knowledge and expertise to the board of directors of our general partner from his service on other boards and his years of experience with private equity groups, including his useful insight into investments and business development and proven leadership skills as Managing Director of MLGPE. As a result of this experience and resulting skills set, we believe Mr. End is a valuable member of the board of directors of our general partner.

William H. Shea, Jr. has served as a director of USA Compression GP, LLC since June 2011. Mr. Shea is also the chairman of the board of directors, President and Chief Executive Officer of Niska Gas Storage Partners LLC and has served in such role since May 2014.  Previously, Mr. Shea served as the President and Chief Operating Officer of Buckeye GP LLC and its predecessor entities (“Buckeye”), from July 1998 to September 2000, as President and Chief Executive Officer of Buckeye from September 2000 to July 2007, and Chairman from May 2004 to July 2007. From August 2006 to July 2007, Mr. Shea served as Chairman of MainLine Management LLC, the general partner of Buckeye GP Holdings, L.P., and as President and Chief Executive Officer of MainLine Management LLC from May 2004 to July 2007. Mr. Shea served as a director of Penn Virginia Corp. from July 2007 to March 2010, and as President and Chief Executive Officer of the general partner of Penn Virginia GP Holdings, L.P. from March 2010 to October 2013 and as Chief Executive Officer of the general partner of PVR Partners, L.P. (“PVR”), from March 2010 to October 2013. Mr. Shea has also served as a director of Kayne Anderson Energy Total Return Fund, Inc., and Kayne Anderson MLP Investment Company since March 2008 and Niska Gas Storage Partners LLC since May 2010. Mr. Shea has an agreement with Riverstone, pursuant to which he has agreed to serve on the boards of certain Riverstone portfolio companies. Mr. Shea received his B.A. from Boston College and his M.B.A. from the University of Virginia.

Mr. Shea’s experiences as an executive with both PVR and Buckeye, energy companies that operate across a broad spectrum of sectors, including coal, natural gas gathering and processing and refined petroleum products transportation, have given him substantial knowledge about our industry. In addition, Mr. Shea has substantial experience overseeing the strategy and operations of publicly traded partnerships. As a result of this experience and resulting skill set, we believe Mr. Shea is a valuable member of the board of directors of our general partner.

Andrew W. Ward has served as a director of USA Compression GP, LLC since June 2011. Mr. Ward has served as a Principal of Riverstone from 2002 until 2004, as a Managing Director since January 2005 and as a Partner and Managing Director since July 2009, where he focuses on the firm’s investment in the midstream sector of the energy industry. Mr. Ward served on the boards of directors of Buckeye and MainLine Management LLC from May 2004 to June 2006. Mr. Ward has also served on the board of directors of Gibson Energy Inc. from 2008 to 2013 and of the general partner of PVR Partners, L.P. from 2012 to 2014.  Mr. Ward has served on the board of directors of Niska Gas Storage Partners LLC since May 2006 as well as various private companies sponsored by Riverstone. Mr. Ward received his A.B. from Dartmouth College and received his M.B.A. from the UCLA Anderson School of Management.

Mr. Ward’s experience in evaluating the financial performance and operations of companies in our industry make him a valuable member of the board of directors of our general partner. In addition, Mr. Ward’s work with Gibson Energy, Inc., Buckeye, PVR Partners, L.P. and Niska Gas Storage Partners LLC has given him both an understanding of

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the midstream sector of the energy business and of the unique issues related to operating publicly traded limited partnerships.

Olivia C. Wassenaar has served as a director of USA Compression GP, LLC since June 2011. Ms. Wassenaar was an Associate with Goldman, Sachs & Co. in the Global Natural Resources investment banking group from July 2007 to August 2008, where she focused on mergers, equity and debt financings and leveraged buyouts for energy, power and renewable energy companies. Ms. Wassenaar joined Riverstone in September 2008 as Vice President, and has served as a Principal from May 2010 to February 2014 and as a Managing Director since February 2014. In this capacity, she invests in and monitors investments in the midstream, exploration & production, and solar sectors of the energy industry. Ms. Wassenaar has also served on the board of directors of Northern Blizzard Resources Inc. since June 2011 and on the board of directors of Niska Gas Storage Partners LLC as well as various private portfolio companies sponsored by Riverstone. Ms. Wassenaar received her A.B., magna cum laude, from Harvard College and earned an M.B.A. from the Wharton School of the University of Pennsylvania.

Ms. Wassenaar’s experience in evaluating financial and strategic options and the operations of companies in our industry and as an investment banker make her a valuable member of the board of directors of our general partner.

Forrest E. Wylie has served as a director of USA Compression GP, LLC since March 2013. Mr. Wylie served as the Non-Executive Chairman of the board of directors of Buckeye GP LLC, the general partner of Buckeye Partners, L.P., from February 2012 to August 2014. He served as Chairman of the Board, CEO and a director of Buckeye GP LLC from June 2007 to February 2012. Mr. Wylie also served as a director of the general partner of Buckeye GP Holdings L.P., the former parent company of Buckeye (“BGH”) from June 2007 until the merger of BGH with Buckeye Partners, L.P. on November 2010. Prior to his appointment, he served as Vice Chairman of Pacific Energy Management LLC, an entity affiliated with Pacific Energy Partners, L.P., a refined product and crude oil pipeline and terminal partnership, from March 2005 until Pacific Energy Partners, L.P. merged with Plains All American, L.P. in November 2006. Mr. Wylie was President and CFO of NuCoastal Corporation, a midstream energy company, from May 2002 until February 2005. From November 2006 to June 2007, Mr. Wylie was a private investor. Mr. Wylie served on the board of directors and the audit committee of Coastal Energy Company, a publicly traded entity, until April 2011. Mr. Wylie also served on board of directors and compensation and nominating and corporate governance committees of Eagle Bulk Shipping Inc. until May 2010.

Mr. Wylie’s experience in the energy industry, through his prior position as the CEO of a publicly traded partnership and the past employment described above, has given him both an understanding of the midstream sector of the energy business and of the unique issues related to operating publicly traded limited partnerships that make him a valuable member of the board of directors of our general partner.

ITEM 11.Executive Compensation

As is commonly the case for many publicly traded limited partnerships, we have no employees. Under the terms of our partnership agreement, we are ultimately managed by our general partner. All of our employees, including our executive officers, are employees of USAC Management, a wholly owned subsidiary of our general partner.

Executive Compensation

We are an “emerging growth company” as defined under the Jumpstart Our Business Startups (JOBS) Act. As such, we are permitted to meet the disclosure requirements of Item 402 of Regulation S-K by providing the reduced disclosure required of a “smaller reporting company.”

Executive Summary

This Executive Compensation disclosure provides an overview of the executive compensation program for our named executive officers identified below. Our general partner intends to provide our named executive officers with

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compensation that is significantly performance based. For the year ended December 31, 2015, our named executive officers (“NEOs”) were:

· Eric D. Long, President and Chief Executive Officer;

· William G. Manias, Vice President and Chief Operating Officer; and

· Matthew C. Liuzzi, Vice President, Chief Financial Officer and Treasurer.

Summary Compensation Table

The following table sets forth certain information with respect to the compensation paid to our NEOs for the years ended December 31, 2014 and 2015.  

					All Other
				Unit Awards	Compensation
Name and Principal Position	Year	Salary ($)	Bonus ($) (1)	($) (2)	($)		Total ($)
Eric D. Long	2015	588,962	885,000	1,500,000	279,917	(3)	3,253,879
President and Chief Executive Officer	2014	488,462	650,500	1,000,000	270,562		2,409,524
William G. Manias (4)	2015	399,596	450,000	725,000	95,866	(5)	1,670,462
Vice President and Chief Operating Officer
Matthew C. Liuzzi (6)	2015	312,247	325,500	586,500	85,351	(7)	1,309,598
Vice President, Chief Financial Officer and Treasurer

(1) Represents the awards earned under annual cash incentive bonus program for the years ended December 31, 2014 and 2015, as applicable. For a discussion of the determination of the 2015 bonus amounts, see “—Annual Performance Based Compensation for 2015” below.

(2) On February 19, 2015, each of our NEOs received an award of phantom units under our LTIP. Each phantom unit is the economic equivalent of one common unit.  The phantom unit values reflect the grant date fair value of the awards calculated in accordance with FASB ASC Topic 718.  For a detailed discussion of the assumptions utilized in coming to these values, please see Note 10 to our consolidated financial statements.

(3) Includes $229,816 of distribution equivalent rights, $18,000 of automobile allowance, $10,449 of club membership dues, $7,950 of employer contributions under the 401(k) plan, $3,302 of parking, $8,400 of personal administrative assistant support and $2,000 of personal tax support. Please see a description of the distribution equivalent rights under “—Discretionary Long-Term Equity Incentive Awards” below.

(4) Mr. Manias was not a NEO for the 2014 fiscal year, therefore we have not reported his compensation for the 2014 fiscal year.

(5) Includes $86,398 of distribution equivalent rights, $7,373 of employer contributions under the 401(k) plan and $2,095 of parking.

(6) Mr. Liuzzi was not an NEO for the 2014 fiscal year, therefore we have not reported his compensation for the 2014 fiscal year.

(7) Includes $75,350 of distribution equivalent rights and $7,950 of employer contributions under the 401(k) plan and $2,051 of parking.

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Narrative Disclosure to Summary Compensation Table

Elements of the Compensation Program

Compensation for our NEOs consists primarily of the elements, and their corresponding objectives, identified in the following table.

Compensation Element	Primary Objective
Base salary	To recognize performance of job responsibilities and to attract and retain individuals with superior talent.
Annual incentive compensation	To promote near-term performance objectives and reward individual contributions to the achievement of those objectives.
Discretionary long-term equity incentive awards	To emphasize long-term performance objectives, encourage the maximization of unitholder value and retain key executives by providing an opportunity to participate in the ownership of our partnership.
Severance benefits	To encourage the continued attention and dedication of key individuals and to focus the attention of such key individuals when considering strategic alternatives.
Retirement savings (401(k)) plan	To provide an opportunity for tax-efficient savings.
Other elements of compensation and perquisites	To attract and retain talented executives in a cost-efficient manner by providing benefits with high perceived values at relatively low cost.

Base Compensation For 2015 and 2016

Base salaries for our NEOs have generally been set at a level deemed necessary to attract and retain individuals with superior talent. Base salary increases are determined based upon the job responsibilities, demonstrated proficiency and performance of the executive officers and market conditions, each as assessed by the board of directors of our general partner or the chief executive officer (for non-chief executive officer compensation) in conjunction with the compensation committee. No formulaic base salary increases are provided to the NEOs. For 2015 and 2016, in connection with determining base salaries for each of our NEOs, the board of directors of our general partner,compensation committee and chief executive officer worked with a compensation consultant to determine comparable salaries for our peer group, which we identified based on a review of companies in our industry with similar characteristics.

Based upon the information provided by the compensation consultant with respect to a review of base salary information of companies within our peer group, the board of directors of our general partner determined during2014 to move towards targeting base salaries more directly in-line with our peer group. For 2015 and 2016, the board of directors of our general partner determined that base salary should be set at approximately the 50th percentile of the peer group.  The 2015 and current 2016 base salaries for our NEOs, including for our Chief Executive Officer, are set forth in the following table:

	2015 Base Salary	Current 2016 Base Salary
Name and Principal Position	($)	($)
Eric D. Long President and Chief Executive Officer	590,000	607,700
William G. Manias, Vice President and Chief Operating Officer	400,000	412,000
Matthew C. Liuzzi, Vice President, Chief Financial Officer and Treasurer	310,000	365,000

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Annual Incentive Compensation For 2015

In February 2014, the board of directors of our general partner approved the adoption of an Annual Cash Incentive Plan (the “Cash Plan”). Each of our NEOs is entitled to participate in the Cash Plan and their potential bonus is governed both by the Cash Plan and their employment agreement.  The compensation committee acts as the administrator of the Cash Plan under the supervision of the full board of directors of our general partner, and has the discretion to amend, modify or terminate the Cash Plan at any time upon approval by the board of directors of our general partner.  Although the Cash Plan uses both company and individual performance goals to determine bonus amounts, the Cash Plan is ultimately a discretionary annual bonus plan and awards are therefore reported in the “Bonus” column within the Summary Compensation Table above.

The board of directors of our general partner sets a target bonus amount (the “Target Bonus”) for each NEO prior to or during the first quarter of the calendar year.  For the year ended December 31, 2015, the Target Bonus for each NEO was $590,000 for Mr. Long, $300,000 for Mr. Manias and $217,000 for Mr. Liuzzi.  The Target Bonus is generally subject to the satisfaction of both a partnership performance goal and an individual performance goal.  For the year ended December 31, 2015 fifty percent (50%) of the Target Bonus is subject to our achievement of our budgeted distributable cash flow level (“DCF”) for the year, as determined by our board of directors of our general partner.  Payouts with respect to the portion of the bonus subject to DCF (the “DCF Bonus”) generally do not occur unless we have satisfied the threshold set for DCF.  For 2015, the board of directors of our general partner set the budget for DCF at $105 million. The threshold, target and maximum requirements for the DCF target for the year ended December 31, 2015, as well as the portion of the DCF Bonus that could become payable if performance was satisfied for the year, are set forth below:

	DCF as a	Percentage of
	Percentage of	DCF
Levels of	Budgeted DCF	Bonus that would
DCF Bonus	for 2015	be Paid
Threshold	80%	50%
Target	100%	100%
Maximum	110%	200%

If DCF performance falls in between threshold and target, or between target and maximum, the amounts payable are adjusted ratably using straight line interpolation.  If DCF is satisfied above maximum levels, the potential payment of the DCF Bonus is capped at the maximum level of 200%.

For the year ended December 31, 2015, the remaining fifty percent (50%) of the Target Bonus is subject to individual objectives specific to each eligible individual’s role at USAC Management (the “Individual Bonus”).  The individual objectives are agreed upon in advance between the NEO and his immediate supervisor (or, with respect to the chief executive officer, between the board of directors of our general partner and the chief executive officer) and such objectives address the key priorities for that NEO’s position.  They may include key operating objectives as well as personal development criteria.  The Individual Bonus is subject to a maximum payout of 100% of the targeted Individual Bonus amount, although the board of directors of our general partner has discretion to pay out smaller amounts ranging from 0% to 100%, at their sole discretion, after analyzing the individual’s personal performance for the year.  In connection with the Individual Bonus for the year ended December 31, 2015, each of the NEOs met with their immediate supervisor (or, with respect to the chief executive officer, the board of directors of our general partner) to set individual objectives that reflected the responsibilities and priorities of their position.

For the year ended December 31, 2015, in the aggregate, the maximum amount payable with respect to a Target Bonus under the Plan is 150%, as the DCF Bonus is capped at 200% of target and the Individual Bonus is capped at 100% of target.  Target Bonuses, if any, are paid within one week following delivery by our independent auditor of the audit of our financial statements for the year in which the Target Bonus relates, but in no case later than March 15 of the year following the year in which the Target Bonus relates. For the year ended December 31, 2015, DCF exceeded the target threshold in excess of 10%, which resulted in the DCF portion of the Cash Plan (comprising one-half of the overall

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Bonus) being paid to each NEO at the maximum rate of 200% for such portion of the Bonus.  With respect to the Individual Bonus portion of the overall Bonus, each NEO was determined by his immediate supervisor (which in the case of the chief executive officer is the board of directors of our general partner) to have satisfied his individual objectives and therefore was entitled to receive 100% of the Individual Bonus.  The awards made pursuant to the Cash Plan with respect to the 2015 year were:

Eric D. Long	$	885,000
William G. Manias	$	450,000
Matthew C. Liuzzi	$	325,500

Benefit Plans and Perquisites

We provide our executive officers, including our NEOs, with certain personal benefits and perquisites, which we do not consider to be a significant component of executive compensation but which we recognize are an important factor in attracting and retaining talented executives. Executive officers are eligible under the same plans as all other employees with respect to our medical, dental, vision, disability and life insurance plans and a defined contribution plan that is tax-qualified under Section 401(k) of the Internal Revenue Code and that we refer to as the 401(k) Plan. We also provide certain executive officers with an annual automobile allowance. We provide these supplemental benefits to our executive officers due to the relatively low cost of such benefits and the value they provide in assisting us in attracting and retaining talented executives. The value of personal benefits and perquisites we provide to each of our NEOs is set forth above in our “—Summary Compensation Table.”

Discretionary Long-Term Equity Incentive Awards

In connection with our initial public offering, our board of directors of our general partner adopted the LTIP. The LTIP was designed to promote our interests, as well as the interests of our unitholders, by rewarding the officers, employees and directors of us, our subsidiaries and our general partner for delivering desired performance results, as well as by strengthening our and our general partner’s ability to attract, retain and motivate qualified individuals to serve as officers, employees and directors.  The LTIP provides for the grant, from time to time at the discretion of the board of directors of our general partner, of unit awards, restricted units, phantom units, unit options, unit appreciation rights, distribution equivalent rights and other unit-based awards, although in 2015, as well as in 2014, we only granted phantom unit awards pursuant to the LTIP. The outstanding LTIP awards held by our NEOs are reflected in the table below.

During the years ended December 31, 2014 and 2015, our board of directors of our general partner granted phantom unit awards to certain key employees, including our NEOs. Each of these phantom unit awards vest in three equal annual installments, with the first installment vesting on the first anniversary of the date of grant. In the event of cessation of an employee’s service for any reason, all phantom units that have not vested prior to or in connection with such cessation of service shall automatically be forfeited. Each phantom unit granted to an employee, including the NEOs, is granted in tandem with a corresponding distribution equivalent right, which is paid quarterly on the distribution date from the grant date until the earlier of the vesting or the forfeiture of the related phantom units.  Each distribution equivalent right entitles the participant to receive payments in the amount equal to any distribution made by us following the grant date in respect of the grant date in respect of the common unit underlying the phantom unit to which such distribution equivalent right relates.

Prior to the Holdings Acquisition, Mr. Long historically received various forms of equity compensation, in the form of both capital and profits interests in us and our predecessor entities, and in connection with the Holdings Acquisition, Mr. Long re-invested a substantial portion of the cash proceeds received in respect of his prior equity interests in certain classes of capital or profit interest units in USA Compression Holdings.  Mr. Manias and Mr. Liuzzi joined us after the Holdings Acquisition.

Mr. Long was also granted Class B Units of USA Compression Holdings at the time of the Holdings Acquisition.  Mr. Manias and Mr. Liuzzi were granted Class B Units of USA Compression Holdings at the time of their employment.

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The grants the NEOs received had time-based vesting requirements (which, for Mr. Long, were satisfied in full as of December 31, 2013) and are designed not only to compensate but also to motivate and retain the recipients by providing an opportunity for equity ownership by our NEOs. The grants to our NEOs also provide our NEOs with meaningful incentives to increase unitholder value over time.  The Class B Units are profits interests that allow our NEOs to participate in the increase in value of USA Compression Holdings over and above an 8% annual and cumulative preferred return hurdle. Available cash will be distributed to the USA Compression Holdings members at such times as determined by its board of managers, at which time the holders of Class B Units could receive distributions if the cash distributed reaches the required distribution hurdles. Distributions to the Class B Unit holders could also occur in connection with a sale or liquidation event of USA Compression Holdings.  To date, our NEOs have not received distributions with respect to these awards.

Outstanding Equity Awards as of December 31, 2015

The following table provides information regarding the Class B Units in USA Compression Holdings held by the NEOs as of December 31, 2015. None of our NEOs held any option awards that were outstanding as of December 31, 2014 and 2015. Also reflected within the table are the outstanding phantom units that were granted to our NEOs from the LTIP during the years ended December 31, 2013, 2014 and 2015, respectively.

	Unit Awards
	Number of Class	Number of Class
	B Units That	B Units That Are
	Have Vested but	Unvested and	Market Value of	Number of		Market Value of
	Are Still	Outstanding	Class B Units	Outstanding		Outstanding
	Outstanding		That Have Not	Phantom Units		Phantom Units
Name	(#)(1)	(#)(2)	Vested ($)(3)	(#)		($) (7)
Eric D. Long	462,500
2013 Grant			—	20,408	(4)	234,488
2014 Grant				25,262	(5)	290,260
2015 Grant				75,528	(6)	867,817
William G. Manias	64,453	60,547
2013 Grant			—	4,691	(4)	53,900
2014 Grant				5,263	(5)	60,472
2015 Grant				36,505	(6)	419,442
Matthew C. Liuzzi	35,156	27,344
2013 Grant			—	3,456	(4)	39,709
2014 Grant				7,142	(5)	82,062
2015 Grant				29,531	(6)	339,311

(1) Represents the number of Class B Units in USA Compression Holdings that became vested but had not been settled as of December 31, 2015.  These Class B Units vested 25% on the one-year anniversary of the date of grant and 1/48 monthly thereafter; provided that with respect to Mr. Long 50% of the then-unvested portion of Class B Units vested at the time of the Partnership’s initial public offering, which occurred on January 18, 2013.

(2) Represents the number of Class B Units in USA Compression Holdings that have not yet vested.  The remainder of Mr. Manias’ awards are scheduled to vest pro rata each month through July 15, 2017.  The remainder of Mr. Liuzzi’s awards are scheduled to vest pro rata each month through April 17, 2017.

(3) As described under the heading “—Discretionary Long-Term Equity Incentive Awards,” the Class B Units are intended to allow recipients to receive a percentage of profits generated by USA Compression Holdings over and above certain return hurdles. The Class B Units had no recognizable value as of December 31, 2015 and the holders of the Class B Units had not received any distributions with respect to those awards during the 2015 year.

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(4) Represents the number of phantom units issued on March 11, 2013,April 17, 2013 and October 28, 2013 to Mr. Long, Mr. Manias and Mr. Liuzzi, respectively, pursuant to the LTIP that have not vested as of December 31, 2015.Each phantom unit is the economic equivalent of one common unit.  The phantom units are scheduled to vest in three equal annual installments on the anniversary of the date of grant.  In the event of cessation of the NEO’s service for any reason, all phantom units that have not vested prior to or in connection with such cessation of service shall automatically be forfeited. 

(5) Represents the number of phantom units issued on February 20, 2014 pursuant to the LTIP that had not vested as of December 31, 2015.  Each phantom unit is the economic equivalent of one common unit.  The phantom units are scheduled to vest in three equal annual installments on each subsequent February 15th.  The first installment vested on February 15, 2015.  In the event of cessation of the NEO’s service for any reason, all phantom units that have not vested prior to or in connection with such cessation of service shall automatically be forfeited.

(6) Represents the number of phantom units issued on February 19, 2015 pursuant to the LTIP that had not vested as of December 31, 2015.  Each phantom unit is the economic equivalent of one common unit.  The phantom units are scheduled to vest in three equal annual installments on each subsequent February 15th with the first installment vesting on February 15, 2016.  In the event of cessation of the NEO’s service for any reason, all phantom units that have not vested prior to or in connection with such cessation of service shall automatically be forfeited.

(7) Market value is calculated using the value of $11.49, which was the closing price of our common units on December 31, 2015.

Severance and Change in Control Arrangements

Our NEOs are entitled to severance payments and benefits upon certain terminations of employment and, in certain cases, in connection with a change in control of Holdings.

Each NEO currently has an employment agreement with USAC Management that provides for severance benefits upon a termination of employment. On January 1, 2013, we entered into the services agreement with USAC Management, pursuant to which USAC Management provides to us and our general partner management, administrative and operating services and personnel to manage and operate our business.  Pursuant to the services agreement, we will reimburse USAC Management for the allocable expenses for the services performed, including the salary, bonus, cash incentive compensation and other amounts paid to our NEOs. See Part III, Item 13 (“Certain Relationships and Related Transactions, and Director Independence”).

Severance Arrangements

Each NEO’s employment agreementhad an initial term that has been extended on a year-to-year basis and will be extended automatically for successive twelve-month periods thereafter unless either party delivers written notice to the other within ninety days prior to the expiration of the then-current employment term. Upon termination of an NEO’s employment for any reason, all earned, unpaid annual base salary and vacation time(and, with respect to the chief executive officer, accrued, unused sick time off) shall be paid to the NEO within thirty (30) days of the date of the NEO’s termination of employment. Upon termination of an NEO’s employment either by us for convenience or due to the NEO’s resignation for good reason, subject to the timely execution of a general release of claims, the NEO is entitled to receive (i) an amount equal to one times his annual base salary (plus, in the case of Mr. Long, an amount equal to one times his target annual bonus), payable in equal semi-monthly installments over one year following termination (the “Severance Period”) (or, if such termination occurs within two years following a change in control, in a lump sum within thirty days following the termination of employment), subject to acceleration upon the NEO’s death during the Severance Period, and (ii) continued coverage for twenty-four (24) months (or, with respect to Mr. Long, thirty (30) months) under our group medical plan in which the executive and any of his dependents were participating immediately prior to his termination. Continued coverage under our group medical plan is subsidized for the first twelve (12) months following termination, after which time continued coverage shall be provided at the NEO’s sole expense (except with respect to Mr. Long, who is entitled to reimbursement by us to the extent the cost of such coverage exceeds $1,200 per month) for the remainder of the applicable period. Additionally, upon a termination of an NEO’s employment by us for

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convenience, by the NEO for good reason, or due to the NEO’s death or disability, the NEO is entitled to receive (i) an amount equal to one times his annual bonus (up to his target annual bonus) for the immediately preceding year and (ii) a pro-rata portion of any earned annual bonus for the year in which termination occurs. During employment and for two years following termination, each NEO’s employment agreement prohibits him from competing with our business.

As used in the NEOs’ employment agreements, a termination for “convenience” means an involuntary termination for any reason, including a failure to renew the employment agreement at the end of an initial term or any renewal term, other than a termination for “cause.” “Cause” is defined in the NEOs’ employment agreements to mean (i) any material breach of the employment agreement or the Holdings Operating Agreement, by the executive, (ii) the executive’s breach of any applicable duties of loyalty to us or any of our affiliates, gross negligence or misconduct, or a significant act or acts of personal dishonesty or deceit, taken by the executive, in the performance of the duties and services required of the executive that has a material adverse effect on us or any of our affiliates, (iii) conviction or indictment of the executive of, or a plea of nolo contendere by the executive to, a felony, (iv) the executive’s willful and continued failure or refusal to perform substantially the executive’s material obligations pursuant to the employment agreement or the Holdings Operating Agreement or follow any lawful and reasonable directive from the board of managers of USA Compression Holdings (regarding Mr. Long) or the board of directors of our general partner (regarding Mr. Manias and Mr. Liuzzi) or, as applicable, the chief executive officer, other than as a result of the executive’s incapacity, or (v) a pattern of illegal conduct by the executive that is materially injurious to us or any of our affiliates or our or their reputation.

“Good reason” is defined in the NEOs’ employment agreements to mean (i) a material breach by us of the employment agreement, the Holdings Operating Agreement, or any other material agreement with the executive, (ii) any failure by us to pay to the executive the amounts or benefits to which he is entitled, other than an isolated and inadvertent failure not committed in bad faith, (iii) a material reduction in the executive’s duties, reporting relationships or responsibilities, (iv) a material reduction by us in the facilities or perquisites available to the executive or in the executive’s base salary, other than a reduction that is generally applicable to all similarly situated employees, or (v) the relocation of the geographic location of the executive’s current principal place of employment by more than fifty miles from the location of the executive’s principal place of employment. With respect to Mr. Long’s employment agreement, “good reason” also means the failure to appoint and maintain Mr. Long in the office of President and Chief Executive Officer.

Each of the Class B Units held by the NEOs would be forfeited for no consideration if the NEO was terminated for cause.  A termination for “Cause” under the USA Compression Holdings limited liability company agreement is defined substantially the same as the term used within the employment agreements described above.  In the event that the NEO’s employment is terminated for any reason, however, USA Compression Holdings (or its nominee) shall have the right, but not the obligation, to repurchase any vested Class B Units held by the terminated NEO for then-current fair market value or other agreed value.

Change in Control Benefits

We generally have double-trigger change in control benefits for our outstanding LTIP awards.  If a change in control occurs, and our NEOs are also terminated without cause or for good reason (each term as defined in the NEO’s employment agreement) in connection with that change in control event, the current LTIP phantom units would become fully vested.  One exception to this practice is with respect to our CEO, who would receive immediate vesting of any outstanding phantom units upon the change in control event.  In addition, a portion (subject to the discretion of the compensation committee) of each LTIP award granted to our NEOs during the year ending December 31, 2016 will immediately vest immediately prior to the change in control event.

Director Compensation

For the year ended December 31, 2015, Mr. Long, our only NEO who also served as a director, did not receive additional compensation for his service as a director.  Mr. Long’s compensation as an executive is reflected in the Summary Compensation Table above. Only the independent members of the board of directors of our general partner receive compensation for their service as directors.

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The following table shows the total compensation earned by each independent director during 2015.

	Fees Earned or			All Other
	Paid in Cash		Unit Awards	Compensation	Total
Name	($)		($) (1)	($) (2)	($)
John D. Chandler	116,000		75,000	1,737	192,737
Robert F. End	128,000		75,000	6,948	209,948
Forrest E. Wylie	99,000	(3)	75,000	6,948	180,948

(1) Represents the grant date fair value of our phantom units, calculated in accordance with ASC 718.  For a detailed discussion of the assumptions utilized in coming to these values, please see Note 10 to our consolidated financial statements.  As of December 31, 2015,  the independent members of the board of directors of our general partner held the following number of outstanding equity awards under the LTIP: Mr. Chandler, 3,932 phantom units; Mr. End, 3,932 phantom units; and Mr. Wylie, 7,865 phantom units.

(2) Amounts in this column reflect the value of distribution equivalent rights (“DERs”), received by the directors with respect to their outstanding phantom unit awards.

(3) Mr. Wylie elected to receive his annual cash retainer of $75,000 in phantom units that will vest in full on February 15, 2016.

Officers, employees or paid consultants or advisors of us or our general partner or its affiliates who also serve as directors do not receive additional compensation for their service as directors. Our directors who are not officers, employees or paid consultants or advisors of us or our general partner or its affiliates receive cash and equity based compensation for their services as directors. Our director compensation program consists of the following and will be subject to revision by the board of directors of our general partner from time to time:

· an annual cash retainer of $75,000,

· an additional annual retainer of $15,000 for service as the chair of any standing committee,

· meeting attendance fees of $2,000 per meeting attended, and

· an annual equity based award in the form of phantom units that will be granted under the LTIP, having a value as of the grant date of $75,000. Phantom unit awards are expected to be subject to vesting conditions (which, for the 2015 phantom unit grants was a one year vesting period).  DERs will be paid either on a current or deferred basis, in each case as will be determined at the time of grant of the awards; the 2015 phantom unit awards provided for deferred DERs.

Directors will also receive reimbursement for out-of-pocket expenses associated with attending such board or committee meetings and director and officer liability insurance coverage. Each director will be fully indemnified by us for actions associated with being a director to the fullest extent permitted under Delaware law.

ITEM 12.Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters

Security Ownership of Certain Beneficial Owners and Management

The following table sets forth the beneficial ownership of our units as of February 9, 2016 held by:

· each person who beneficially owns 5% or more of our outstanding units;

· all of the directors of USA Compression GP, LLC;

· each named executive officer of USA Compression GP, LLC; and

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· all directors and officers of USA Compression GP, LLC as a group.

Except as indicated by footnote, the persons named in the table below have sole voting and investment power with respect to all units shown as beneficially owned by them and their address is 100 Congress Avenue, Suite 450, Austin, Texas 78701.  All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the payment of our quarterly distribution on February 12, 2016.

							Percentage of
		Percentage of			Percentage of		Common and
	Common	Common		Subordinated	Subordinated		Subordinated
	Units	Units		Units	Units		Units
	Beneficially	Beneficially		Beneficially	Beneficially		Beneficially
Name of Beneficial Owner	Owned	Owned		Owned	Owned		Owned
USA Compression Holdings (1)	7,267,511	18.8	%	14,048,588	100	%	40.5	%
Argonaut (2)	7,715,948	20.0	%	—	—		14.7	%
Oppenheimer Funds, Inc. (3)	3,513,104	9.1	%	—	—		6.7	%
Eric D. Long (4)	167,970	*		—	—		*
William G. Manias (5)	40,140	*		—	—		*
Matthew C. Liuzzi (6)	25,165	*		—	—		*
John D. Chandler (7)	7,651	*		—	—		*
Jim H. Derryberry	—	—		—	—		—
William H. Shea, Jr.	—	—		—	—		—
Robert F. End (8)	20,554	*		—	—		*
Andrew W. Ward	—	—		—	—		—
Olivia C. Wassenaar	—	—		—	—		—
Forrest E. Wylie (9)	23,414	*		—	—		*
All directors and executive officers
as a group (12 persons) (10)	341,047	0.9	%	—	—		*

*Less than 1%.

(1) Eric D. Long, Matthew C. Liuzzi, William G. Manias, J. Gregory Holloway and David A. Smith, each of whom are executive officers of our general partner, Aladdin Partners, L.P., a limited partnership affiliated with Mr. Long, and R/C IV USACP Holdings, L.P. (“R/C Holdings”), own equity interests in USA Compression Holdings. USA Compression Holdings is managed by a three person board of managers consisting of Mr. Long, Mr. Ward and Ms. Wassenaar. The board of managers exercises investment discretion and control over the units held by USA Compression Holdings.

R/C Holdings is the record holder of approximately 97.6% of the limited liability company interests of USA Compression Holdings and is entitled to elect a majority of the members of the board of managers of USA Compression Holdings. R/C Holdings is an investment partnership affiliated with Riverstone/Carlyle Global Energy and Power Fund IV, L.P. (“R/C IV”). Management and control of R/C Holdings is vested in its general partner, which is in turn managed and controlled by its general partner, R/C Energy GP IV, LLC. R/C Energy GP IV, LLC is managed by an eight person management committee that includes Andrew W. Ward. The principal business address of R/C Energy GP IV, LLC is 712 Fifth Avenue, 51st Floor, New York, New York 10019.

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Mr. Long, Mr. Ward and Ms. Wassenaar, each of whom is a member of the board of managers of USA Compression Holdings and a member of the board of directors of our general partner, each disclaims beneficial ownership of the units owned by USA Compression Holdings.

(2) Argonaut has sole voting and dispositive power of 7,715,948 common units.  The principal business address of Argonaut is 6733 South Yale Avenue, Tulsa, Oklahoma 74136.

(3) Oppenheimer Funds, Inc. has the shared power to vote or to direct the vote, and the shared power to dispose or to direct the disposition of, 3,513,104 common units, including 3,429,769 common units held by Oppenheimer SteelPath MLP Income Fund, based on Amendment No. 5 to Schedule 13G filed on February 5, 2016 with the SEC. The principal business address of Oppenheimer Funds, Inc. is Two World Financial Center, 225 Liberty Street, New York, New York 10281, and the principal business address of Oppenheimer SteelPath MLP Income Fund is 6803 South Tucson Way, Centennial, Colorado 80112.

(4) Includes 61,462 common units held directly by Mr. Long, 6,665 common units held by Aladdin Partners, L.P., a limited partnership affiliated with Mr. Long, 39,720 common units held by certain trusts of which Mr. Long is the trustee, 1,908 common units held by Mr. Long’s spouse and 58,215 common units that Mr. Long has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units, subject to compensation committee discretion.  Mr. Long disclaims any beneficial ownership of the units held by Mr. Long’s spouse, except to the extent of his pecuniary interest therein.

(5) Includes 14,801 common units that Mr. Manias has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units, subject to compensation committee discretion.

(6) Includes 13,415 common units that Mr. Liuzzi has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units, subject to compensation committee discretion.

(7) Includes 3,932 common units that Mr. Chandler has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units.

(8) Includes 3,932 common units that Mr. End has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units.

(9) Includes 7,865 common units that Mr. Wylie has the right to acquire within 60 days upon the vesting and/or settlement of his phantom units.

(10) Includes 131,743 common units that certain of our directors and executive officers have the right to receive within 60 days upon the vesting and/or settlement of phantom units held by such directors and executive officers.

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Securities Authorized for Issuance Under Equity Compensation Plans

In connection with the consummation of our initial public offering on January 18, 2013, the board of directors of our general partner adopted the LTIP. The following table provides certain information with respect to this plan as of December 31, 2015:

			Number of securities
			remaining available for
			future issuance under
	Number of securities to	Weighted-average	equity compensation
	be issued upon exercise	exercise price of	plan (excluding securities
	of outstanding options,	outstanding options,	reflected in the first
Plan Category	warrants and rights	warrants and rights	column)
Equity compensation plans approved by security holders	—	N/A	—
Equity compensation plans not approved by security holders	457,081	N/A	771,532

For more information about our LTIP, please see Note 10 to our consolidated financial statements.

ITEM 13.Certain Relationships and Related Transactions, and Director Independence

Certain Relationships And Related Party Transactions

In connection with our formation and initial public offering, we and other parties have entered into the following agreements. These agreements were not the result of arm’s length negotiations, and they, or any of the transactions that they provide for, may not be effected on terms as favorable to the parties to these agreements as could have been obtained from unaffiliated third parties.

Services Agreement

We entered into a services agreement with USAC Management, effective on January 1, 2013, pursuant to which USAC Management provides to us and our general partner management, administrative and operating services and personnel to manage and operate our business. We or one of our subsidiaries pays USAC Management for the allocable expenses it incurs in its performance under the services agreement. These expenses include, among other things, salary, bonus, cash incentive compensation and other amounts paid to persons who perform services for us or on our behalf and other expenses allocated by USAC Management to us. USAC Management has substantial discretion to determine in good faith which expenses to incur on our behalf and what portion to allocate to us.

The services agreement has an initial term of five years, at which point it automatically renews for additional one year terms. The services agreement may be terminated at any time by (i) the board of directors of our general partner upon 120 days’ written notice for any reason in its sole discretion or (ii) USAC Management upon 120 days’ written notice if (a) we or our general partner experience a change of control, (b) we or our general partner breach the terms of the services agreement in any material respect following 30 days’ written notice detailing the breach (which breach remains uncured after such period), (c) a receiver is appointed for all or substantially all of our or our general partner’s property or an order is made to wind up our or our general partner’s business; (d) a final judgment, order or decree that materially and adversely affects the ability of us or our general partner to perform under the services agreement is obtained or entered against us or our general partner, and such judgment, order or decree is not vacated, discharged or stayed; or (e) certain events of bankruptcy, insolvency or reorganization of us or our general partner occur. USAC Management will not be liable to us for their performance of, or failure to perform, services under the services agreement unless its acts or omissions constitute gross negligence or willful misconduct.

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Procedures for Review, Approval and Ratification of Related Person Transactions

The board of directors of our general partner adopted a code of business conduct and ethics in connection with the closing of our initial public offering that provides that the board of directors of our general partner or its authorized committee will periodically review all related person transactions that are required to be disclosed under SEC rules and, when appropriate, initially authorize or ratify all such transactions. If the board of directors of our general partner or its authorized committee considers ratification of a related person transaction and determines not to so ratify, the code of business conduct and ethics provides that our management will make all reasonable efforts to cancel or annul the transaction.

The code of business conduct and ethics provides that, in determining whether or not to recommend the initial approval or ratification of a related person transaction, the board of directors of our general partner or its authorized committee should consider all of the relevant facts and circumstances available, including (if applicable) but not limited to: (i) whether there is an appropriate business justification for the transaction; (ii) the benefits that accrue to us as a result of the transaction; (iii) the terms available to unrelated third parties entering into similar transactions; (iv) the impact of the transaction on a director’s independence (in the event the related person is a director, an immediate family member of a director or an entity in which a director or an immediately family member of a director is a partner, shareholder, member or executive officer); (v) the availability of other sources for comparable products or services; (vi) whether it is a single transaction or a series of ongoing, related transactions; and (vii) whether entering into the transaction would be consistent with the code of business conduct and ethics.

The code of business conduct and ethics described above was adopted in connection with the closing of our initial public offering, and as a result the transaction described above was not reviewed under such policy. The transaction described above was not approved by an independent committee of our board of directors of our general partner and the terms were determined by negotiation among the parties.

Conflicts of Interest

Conflicts of interest exist and may arise in the future as a result of the relationships between our general partner and its affiliates, including USA Compression Holdings, on the one hand, and our partnership and our limited partners, on the other hand. The directors and officers of our general partner have fiduciary duties to manage our general partner in a manner beneficial to its owners. At the same time, our general partner has a fiduciary duty to manage our partnership in a manner beneficial to us and our unitholders.

Whenever a conflict arises between our general partner or its affiliates, on the one hand, and us and our limited partners, on the other hand, our general partner will resolve that conflict. Our partnership agreement contains provisions that modify and limit our general partner’s fiduciary duties to our unitholders. Our partnership agreement also restricts the remedies available to our unitholders for actions taken by our general partner that, without those limitations, might constitute breaches of its fiduciary duty.

Our general partner will not be in breach of its obligations under our partnership agreement or its fiduciary duties to us or our unitholders if the resolution of the conflict is:

· approved by the conflicts committee of our general partner, although our general partner is not obligated to seek such approval;

· approved by the vote of a majority of the outstanding common units, excluding any common units owned by our general partner or any of its affiliates;

· on terms no less favorable to us than those generally being provided to or available from unrelated third parties; or

· fair and reasonable to us, taking into account the totality of the relationships among the parties involved, including other transactions that may be particularly favorable or advantageous to us.

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Our general partner may, but is not required to, seek the approval of such resolution from the conflicts committee of its board of directors. In connection with a situation involving a conflict of interest, any determination by our general partner involving the resolution of the conflict of interest must be made in good faith, provided that, if our general partner does not seek approval from the conflicts committee and its board of directors determines that the resolution or course of action taken with respect to the conflict of interest satisfies either of the standards set forth in the third and fourth bullet points above, then it will conclusively be deemed that, in making its decision, the board of directors acted in good faith. Unless the resolution of a conflict is specifically provided for in our partnership agreement, our general partner or the conflicts committee may consider any factors that it determines in good faith to be appropriate when resolving a conflict. When our partnership agreement provides that someone act in good faith, it requires that person to reasonably believe he is acting in the best interests of the partnership.

Director Independence

Please see Part III, Item 10 (“Directors, Executive Officers and Corporate Governance—Board of Directors”) for a discussion of director independence matters.

ITEM 14.Principal Accountant Fees and Services

The following table presents fees for professional services rendered by our independent registered public accounting firm, KPMG LLP during the years ended December 31, 2015 and 2014:

	Year Ended December 31,
	2015		2014
	(in millions)
Audit Fees (1)	$	0.6	$	0.5
Audit-Related Fees		—		—
Tax Fees		—		—
All Other Fees		—		—
Total	$	0.6	$	0.5

(1) Expenditures classified as “Audit Fees” above were billed to USA Compression Partners, LP and include the audits of our annual financial statements, work related to the registration statements, reviews of our quarterly financial statements, and fees associated with comfort letters and consents related to equity offerings and registration statements.

Our audit committee has adopted an audit committee charter, which is available on our website and which requires the audit committee to pre-approve all audit and non-audit services to be provided by our independent registered public accounting firm. The audit committee does not delegate its pre-approval responsibilities to management or to an individual member of the audit committee.

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PART IV

ITEM 15.Exhibits and Financial Statement Schedules

(a) Documents filed as a part of this report.

1. Financial Statements.  See “Index to Consolidated Financial Statements” set forth on Page F-1.

2. Financial Statement Schedule

All other schedules have been omitted because they are not required under the relevant instructions.

3. Exhibits

The following documents are filed as exhibits to this report:

Exhibit Number	Description
3.1	Certificate of Limited Partnership of USA Compression Partners, LP (incorporated by reference to Exhibit 3.1 to Amendment No. 3 of the Partnership’s registration statement on Form S-1 (Registration No. 333-174803) filed on December 21, 2011)
3.2	First Amended and Restated Agreement of Limited Partnership of USA Compression Partners, LP (incorporated by reference to Exhibit 3.1 to the Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on January 18, 2013)
4.1	Registration Rights Agreement dated August 30, 2013 (incorporated by reference to Exhibit 4.1 to the Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on September 5, 2013)
10.1	Fifth Amended and Restated Credit Agreement dated as of December 13, 2013, by and among USA Compression Partners, LP, USAC OpCo 2, LLC and USAC Leasing 2, LLC, as guarantors, USA Compression Partners, LLC and USAC Leasing, LLC, as borrowers, the lenders party thereto from time to time, JPMorgan Chase Bank, N.A., as agent and LC issuer, J.P. Morgan Securities LLC, as lead arranger and sole book runner, Wells Fargo Bank, N.A., as documentation agent, and Regions Bank, as syndication agent (incorporated by reference to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on December 17, 2013)
10.2	Letter Agreement by and among USA Compression Partners, LLC, USAC Leasing, LLC, USACompression Partners, LP, USAC Leasing 2, LLC, USAC OpCo 2, LLC, the Lenders party thereto and JPMorgan Chase Bank, N.A., in its capacity as administrative agent for the Lenders, dated as of June 30,2014 (incorporated by reference to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K (FileNo. 001-35779) filed on July 3, 2014)
10.3	Second Amendment to the Fifth Amended and Restated Credit Agreement, dated as of January 6, 2015, by and among USA Compression Partners, LP, as guarantor, USA Compression Partners, LLC, USACLeasing, LLC, USAC OpCo 2, LLC and USAC Leasing 2, LLC, as borrowers, the lenders party theretoand JPMorgan Chase Bank, N.A., as agent and LC issuer (incorporated by reference to Exhibit 10.1 tothe Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on January 9, 2015)
10.4†	Long-Term Incentive Plan of USA Compression Partners, LP (incorporated by reference to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on January 18, 2013)
10.5†	Employment Agreement, dated December 23, 2010, between USA Compression Partners, LLC and Eric D. Long (incorporated by reference to Exhibit 10.5 to Amendment No. 4 of the Partnership’s registration statement on Form S-1 (Registration No. 333-174803) filed on February 13, 2012)

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10.6†	Employment Agreement, dated April 17, 2013, between USA Compression Management Services, LLC and Matthew C. Liuzzi (incorporated by reference to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K (File No. 001-35779) filed on January 15, 2015)
10.7*†	Employment Agreement, dated July15, 2013, between USA Compression Management Services, LLCand William G. Manias
10.8	Services Agreement, dated effective January 1, 2013, by and among USA Compression Partners, LP, USA Compression GP, LLC and USA Compression Management Services, LLC (incorporated by reference to Exhibit 10.11 to Amendment No. 10 of the Partnership’s registration statement on Form S-1 (Registration No. 333-174803) filed on January 7, 2013)
10.9†	USA Compression Partners, LP 2013 Long-Term Incentive Plan—Form of Director Phantom Unit Agreement (incorporated by reference to Exhibit 10.8 to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 001-35779) filed on March 28, 2013)
10.10†	USA Compression Partners, LP 2013 Long-Term Incentive Plan—Form of Employee Phantom Unit Agreement (incorporated by reference to Exhibit 10.10 to the Partnership’s Annual Report on Form10-K for the year ended December 31, 2013 (File No. 001-35779) filed on February 20, 2014)
10.11†	USA Compression Partners, LP 2013 Long-Term Incentive Plan—Form of Director Phantom Unit Agreement (in lieu of Annual Cash Retainer) (incorporated by reference to Exhibit 10.10 to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2012 (File No. 001-35779) filed on March 28, 2013)
10.12†	USAC Compression Partners, LP Annual Cash Incentive Program (incorporated by reference to Exhibit 10.12 to the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2013 (File No. 001-35779) filed on February 20, 2014)
10.13*†	USA Compression Partners, LP 2013 Long-Term Incentive Plan—Form of Employee Phantom Unit Agreement(with updated performance metrics)
21.1*	List of subsidiaries of USA Compression Partners, LP
23.1*	Consent of KPMG LLP
31.1*	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934
31.2*	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934
32.1#	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2#	Certification of 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 Extension Schema Document
101.CAL*	XBRL Calculation Linkbase Document
101.DEF*	XBRL Definition Linkbase Document
101.LAB*	XBRL Label Linkbase Document
101.PRE*	XBRL Presentation Linkbase Document

.

*Filed Herewith.

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#Furnished herewith; not considered to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934 or otherwise subject to the liabilities of that section.

†Management contract or compensatory plan or arrangement required to be filed as an exhibit to this Annual Report on Form 10-K pursuant to Item 15(b).

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SIGNATURES

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.

USA COMPRESSION PARTNERS, LP
By:	USA Compression GP, LLC,
	its General Partner
By:	/s/ Eric D. Long
	Eric D. Long
	President and Chief Executive Officer
	(Principal Executive Officer)
Date:	February 11, 2016

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 11, 2016.

Name	Title
/s/ Eric D. Long	President and Chief Executive Officer and Director
Eric D. Long	(Principal Executive Officer)
/s/ Matthew C. Liuzzi	Vice President, Chief Financial Officer and Treasurer
Matthew C. Liuzzi	(Principal Financial Officer)
/s/ Michael D. Lenox	Vice President—Finance and Chief Accounting Officer
Michael D. Lenox	(Principal Accounting Officer)
/s/ John D. Chandler
John D. Chandler	Director
/s/ Jim H. Derryberry
Jim H. Derryberry	Director
/s/ Robert F. End
Robert F. End	Director
/s/ William H. Shea, Jr.
William H. Shea, Jr.	Director
/s/ Andrew W. Ward
Andrew W. Ward	Director
/s/ Olivia C. Wassenaar
Olivia C. Wassenaar	Director
/s/ Forrest E. Wylie
Forrest E. Wylie	Director

83

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

Report of Independent Registered Public Accounting Firm	F-2
Consolidated Balance Sheets as of December 31, 2015 and 2014	F-3
Consolidated Statements of Operations for the years ended December 31, 2015, 2014 and 2013	F-4
Consolidated Statements of Changes in Partners’ Capital for the years ended December 31, 2015, 2014 and 2013	F-5
Consolidated Statements of Cash Flows for the years ended December 31, 2015, 2014 and 2013	F-6
Notes to Consolidated Financial Statements	F-7
Supplemental Selected Quarterly Financial Data	S-1

F-1

Report of Independent Registered Public Accounting Firm

The Partners

USA Compression Partners, LP:

We have audited the accompanying consolidated balance sheets of USA Compression Partners, LP (a Delaware limited partnership) and subsidiaries as of December 31, 2015 and 2014, and the related consolidated statements of operations, changes in partners’ capital, and cash flows for each of the years in the three‑year period ended December 31, 2015. These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of USA Compression Partners, LP and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the years in the three‑year period ended December 31, 2015, in conformity with U.S. generally accepted accounting principles.

/s/ KPMG LLP

Dallas, Texas

February 11, 2016

F-2

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Consolidated Balance Sheets

December31, 2015 and 2014

(in thousands, except for unit amounts)

	2015		2014
Assets
Current assets:
Cash and cash equivalents	$	7	$	6
Accounts receivable, net:
Trade, net		28,465		25,159
Other		3,023		2,926
Inventory, net		18,872		8,923
Prepaid expenses		2,600		1,020
Total current assets		52,967		38,034
Property and equipment, net		1,318,043		1,162,637
Installment receivable		17,275		20,241
Identifiable intangible assets, net		78,773		82,357
Goodwill		35,866		208,055
Other assets		6,847		5,158
Total assets	$	1,509,771	$	1,516,482
Liabilities and Partners’ Capital
Current liabilities:
Accounts payable	$	23,840	$	44,535
Accrued liabilities		20,582		21,708
Deferred revenue		17,000		15,855
Total current liabilities		61,422		82,098
Long-term debt		729,187		594,864
Other liabilities		874		—
Partners’ capital:
Limited partner interest:
Common units, 38,556,245 and 31,307,116 units issued and outstanding, respectively		557,583		600,401
Subordinated units, 14,048,588 units issued and outstanding each period		150,787		225,221
General partner interest		9,918		13,898
Total partners’ capital		718,288		839,520
Total liabilities and partners’ capital	$	1,509,771	$	1,516,482

See accompanying notes to consolidated financial statements.

F-3

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Consolidated Statements of Operations

Years ended December31, 2015, 2014 and 2013

(in thousands, except per unit amounts)

	2015		2014		2013
Revenues:
Contract operations	$	263,816	$	217,361	$	150,360
Parts and service		6,729		4,148		2,558
Total revenues		270,545		221,509		152,918
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		81,539		74,035		48,097
Selling, general and administrative		40,950		38,718		27,587
Depreciation and amortization		85,238		71,156		52,917
Loss (gain) on sale of assets		(1,040)		(2,233)		284
Impairment of compression equipment (Note 4)		27,274		2,266		203
Impairment of goodwill		172,189		—		—
Total costs and expenses		406,150		183,942		129,088
Operating income (loss)		(135,605)		37,567		23,830
Other income (expense):
Interest expense, net		(17,605)		(12,529)		(12,488)
Other		22		11		9
Total other expense		(17,583)		(12,518)		(12,479)
Net income (loss) before income tax expense		(153,188)		25,049		11,351
Income tax expense (Note 7)		1,085		103		280
Net income (loss)	$	(154,273)	$	24,946	$	11,071
Less:
Earnings allocated to general partner prior to initial public offering on January 18, 2013	$	—	$	—	$	5
Earnings available for limited partners prior to initial public offering on January 18, 2013	$	—	$	—	$	530
Net income (loss) subsequent to initial public offering on January 18, 2013	$	(154,273)	$	24,946	$	10,536
Net income (loss) subsequent to initial public offering allocated to:
General partner’s interest in net income (loss)	$	(1,477)	$	760	$	211
Limited partners’ interest in net income (loss):
Common units	$	(107,513)	$	16,811	$	5,805
Subordinated units	$	(45,283)	$	7,375	$	4,520
Weighted average common units outstanding:
Basic		34,109,547		28,087,498		18,043,075
Diluted		34,109,547		28,146,446		18,086,745
Weighted average subordinated units outstanding:
Basic and diluted		14,048,588		14,048,588		14,048,588
Net income (loss) per common unit:
Basic	$	(3.15)	$	0.60	$	0.32
Diluted	$	(3.15)	$	0.60	$	0.32
Net income (loss) per subordinated unit:
Basic and diluted	$	(3.22)	$	0.52	$	0.32
Distributions declared per limited partner unit in respective periods	$	2.09	$	2.01	$	1.73

See accompanying notes to consolidated financial statements.

F-4

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Consolidated Statements of Changes in Partners’ Capital

Years ended December31, 2015, 2014 and 2013

(in thousands)

					Partners’ Capital								Total
	General		Limited		Common Units			Subordinated Units			General Partner Units		Partners’
	Partners		Partners		Units	Amount		Units	Amount		Amount		Capital
Partners’ capital, December 31, 2012		2,396		341,130	—		—	—		—		—		343,526
Net income January 1, 2013 — January 18, 2013		5		530	—		—	—		—		—		535
Conversion of Partners’ capital for common and subordinated units, Incentive Distribution Rights, and General Partner interest		(2,401)		(341,660)	4,049		74,526	14,049		258,605		10,930		—
Issuance of common units in initial public offering		—		—	11,000		180,555	—		—		—		180,555
Vesting of phantom units		—		—	4		—	—		—		—		—
General partner contribution		—		—	—		—	—		—		4,251		4,251
Distributions and DERs		—		—	—		(22,872)	—		(17,533)		(819)		(41,224)
Issuance of common units		—		—	1,084		26,286	—		—		—		26,286
Unit-based compensation		—		—	—		1,343	—		—		—		1,343
Acquisition of S&R compression assets		—		—	7,425		181,919	—		—		—		181,919
Net income January 19, 2013 — December 31, 2013		—		—	—		5,805	—		4,520		211		10,536
Partners’ capital, December 31, 2013	$	—	$	—	23,562	$	447,562	14,049	$	245,592	$	14,573	$	707,727
Vesting of phantom units		—		—	76		1,707	—		—		—		1,707
General partner contribution		—		—	—		—	—		—		294		294
Distributions and DERs		—		—	—		(53,854)	—		(27,746)		(1,729)		(83,329)
Issuance of common units		—		—	7,669		188,992	—		—		—		188,992
Unit-based compensation		—		—	—		353	—		—		—		353
Modification of unit-based compensation		—		—	—		(1,170)	—		—		—		(1,170)
Net income		—		—	—		16,811	—		7,375		760		24,946
Partners’ capital, December 31, 2014	$	—	$	—	31,307	$	600,401	14,049	$	225,221	$	13,898	$	839,520
Vesting of phantom units		—		—	101		1,844	—		—		—		1,844
Distributions and DERs		—		—	—		(69,480)			(29,151)		(2,503)		(101,134)
Issuance of common units		—		—	7,148		132,006	—		—		—		132,006
Unit-based compensation		—		—	—		325	—		—		—		325
Net loss		—		—	—		(107,513)	—		(45,283)		(1,477)		(154,273)
Partners’ capital, December 31, 2015	$	—	$	—	38,556	$	557,583	14,049	$	150,787	$	9,918	$	718,288

See accompanying notes to consolidated financial statements.

F-5

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Consolidated Statements of Cash Flows
Years ended December 31, 2015, 2014 and 2013

(in thousands)

	2015		2014		2013
Cash flow from operating activities:
Net income (loss)	$	(154,273)	$	24,946	$	11,071
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization		85,238		71,156		52,917
Amortization of debt issue costs		1,702		1,224		2,192
Unit-based compensation expense		3,863		3,034		1,343
Net loss (gain) on sale of assets		(1,040)		(2,233)		284
Impairment of compression equipment		27,274		2,266		203
Impairment of goodwill		172,189		—		—
Changes in assets and liabilities:
Accounts receivable		(439)		(2,659)		(11,674)
Inventory		(14,340)		(4,942)		(5,725)
Prepaids		(1,580)		1,380		(600)
Other noncurrent assets		(3)		(39)		3,824
Accounts payable		(3,310)		(1,431)		8,132
Accrued liabilities and deferred revenue		2,120		9,189		6,223
Net cash provided by operating activities		117,401		101,891		68,190
Cash flow from investing activities:
Capital expenditures		(281,050)		(381,943)		(159,547)
Proceeds from sale of property and equipment		1,735		1,420		2,227
Acquisitions, net of cash		—		—		3,374
Proceeds from insurance recovery		1,157		—		—
Net cash used in investing activities		(278,158)		(380,523)		(153,946)
Cash flows from financing activities:
Proceeds from long-term debt		480,004		538,644		243,501
Payments on long-term debt		(345,681)		(364,714)		(324,834)
Net proceeds from issuance of common units		75,111		138,047		180,555
Cash paid for taxes related to net settlement of unit-based awards		(210)		(334)		—
Cash Distributions		(45,078)		(32,345)		(14,669)
General partner contribution		—		294		4,251
Financing costs		(3,388)		(961)		(3,048)
Net cash provided by financing activities		160,758		278,631		85,756
Increase (decrease) in cash and cash equivalents		1		(1)		—
Cash and cash equivalents, beginning of year		6		7		7
Cash and cash equivalents, end of year	$	7	$	6	$	7
Supplemental cash flow information:
Cash paid for interest	$	17,110	$	12,622	$	10,603
Cash paid for income taxes	$	282	$	115	$	196
Supplemental non-cash transactions:
Non-cash distributions to certain limited partners (DRIP)	$	56,895	$	51,707	$	26,286
Change in capital expenditures included in accounts payable and accrued liabilities	$	(19,256)	$	16,515	$	15,846
Capital Lease Transaction:
Installment receivable	$	—	$	(24,820)	$	—
Property and equipment write-off	$	—	$	22,134	$	—
(Gain) on transaction	$	—	$	(2,686)	$	—

See accompanying notes to consolidated financial statements.

F-6

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013

(1)  The Partnership, Nature of Business, and Recent Transactions

USA Compression Partners, LP, a Texas limited partnership (the “Former Partnership”), was formed on July 10, 1998. In October 2008, the Former Partnership entered into several transactions through which the Former Partnership was reorganized into a holding company, USA Compression Holdings, LP (the “Partnership”). The owners of the Former Partnership caused the Partnership to be formed as a Texas limited partnership to conduct its affairs as the holding company of an operating and leasing structure of entities. The Former Partnership’s owners then transferred their equity interests in the Former Partnership to the Partnership in exchange for identical interests in the Partnership. The Former Partnership became a wholly-owned subsidiary of the Partnership, and was converted into USA Compression Partners, LLC, a Delaware, single-member, limited liability company (the “Operating Subsidiary”) to continue providing compression services to customers of the Former Partnership. Concurrently, the Operating Subsidiary formed a wholly-owned subsidiary, USAC Leasing, LLC, as a Delaware limited liability company (the “Leasing Subsidiary”), and agreed to sell its then existing compressor fleet to the Leasing Subsidiary for assumption of debt relating to the then existing fleet. On June 7, 2011, the Partnership converted from a Texas limited partnership into a Delaware limited partnership and changed its name from USA Compression Holdings, LP to USA Compression Partners, LP. USA Compression GP, LLC, a Delaware limited liability Company and the general partner of the Partnership, is referred to herein as the “General Partner.”  In connection with the S&R Acquisition (as defined below), the Partnership acquired all of the membership interests in USAC OpCo 2, LLC, a Texas limited liability company (“OpCo 2”), which owned all of the membership interests in USAC Leasing 2, LLC, a Texas limited liability company (“LeaseCo 2”). LeaseCo 2 owns all of the compression assets acquired in the S&R Acquisition as well as certain compression assets acquired after the acquisition.  Each of Leasing Subsidiary and LeaseCo 2 leases its compressor fleet to Operating Subsidiary and OpCo 2, respectively, for use in providing compression services to customers. The Partnership is a guarantor to Operating Subsidiary’s revolving credit facility and each of Leasing Subsidiary, OpCo2 and LeaseCo2 are co-borrowers on the revolving credit facility (see Note 8). The accompanying consolidated financial statements include the accounts of the Partnership, the Operating Subsidiary, the Leasing Subsidiary, OpCo 2 and LeaseCo 2, and all intercompany balances and transactions have been eliminated in consolidation. The Operating Subsidiary, the Leasing Subsidiary, OpCo 2 and LeaseCo 2, are collectively referred to herein, as the “Operating Subsidiaries.”

The Partnership, through the Operating Subsidiaries, provides compression services under term contracts with customers in the natural gas and crude oil industry, using natural gas compression packages that it designs, engineers, owns, operates and maintains.

Partnership net income (loss) is allocated to the partners, both general and limited, in proportion to their respective interest in the Partnership.

(2)  Summary of Significant Accounting Policies

(a)Cash and Cash Equivalents

Cash and cash equivalents consist of all cash balances. The Partnership considers investments in highly liquid financial instruments purchased with an original maturity of 90 days or less to be cash equivalents. 

(b)Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $2.1 million and $0.4 million as of December 31, 2015 and 2014, respectively, is the Partnership’s best estimate of the amount of probable credit losses in the Partnership’s existing accounts receivable. Bad debt expense for the year ended December 31, 2015 was $1.8 million.  The determination of the allowance for doubtful accounts requires us to make estimates and judgments regarding our customers’ ability to pay amounts due.  The Partnership determines the allowance based upon historical write-off experience, specific customer circumstances and the overall business climate in which our customers operate. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

F-7

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(c)Inventories

Inventory consists of serialized and non-serialized parts used primarily in the repair of compression units. Serialized parts inventories are valued at the lower of cost or market value using the specific identification method, while non-serialized parts inventory is valued using the weighted average cost method. Purchases of these assets are considered operating activities in the consolidated statement of cash flows. 

Significant components of inventories as of December 31, 2015 and 2014 are as follows (in thousands):

	2015		2014
Serialized parts	$	18,361	$	9,286
Non-serialized parts		825		—
Total Inventory, gross		19,186		9,286
Less: obsolete and slow moving reserve		(314)		(363)
Total Inventory, net	$	18,872	$	8,923

(d)Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compression equipment are capitalized and depreciated over 3 to 5 years. Ordinary maintenance and repairs are charged to cost of operations, exclusive of depreciation and amortization. Depreciation is calculated using the straight-line method over the estimated useful lives of the assets as follows:

Compression equipment	25 years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

Depreciation expense for the years ended December 31, 2015, 2014 and 2013 was $81.7 million, $67.6 million and $49.7 million, respectively.

(e)Impairments of Long-Lived Assets

Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written-down to estimated fair value. An asset shall be tested for impairment when events or circumstances indicate that its carrying value may not be recoverable or will no longer be utilized in the operating fleet. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows associated with the operating fleet, an impairment loss equal to the amount of the carrying value exceeding the fair value of the asset is recognized. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows, the expected net sale proceeds compared to the other similarly configured fleet units the Partnership recently sold or a review of other units recently offered for sale by third parties, or the estimated component value of the equipment the Partnership plans to use.   

Refer to Note 4 for more detailed information about impairment charges during the years ended December 31, 2015 and 2014.

(f)Revenue Recognition

Revenue from contract operations is recorded when earned over the period of the contract, which generally ranges from one month to five years. Parts and service revenue is recorded as parts are delivered or services are performed for the customer.

F-8

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(g)Income Taxes

The Partnership elected to be treated under SubChapter K of the Internal Revenue Code. Under SubChapter K, a partnership return is filed annually reflecting each partner’s allocable share of the partnership’s income or loss. Therefore, no provision has been made for federal income tax. Partnership net income (loss) is allocated to the partners in proportion to their respective interest in the Partnership.

As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by the Partnership generally flow through to its unitholders. However, Texas imposes an entity-level income tax on partnerships.

Refer to Note 7 for more detailed information about the Revised Texas Franchise Tax for the years ended December 31, 2015, 2014 and 2013.

(h)Fair Value Measurements

Accounting standards on fair value measurements establish a framework for measuring fair value and stipulate disclosures about fair value measurements. The standards apply to recurring and nonrecurring financial and non-financial assets and liabilities that require or permit fair value measurements. Among the required disclosures is the fair value hierarchy of inputs the Partnership uses to value an asset or a liability. The three levels of the fair value hierarchy are described as follows:

Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Partnership has the ability to access at the measurement date.

Level 2 inputs are those other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly.

Level 3 inputs are unobservable inputs for the asset or liability.

As of December 31, 2015 and 2014, the Partnership’s financial instruments consisted primarily of cash and cash equivalents, trade accounts receivable, trade accounts payable and long-term debt. The book values of cash and cash equivalents, trade accounts receivable, and trade accounts payable are representative of fair value due to their short-term maturity. The carrying amount of long-term debt approximates fair value due to the floating interest rates associated with the debt.

Phantom unit awards granted to employees under the USA Compression Partners, LP 2013 Long-Term Incentive Plan (the “LTIP”) are accounted for as a liability, and such liability is re-measured on a quarterly basis.  The liability is based on the publicly quoted price of the Partnership’s common units, which is considered a Level 1 input.  Refer to Note 10 for more detailed information about unit-based compensation for the years ended December 31, 2015, 2014 and 2013.

As part of the impairment analysis of goodwill, the fair value of the Partnership’s goodwill was re-measured using Level 3 inputs.  Refer to the Goodwill section of Note 2 below for more detailed information about the valuation as of December 31, 2015 and 2014.

(i)Pass Through Taxes

Sales taxes incurred on behalf of, and passed through to, customers are accounted for on a net basis.

F-9

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(j)Use of Estimates

The preparation of the consolidated financial statements of the Partnership in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires the management of the Partnership to make estimates and assumptions that affect the amounts reported in these consolidated financial statements and the accompanying results. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could differ from these estimates.

(k)Identifiable Intangible Assets

As of December 31, 2015, identifiable intangible assets consisted of the following (in thousands):

	Customer
	Relationships		Trade Names		Non-compete		Total
Gross Balance at December 31, 2013	$	78,700		15,600		900	$	95,200
Additions		—		—		—		—
Accumulated amortization		(10,047)		(2,496)		(300)		(12,843)
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Gross Balance at December 31, 2014		78,700		15,600		900		95,200
Additions		—		—		—		—
Accumulated amortization		(12,782)		(3,120)		(525)		(16,427)
Net Balance at December 31, 2015	$	65,918	$	12,480	$	375	$	78,773

Identifiable intangible assets are amortized using the straight-line method over their estimated useful lives, which is the period over which the assets are expected to contribute directly or indirectly to the Partnership’s future cash flows. The estimated useful lives range from 4 to 30 years. Amortization expense for the years ended December 31, 2015, 2014 and 2013 was $3.6 million, $3.6 million and $3.2 million, respectively.  The expected amortization of the identifiable intangible assets for each of the five succeeding years is as follows (in thousands):

Year ending December 31,	Total
2016	$	3,584
2017		3,509
2018		3,359
2019		3,359
2020		3,359

The Partnership assesses identifiable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The Partnership did not record any impairment of identifiable intangible assets in the years ended December 31, 2015, 2014 or 2013.

(l)Goodwill

Goodwill represents consideration paid in excess of the fair value of the identifiable net assets acquired in a business combination. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of October 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.

As of October 1, 2015, a quantitative assessment was performed to determine whether the fair value of the Partnership’s single reporting unit was greater than its carrying value.  As of October 1, 2015, the fair value was determined to be in excess of the carrying value. Due to the identification of certain impairment indicators during the fourth quarter of 2015, specifically (1) the decline in the market price of the Partnership’s common units, (2) the sustained decline in global commodity prices, and (3) the decline in performance of the Alerian MLP Index, the Partnership prepared a quantitative assessment as of December 31, 2015.  This assessment indicated that the calculated

F-10

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

fair value was less than the carrying value.  As such, the Partnership prepared a Step 2 impairment test which measures the amount of the impairment loss and involves a hypothetical allocation of the estimated fair value of the reporting unit among all assets and liabilities of the reporting unit.  The carrying value of goodwill exceeded the implied value of goodwill and an impairment charge was recorded for $172.2 million.  The fair value of our single reporting unit was calculated using the Discounted Cash Flow Method, an income approach.  This method utilizes Level 3 inputs from the fair value hierarchy. The impairment of goodwill is primarily the result of the sustained decline in the market price of the Partnership’s common units.  The continued decline in commodity prices has adversely impacted many of the Partnership’s customers and resulted in a significant decline in their future capital expansion plans.  This has in turn reduced the Partnership’s expected future capital expansion plans and in turn, the Partnership’s estimated future cash flows. 

The Partnership had approximately $35.9 million of goodwill remaining on the balance sheet as of December 31, 2015.No impairment of goodwill was recorded in the years ended December 31, 2014 and 2013.

(m)Capitalized Interest

For each of the years ended December 31, 2015 and 2014, the Partnership capitalized $0.3 million of interest expense in accordance with Accounting Standards Codification (“ASC”) Topic 835-20 for interest costs incurred during the period related to upfront payments required in acquiring certain compression units.  The Partnership capitalized no interest during the year ended December 31, 2013.

(n)Operating Segment

The Partnership operates in a single business segment, the compression services business. 

(3)  Acquisition

On August 30, 2013, the Partnership completed the acquisition of assets and certain liabilities related to S&R Compression, LLC’s (“S&R”) business of providing gas lift compression services to third parties engaged in the exploration, production, gathering, processing, transportation or distribution of oil and gas in exchange for 7,425,261 common units, which were valued at $181.9 million at the time of issuance (the “S&R Acquisition”). The S&R Acquisition was consummated pursuant to the contribution agreement with S&R and Argonaut Private Equity L.L.C. (“Argonaut”). The S&R Acquisition had an effective date (from a standpoint of settling working capital) of June 30,2013. The consolidated financial statements reflect the operating results of the S&R Acquisition for the period subsequent to the August 30, 2013 acquisition. At the time of the closing of the acquisition, the common units issued in the S&R Acquisition were not registered pursuant to the Securities Act of 1933, as amended(the “Securities Act”), or any applicable state securities laws, and, at the time of issuance, were restricted securities under the federal securities laws. The resale of the common units issued in the S&R Acquisition was registered pursuant to the Shelf Registration Statement (as defined below). The effective purchase price of $178.5 million reflects customary effective-date adjustments such as a $3.4million purchase price adjustment due to working capital changes from the effective date to the closing date.

F-11

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

The transaction was accounted for in accordance with ASC Topic 805, Business Combinations. The purchase price allocation as of August 30, 2013 is comprised of the following components (in thousands):

Issuance of limited partner units	$	181,919
Less cash received for working capital adjustment		(3,374)
Total consideration	$	178,545
Trucks and Trailers	$	2,158
Compression equipment		117,784
Computers		23
Intangibles
Customer relationships		6,700
Non-compete		900
Total intangibles		7,600
Goodwill		50,980
Allocation of Purchase Consideration	$	178,545

Expenses associated with acquisition activities and transaction activities related to the S&R Acquisition for the year ended December 31, 2013 were $2.1 million and were included in selling, general and administrative expenses (“SG&A”). The acquisition was recorded at fair value, which was determined using the cost and market approaches for the fixed assets, the multi-period excess earnings method for the customer relationships asset and the with-and-without method for the non-compete agreement. In applying these accounting principles, the Partnership estimated the fair value of the S&R assets acquired to be $127.6 million. This measurement resulted in the recognition of goodwill totaling approximately $51.0 million. Goodwill was calculated as the excess of the consideration transferred to acquire S&R over the acquisition date estimated fair value of the assets acquired. Goodwill recorded in the S&R Acquisition primarily represents the value of the opportunity to expand into gas lift operations with a high quality fleet, the experience and technical expertise of former S&R employees who have joined the Partnership and the addition of strategic areas of operations in which the Partnership did not previously have a significant presence. This goodwill was included as a component of the goodwill impairment, as described in Note 2.  The intangible asset customer relationships will be amortized over a life of 20 years and the intangible asset non-compete will be amortized over the 4-year term of the agreement.

Revenue, Net Income and Pro Forma Financial Information — Unaudited

For the period of August 30, 2013 to December 31, 2013, the S&R Acquisition accounted for $14.5 million of revenue, $4.4 million of direct operating expenses, and $0.6 million of SG&A and $3.7 million of depreciation and amortization, resulting in $5.8 million of net income. The net income attributable to these assets does not reflect certain expenses, such as certain SG&A and interest expense; therefore, this information is not intended to report results as if these operations were managed on a stand-alone basis.

The unaudited pro forma financial information was prepared assuming the S&R Acquisition occurred on January 1,2013. The financial information was derived from the Partnership’s audited historical consolidated financial statements for the year ended December 31, 2013 and S&R’s unaudited interim financial statements from January 1, 2013 through August 30, 2013.

The pro forma adjustments were based on currently available information and certain estimates and assumptions by management. If the S&R Acquisition had been in effect on the dates or for the periods indicated, the results may have been substantially different. For example, the Partnership may have operated the assets differently than S&R, realized revenue may have been different and costs of operation of the compression assets may have been different. This pro forma financial information is provided for illustrative purposes only and may not provide an indication of results in the

F-12

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

future.  The following table presents a summary of pro forma financial information (in thousands, except for unit amounts):

	Year Ended December 31,
	2013
	(unaudited)
Total revenues	$	176,254
Net income		15,919
Net income allocated to:
General partner’s interest in net income		318
Limited partner’s interest in net income:
Common units		10,054
Subordinated units		5,546
Basic and diluted net income per common unit	$	0.39
Basic and diluted net income per subordinated unit	$	0.39

In preparing the pro forma financial information, certain information was derived from financial records and certain information was estimated. The sources of information and significant assumptions are described below:

(a) Revenues and direct operating expenses for S&R were derived from the historical financial records of S&R. Incremental revenue adjustments related to the S&R Acquisition were $27.1 million for the year ended December 31, 2013. Incremental operating costs related to the S&R Acquisition were $12.2 million for the year ended December 31, 2013.

(b) Depreciation and amortization was estimated using the straight-line method and reflects the incremental depreciation and amortization expense incurred due to adding the compression assets and intangible fair value assets acquired from S&R. Incremental depreciation and amortization was estimated at $9.7 million for the year ended December 30, 2013.

(c) Incremental transaction expenses related to the S&R Acquisition were $2.1 million and were assumed to be funded from cash on hand.

(d) The S&R Acquisition was financed solely with common units issued in consideration for the assets and liabilities acquired as part of the S&R Acquisition.

(e) The capital contribution made by the General Partner to maintain its then2% general partner interest in the Partnership in connection with the issuance of common units in the S&R Acquisition was used to pay down the Partnership’s revolving credit facility resulting in a reduction of interest expense. Incremental interest expense reductions were estimated at $90,000 for the year ended December 31,2013.

F-13

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(4)  Property and Equipment

Property and equipment consisted of the following at December 31 (in thousands):

	2015		2014
Compression equipment	$	1,520,835	$	1,311,943
Furniture and fixtures		669		619
Automobiles and vehicles		19,284		17,303
Computer equipment		21,457		11,913
Leasehold improvements		1,197		858
Total Property and equipment, gross		1,563,442		1,342,636
Less: accumulated depreciation and amortization		(245,399)		(179,999)
Total Property and equipment, net	$	1,318,043	$	1,162,637

As of December 31, 2015 and 2014, there was $13.1 million and $32.4 million, respectively, of property and equipment purchases in accounts payable and accrued liabilities.

For the year ended December 31, 2015, non-cash transfers of inventory to and from property and equipment totaled $4.0 million.  These transfers have been treated as non-cash inventory activities in the Consolidated Statements of Cash Flows.

During the year ended December 31, 2015, insurance recoveries of $1.2 million were received on previously impaired compression equipment and are reported within the Loss (gain) on sale of assets line in the Consolidated Statements of Operations. 

During the year ended December 31, 2015, the Partnership evaluated the future deployment of its idle fleet under current market conditions and determined to retire and either sell or re-utilize the key components of 166 compressor units, or approximately 58,000 horsepower, that were previously used to provide services in the Partnership’s business.  This compression equipment was written down to its respective estimated salvage value, measured using quoted market prices, or the estimated component value of the equipment the Partnership plans to use.  The Partnership recorded $27.3 million, $2.3 million and $0.2 million in impairment of compression equipment for the years ended December 31, 2015, 2014 and 2013, respectively.

(5)  Installment Receivable

On June 30, 2014, the Partnership entered into a FMV Bargain Purchase Option Grant Agreement (the “Capital Lease Transaction”) with a customer, pursuant to which the Partnership granted a bargain purchase option to the customer with respect to certain compressor packages leased to the customer (each a “Subject Compressor Package”). The bargain purchase option provides the customer with an option to acquire the equipment at a value significantly less than the fair market value at the end of the lease term.

The Capital Lease Transaction was accounted for as a sales type lease and, as of December 31, 2015 and 2014, resulted in a current installment receivable of $3.0 million and $2.8 million, respectively, included in other accounts receivable and a long-term installment receivable of $17.3 million and $20.2 million, respectively. Additionally, the Partnership recorded a $2.6 million gain on sale of assets related to the Capital Lease Transaction for the year ended December 31, 2014.

For the year ended December 31, 2015, non-cash transfers from long-term installment receivable to current installment receivable totaled $3.0 million.  These transfers have been treated as non-cash accounts receivable activities in the Consolidated Statements of Cash Flows.

F-14

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(6)  Accrued Liabilities

Other current liabilities included accrued payroll and benefits and accrued property taxes.  The Partnership recognized $7.1 million and $5.5 million of accrued payroll and benefits as of December 31, 2015 and 2014, respectively.  The Partnership recognized $4.1 million and $4.8 million of accrued property taxes as of December 31, 2015 and 2014, respectively.

(7) Income Tax Expense

The Partnership is subject to the Revised Texas Franchise Tax (“Texas Margin Tax”). The Partnership does not do business in any other state where a similar tax is applied.

The Texas Margin Tax became effective for tax reports originally due on or after January 1, 2008. This margin tax requires certain forms of legal entities, including limited partnerships, to pay a tax of 1.0% (or 0.75% for 2015 and forward) on its  “margin,” as defined in the law, based on annual results. The margin tax base to which the tax rate is applied is the least of (1) 70% of total revenues for federal income tax purposes, (2) total revenue less cost of goods sold or (3) total revenue less compensation for federal income tax purposes. For the years ended December 31, 2015, 2014 and 2013, the Partnership recorded expense related to the Texas margin tax of $1.1 million, $0.1 million and $0.3 million, respectively.

Components of income tax expense are as follows (in thousands):

	2015		2014		2013
Current tax expense:
State income tax	$	211	$	103	$	280
Total current tax expense		211		103		280
Deferred tax expense:
State income tax	$	874	$	—	$	—
Total deferred tax expense		874		—		—
Total income tax expense	$	1,085	$	103	$	280

Deferred income tax balances are the direct effect of temporary differences between the financial statement carrying amounts and the tax basis of assets and liabilities at the enacted tax rates expected to be in effect when the taxes are actually paid or recovered. The tax effects of temporary differences that give rise to deferred tax liabilities are as follows (in thousands):

	2015		2014
Deferred tax liabilities
Property and equipment	$	874	$	—
Total deferred tax liabilities		874		—
Net deferred tax liabilities	$	874	$	—

The Financial Accounting Standards Board’s (“FASB”) ASC Topic 740-10 (“ASC 740-10”) provides guidance on measurement and recognition in accounting for income tax uncertainties and provides related guidance on derecognition, classification, disclosure, interest, and penalties. As of December 31, 2015, the Partnership had no material unrecognized tax benefits (as defined in ASC 740-10). The Partnership does not expect to incur interest charges or penalties related to its tax positions, but if such charges or penalties are incurred, the Partnership’s policy is to account for interest charges as Interest expense, net and penalties as Income tax expense in the Consolidated Statements of Operations.

F-15

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(8)  Long-Term Debt

The long-term debt of the Partnership consisted of the following as of December 31 (in thousands):

	2015		2014
Revolving Credit Facility	$	729,187	$	594,864

On December 13, 2013, the Partnership entered into a Fifth Amended and Restated Credit Agreement (the “revolving credit facility”) whereby the aggregate commitment under the facility increased from $600 million to $850 million (subject to availability under the Partnership’s borrowing base and a further potential increase of $100 million) and reduced the applicable margin for BBA London Interbank Offering Rate (“LIBOR”) loans to a range of 150 to 225 basis points above LIBOR, depending on the Partnership’s leverage ratio. The Partnership’s revolving credit facility is secured by a first priority lien against its assets.

On June 30, 2014, the Partnership entered into a letter agreement regarding a limited consent, amendment and subordination relating to the revolving credit facility to (a) permit the Capital Lease Transaction, (b) permit the customer’s lien with respect to the Subject Compressor Packages, (c) to subordinate the lien of JPMorgan Chase Bank, N.A., as administrative agent under our revolving credit facility, for the benefit of itself and the lenders under the revolving credit facility, to the lien and purchase option of the customer with respect to the Subject Compressor Packages, (d) authorize the release of the lien of the administrative agent, for the benefit of itself and the lenders, upon the exercise by the customer of its purchase option with respect to a specific Subject Compressor Package and (e) amend certain other provisions of the revolving credit facility.

On January 6, 2015, the Partnership entered into a Second Amendment to our revolving credit facility, whereby, the aggregate commitment under the revolving credit facility increased from $850.0 million to $1.1 billion (subject to availability under our borrowing base), with a further potential increase of $200 million and the maturity date of the revolving credit facility was extended to January 6, 2020.  In addition, this Second Amendment provided additional flexibility under the financial covenants of the revolving credit facility.

The revolving credit facility permits the Partnership to make distributions of available cash to unitholders so long as (a) no default under the facility has occurred, is continuing or would result from the distribution, (b) immediately prior to and after giving effect to such distribution, the Partnership is in compliance with the facility’s financial covenants and (c) immediately after giving effect to such distribution, the Partnership has availability under the revolving credit facility of at least $20 million. In addition, the revolving credit facility contains various covenants that may limit, among other things, the Partnership’s ability to (subject to exceptions):

· grant liens;

· make certain loans or investments;

· incur additional indebtedness or guarantee other indebtedness;

· enter into transactions with affiliates;

· merge or consolidate;

· sell the Partnership’s assets; or

· make certain acquisitions.

F-16

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

The revolving credit facility also contains various financial covenants, including covenants requiring the Partnership to maintain:

· a minimum EBITDA to interest coverage ratio of 2.5 to 1.0; and

· a maximum funded debt to EBITDA ratio, determined as of the last day of each fiscal quarter, for the annualized trailing three months of (a) 5.50 to 1.0 through December 31, 2014, (b) 5.95 to 1.0 through the end of the fiscal quarter ending June 30, 2015, (c) 5.50 to 1.0 through the end of the fiscal quarter ending June 30, 2016 and (d) 5.00 to 1.0 thereafter, in each case subject to a provision for increases to such thresholds by 0.5 in connection with certain future acquisitions for the six consecutive month period following the period in which any such acquisition occurs.

If a default exists under the revolving credit facility, the lenders will be able to accelerate the maturity on the amount then outstanding and exercise other rights and remedies.

The Partnership paid various loan fees and incurred costs in respect of the revolving credit facility in the amount of $3.4 million,$0.2 million, and $3.0 million in 2015, 2014 and 2013, respectively, which were capitalized to loan costs and will be amortized through January 2020. The Partnership wrote off $0.3 million in 2013 related to certain third parties that exited the credit facility.

As of December 31, 2015 and 2014, the Partnership was in compliance with all of its covenants under the revolving credit facility.

As of December 31, 2015, the Partnership had outstanding borrowings under its revolving credit facility of $729.2 million, $370.8 million of borrowing base availability and,subject to compliance with the applicable financial covenants, available borrowing capacity of $101.0 million. The borrowing base consists of eligible accounts receivable, inventory and compression units. The largest component, representing 91% and 94% of the borrowing base as of December 31, 2015 and 2014, respectively, was eligible compression units.  Eligible compression units consist of compressor packages that are leased, rented or under service contracts to customers and carried in the financial statements as fixed assets. The Partnership’s interest rate in effect for all borrowings under its revolving credit facility as of December 31, 2015 and 2014 was 2.26% and 2.16%, respectively, with an average interest rate of 2.24%,2.22%, and 2.43% during 2015, 2014 and 2013, respectively. There were no letters of credit issued as of December 31, 2015 and 2014.

The revolving credit facility matures in January 2020 and the Partnership expects to maintain this facility for the term. The facility is a “revolving credit facility” that includes a “springing” lock box arrangement, whereby remittances from customers are forwarded to a bank account controlled by the Partnership, and the Partnership is not required to use such remittances to reduce borrowings under the facility, unless there is a default or excess availability under the facility is reduced below $20 million. As the remittances do not automatically reduce the debt outstanding absent the occurrence of a default or a reduction in excess availability below $20 million, the debt has been classified as long-term as of December 31, 2015 and 2014.

Maturities of long-term debt (in thousands):

Year ending December 31,
2016		—
2017		—
2018		—
2019		—
2020		729,187
Total Debt	$	729,187

F-17

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

In the event that any of the Operating Subsidiaries guarantees any series of the debt securities as described in the Partnership’s registration statement filed on Form S-3 (Reg. No. 333-193724), such guarantees will be full and unconditional and made on a joint and several basis for the benefit of each holder and the Trustee. However, such guarantees will be subject to release, subject to certain limitations, as follows (i) upon the sale, exchange or transfer, whether by way of a merger or otherwise, to any Person that is not an Affiliate of the Partnership, of all the Partnership’s direct or indirect limited partnership or other equity interest in such Subsidiary Guarantor; or (ii) upon the Partnership’s or USA Compression Finance Corp.’s (together, the “Issuers”) delivery of a written notice to the Trustee of the release or discharge of all guarantees by such Subsidiary Guarantor of any Debt of the Issuers other than obligations arising under the indenture governing such debt and any debt securities issued under such indenture, except a discharge or release by or as a result of payment under such guarantees. Capitalized terms used but not defined in this paragraph are defined in the Form of Indenture filed as exhibit 4.1 to such registration statement.

(9)  Partner’s Capital

As of February 9, 2016, USA Compression Holdings held 7,267,511 common units and 14,048,588 subordinated units and controlled the General Partner which held an approximate 1.46% general partner interest (the “General Partner’s Interest”) and the incentive distribution rights (“IDRs”). See the Consolidated Statement of Changes in Partners’ Capital.

Subordinated Units

All of the subordinated units are held by USA Compression Holdings. The Partnership’s limited partnership agreement (the “Partnership Agreement”) provides that, during the subordination period, the common units have the right to receive distributions of Available Cash from Operating Surplus (each as defined in the Partnership Agreement) each quarter in an amount equal to $0.425 per common unit (the “Minimum Quarterly Distribution”), plus any arrearages in the payment of the Minimum Quarterly Distribution from Operating Surplus on the common units from prior quarters, before any distributions of Available Cash from Operating Surplus may be made on the subordinated units. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions from Operating Surplus until the common units have received the Minimum Quarterly Distribution plus any arrearages from prior quarters. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be Available Cash from Operating Surplus to be distributed on the common units. The subordination period will end on the first business day after the Partnership has earned and paid at least (i) $1.70 (the Minimum Quarterly Distribution on an annualized basis) on each outstanding unit and the corresponding distribution on the General Partner’s Interest, for each of three consecutive, non-overlapping four-quarter periods ending on or after December 31, 2015 or (ii) $2.55  (150.0% of the annualized Minimum Quarterly Distribution) on each outstanding unit and the corresponding distributions on the General Partner’s Interest and the related distribution on the incentive distribution rights for the four-quarter period immediately preceding that date. When the subordination period ends, all subordinated units will convert into common units on a one-for-one basis, and all common units thereafter will no longer be entitled to arrearages.  All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the Partnership’s payment of its quarterly distribution on February 12, 2016.

Incentive Distribution Rights

The General Partner holds all of the IDRs. The following table illustrates the percentage allocations of Available Cash from Operating Surplus between the unitholders and the General Partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of the General Partner and the unitholders in any Available Cash from Operating Surplus the Partnership distributes up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.” The percentage interests shown for the Partnership’s unitholders and the General Partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for the General Partner include its General Partner’s Interest, and assume the General Partner

F-18

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

has contributed any additional capital necessary to maintain its General Partner’s Interest, the General Partner has not transferred the IDRs and there are no arrearages on common units.

		Marginal Percentage Interest in
	Total Quarterly	Distributions
	Distributions per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.54	%	1.46	%
First Target Distribution	up to $0.4888	98.54	%	1.46	%
Second Target Distribution	above $0.4888 up to $0.5313	85.54	%	14.46	%
Third Target Distribution	above $0.5313 up to $0.6375	75.54	%	24.46	%
Thereafter	above $0.6375	50.54	%	49.46	%

Cash Distributions

The Partnership has declared quarterly distributions per unit to limited partner unitholders of record, including holders of common, subordinated and phantom units and distributions paid to the General Partner, including the General Partner’s Interest and IDRs, as follows (dollars in millions, except distribution per unit):

	Distribution per			Amount Paid to		Amount Paid to		Amount Paid to		Amount Paid to
	Limited Partner			Common		Subordinated		General		Phantom		Total
Payment Date	Unit			Unitholders		Unitholder		Partner		Unitholders		Distribution
May 15, 2013	$	0.348	(1)	$	5.2	$	4.9	$	0.2	$	—	$	10.3
August 14, 2013		0.440			6.7		6.2		0.3		—		13.2
November 14, 2013		0.460			10.6		6.5		0.3		—		17.4
February 14, 2014		0.480			11.3		6.7		0.4		—		18.4
May 15, 2014		0.490			11.8		6.9		0.4		0.2		19.3
August 14, 2014		0.500			15.1		7.0		0.5		0.2		22.8
November 14, 2014		0.505			15.5		7.1		0.5		0.2		23.3
February 13, 2015		0.510			16.0		7.2		0.5		0.1		23.8
May 15, 2015		0.515			16.6		7.2		0.6		0.2		24.6
August 14, 2015		0.525			17.2		7.4		0.7		0.2		25.5
November 13, 2015		0.525			19.7		7.4		0.7		0.2		28.0

(1) Prorated to reflect 72 days of quarterly cash distribution rate of $0.435 per unit.

Announced Quarterly Distribution

On January 21, 2016, the Partnership announced a cash distribution of $0.525 per unit on its common and subordinated units. The distribution will be paid on February 12, 2016 to unitholders of record as of the close of business on February 2, 2016. USA Compression Holdings, the owner of approximately 41% of the Partnership’s outstanding limited partner interests has elected to reinvest all of this distribution with respect to its units pursuant to the Partnership’s distribution reinvestment plan (the “DRIP”).

Dividend Reinvestment Program

For the years ended December 31, 2015, 2014 and 2013, distributions of $56.9 million, $51.7 million and $26.3 million, respectively, were reinvested under the DRIP resulting in the issuance of 3.1 million, 2.1 million and 1.1 million common units, respectively.  Such distributions are treated as non-cash transactions in the accompanying Consolidated Statements of Cash Flows.

Equity Offerings

F-19

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

On September 15, 2015, the Partnership closed a public offering of 4,000,000 common units at a price to the public of $19.33 per common unit.  The Partnership used the net proceeds of $74.4 million (net of underwriting discounts and commission and offering expenses) to reduce the indebtedness outstanding under its revolving credit facility.

On May 21, 2015, the Partnership issued 34,921 common units in a private placement to Argonaut for $0.7 million in a transaction that was exempt from registration under Section 4(a)(2) of the Securities Act. The Partnership used the proceeds from the private placement for general partnership purposes.  There were no other unregistered sales of securities during the years ended December 31, 2015 or 2014.

On May 19, 2014, the Partnership closed a public offering of 6,600,000 common units, of which 5,600,000 common units were sold by the Partnership and 1,000,000 common units were sold by certain selling unitholders, including USA Compression Holdings and Argonaut (the “Selling Unitholders”), at a price to the public of $25.59 per common unit. USA Compression Holdings and Argonaut granted the underwriters an option to purchase up to an additional 990,000 common units to cover over-allotments, which was exercised by the underwriters in full and closed on May 27, 2014. The Partnership used the net proceeds of $138.0 million (net of underwriting discounts and commissions and offering expenses) to reduce the indebtedness outstanding under the revolving credit facility.

On April 23, 2014, the Partnership’s registration statement on Form S-3 (Reg. No. 333-193724) (as amended, the “Shelf Registration Statement”) was declared effective by the Securities and Exchange Commission. Under the Shelf Registration Statement, the Partnership registered the offer and sale of (1) up to $1.0 billion aggregate principal amount of Partnership securities, including common units and other classes of units representing limited partner interests in the Partnership, debt securities and guarantees of debt securities and (2) up to 27,074,118 common units held by certain selling unitholders and up to 6,266,024 common units that may be issued to such selling unitholders under the Partnership’s DRIP.

Earnings Per Common and Subordinated Unit

The computations of earnings per common unit and subordinated unit are based on the weighted average number of common units and subordinated units, respectively, outstanding during the applicable period. The subordinated units and the General Partner’s Interest (including its IDRs) meet the definition of participating securities as defined by the FASB’s ASC Topic 260 Earnings Per Share; therefore, the Partnership is required to use the two-class method in the computation of earnings per unit. Basic earnings per common and subordinated unit are determined by dividing net income (loss) allocated to the common and subordinated units, respectively, after deducting the amount allocated to the General Partner (including distributions to the General Partner on the General Partner Interest and its IDRs), by the weighted average number of outstanding common and subordinated units, respectively, during the period. Net income (loss) is allocated to the common units, subordinated units and the General Partner Interest (including its IDRs) based on their respective shares of the distributed and undistributed earnings for the period. To the extent cash distributions exceed net income (loss) for the period, the excess distributions are allocated to all participating units outstanding based on their respective ownership percentages. Diluted earnings per unit are computed using the treasury stock method, which considers the potential issuance of limited partner units associated with the LTIP. Unvested phantom units are not included in basic earnings per unit, as they are liability classified and as such are not considered to be participating securities, but are included in the calculation of diluted earnings per unit.  For the year ended December 31, 2015, approximately 121,000 incremental phantom units were excluded from the calculation of diluted units because the impact was anti-dilutive.

(10)  Unit-Based Compensation

Class B Units

During 2011 and 2013, USA Compression Holdings issued to certain employees and members of its management, who provide services to the Partnership, Class B non-voting units. These Class B units are liability-classified profits interest awards which have a service condition.

F-20

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

The holders of Class B units in USA Compression Holdings are entitled to a cash payment of 10% of net proceeds primarily from a monetization event, as defined under the provisions of the Amended and Restated Limited Liability Company Agreement of USA Compression Holdings, or the Holdings Operating Agreement, related to these Class B unit awards, in excess of USA Compression Holdings’ Class A unitholder’s capital contributions and an 8% return on each Class A unitholder’s capital account, compounded annually, (both of which are due upon a monetization event) to the extent of vested units over total units of the respective class. Each holder of Class B units is then allocated their pro-rata share of the respective class of unit’s entitlement based on the number of units held over the total number of units in that class of units. The Class B units vest 25% on the first anniversary date of the grant date and then monthly for the next three years (at the rate of 1/48 per month) subject to certain continued employment. The units have no expiry date provided the employee remains employed with USA Compression Holdings or one of its subsidiaries.

The Class B units vesting schedule consisted of the following at December 31 (in thousands, except unit amounts):

	Class B Interest Units
					Unit-based
	Grant date fair				compensation
	value per unit		Vested	Unvested	expense
Balance of awards as of December 31, 2012			570,313	617,187
Issuance of profit interest units	$	—	—	187,500
Vesting			531,250	(531,250)
Forfeitures			(62,500)	(62,500)
Balance of awards as of December 31, 2013			1,039,063	210,937
Expense recorded in 2013					$	—
Issuance of profit interest units	$	—	—	—
Vesting			80,078	(80,078)
Forfeitures			—	—
Balance of awards as of December 31, 2014			1,119,141	130,859
Expense recorded in 2014					$	—
Issuance of profit interest units	$	—	—	—
Vesting			42,968	(42,968)
Forfeitures			(125,000)	—
Balance of awards as of December 31, 2015			1,037,109	87,891
Expense recorded in 2015					$	—

Fair value of the Class B units is based on enterprise value calculated by a predetermined formula. As of December 31, 2015 and 2014, there was no unit-based compensation expense or liability recorded related to these Class B units.

The Partnership’s initial public offering constituted a qualified public offering for purposes of certain vesting provisions of the employee holder’s Class B Units, which resulted in 50% of certain employee’s unvested Class B Units vesting.  Any remaining unvested Class B Units generally (i) vest 25% percent on the first anniversary date of the grant date and (ii) with respect to the remaining Class B Units, will vest monthly for the next three years (at the rate of 1/48 per month) subject to the employee’s continued employment on each applicable vesting date. If any employee holder’s employment is terminated by the General Partner without cause or the employee resigns for good reason, the remaining unvested Class B Units will vest in full. As used in the Holdings Operating Agreement, “good reason” and “cause” have the meanings set forth in each employee’s employment agreement.

Long-Term Incentive Plan

In connection with the Partnership’s initial public offering, the board of directors of the General Partner (the “Board”) adopted the LTIP for employees, consultants and directors of the General Partner and any of its affiliates who perform services for the Partnership. The LTIP consists of unit options, unit appreciation rights, restricted units, phantom units, DERs, unit awards, profits interest units and other unit-based awards. The LTIP initially limits the number of

F-21

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

common units that may be delivered pursuant to awards under the plan to 1,410,000 common units. Awards that are forfeited, cancelled, paid or otherwise terminate or expire without the actual delivery of units will be available for delivery pursuant to other awards. The LTIP is administered by the Board or a committee thereof.

In February 2014, the Board approved a modification to all of the phantom unit awards that were granted to employees pursuant to the LTIP during the 2013 fiscal year. The modification provided all employees with phantom unit awards granted during 2013 with an option of settling a portion of their award in cash and a portion in units.  The amount that can be settled in cash is in excess of the employee’s minimum statutory tax-withholding rate.  ASC Topic 718, Compensation-Stock Compensation, requires the entire amount of an award with such features to be accounted for as a liability.  Liability accounting requires the Partnership to re-measure the fair value of the award at each financial statement date until the award is vested or cancelled.  The fair value is re-measured at the end of each reporting period using the market price of the common units.  During the requisite service period, compensation cost is recognized using the proportionate amount of the award’s fair value that has been earned through service to date. The total incremental compensation cost recorded in February 2014 as a result of the modification was $1.2 million.

During the years ended December 31, 2015 and 2014, an aggregate of 320,636 and 187,856, respectively, phantom units (including the corresponding DERs) were granted under the LTIP to the General Partner’s executive officers and employees and independent directors. The phantom units granted in 2015 and 2014 provide the employees with an option of settling a portion of their award in cash and a portion in units. The phantom units (including the corresponding DERs) awarded are subject to restrictions on transferability, customary forfeiture provisions and time vesting provisions generally in which, for employees, one-third of each award vests on the first, second, and third anniversaries of the date of grant. The phantom units will generally vest in full in the event of a change in control and a termination of employment.  Grants of phantom units to the independent directors of the General Partner generally vest in full on the one year anniversary of the grant date. Award recipients do not have all the rights of a unitholder in the partnership with respect to the phantom units until the units have vested. Phantom units granted to employees during the years ended December 31, 2015 and 2014 are accounted for as a liability and are re-measured at the end of each reporting period using the market price of the common units. As of December 31, 2015 and 2014, the total unit-based compensation liability was $2.0 million and $1.3 million, respectively.  Phantom units granted to independent directors do not have the cash settlement option and as such are subject to equity treatment.  During the requisite service period, compensation cost is recognized using the proportionate amount of the award’s fair value that has been earned through service to date.

The General Partner’s executive officers, employees and independent directors were granted these awards to incentivize them to help drive the Partnership’s future success and to share in the economic benefits of that success. The compensation costs associated with these awards are recorded in selling, general and administrative expense. During the years ended December 31, 2015, 2014 and 2013, the Partnership recognized $3.9 million, $3.0 million and $1.3 million, respectively, of compensation expense associated with these awards, net of expense related to forfeited units. During the years ended December 31, 2015 and 2014, amounts paid by the Partnership for income tax withholdings related to the vesting of awards under the LTIP were $0.2 million in each year and the value of phantom units that vested and were redeemed by the Partnership for cash was immaterial and$0.1 million, respectively.  During the year ended December 31, 2013, no employee awards under the LTIP plan vested.  The total fair value and intrinsic value of the phantom units vested under the LTIP was $2.2 million, $2.4 million, and $0.1 million during the years ended December 31, 2015, 2014 and 2013, respectively. 

F-22

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

The following table summarizes information regarding phantom unit awards for the periods presented:

		Weighted-Average
		Grant Date Fair
	Number of Units	Value per Unit(1)
Phantom units outstanding at December 31, 2012	—	$	—
Granted	269,521		19.96
Vested	3,816		19.65
Forfeited	35,714		19.60
Phantom units outstanding at December 31, 2013	229,991	$	20.02
Granted	187,856		26.29
Vested	88,707		17.20
Forfeited	60,038		18.81
Phantom units outstanding at December 31, 2014	269,102	$	23.65
Granted	320,636		19.04
Vested	111,991		22.96
Forfeited	20,666		21.77
Phantom units outstanding at December 31, 2015	457,081	$	22.10

(1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

The unrecognized compensation cost associated with phantom unit awards was an aggregate $3.6 million as of December 31, 2015. The Partnership expects to recognize the unrecognized compensation cost for these awards on a weighted-average basis over a period of 1.7 years.

Each phantom unit granted to an independent director is granted in tandem with a corresponding DER, which shall remain outstanding and unpaid from the grant date until the earlier of the payment or forfeiture of the related phantom units. Each vested DER shall entitle the participant to receive payments in the amount equal to any distributions made by the Partnership following the grant date in respect of the common unit underlying the phantom unit to which such DER relates. Accumulated but unpaid DERs are never paid if the underlying phantom unit award is forfeited.

Each phantom unit granted to an executive officer or an employee is granted in tandem with a corresponding DER, which is paid quarterly on the distribution date from the grant date until the earlier of the settlement or the forfeiture of the related phantom units.

(11)  Employee Benefit Plans

A 401(k) plan is available to all of the Partnership’s current employees. The plan permits employees to make contributions up to 20% of their salary, up to statutory limits, which was $18,000 in 2015. The plan provides for discretionary matching contributions by the Partnership on an annual basis. Aggregate matching contributions made by the Partnership were $0.8 million, $0.7 million and $0.6 million for the years ended December 31, 2015, 2014 and 2013, respectively.

(12)  Transactions with Related Parties

William Shea, Jr., who has served as a director of the General Partner since June 2011, served as Chief Executive Officer of the general partner of a customer from March 2010 to March 2014. For the years ended December 31, 2014 and 2013, subsidiaries of this customer made compression service payments to us of approximately $0.6 million and $3.0 million, respectively.

John Chandler, who has served as a director of the General Partner since October 2013, has served as a directorofa customer since October 2014. During the year ended December 31, 2015 and the period of Mr. Chandler’s appointment for the year ended December 31, 2014, the Partnership recognized approximately $8.8million and $1.7 million,  

F-23

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

respectively, in revenue on compression services and $1.3 million and $0.1 million, respectively, in accounts receivable from this customer on the Consolidated Balance Sheets as of December 31, 2015 and 2014.

(13)Recent Accounting Pronouncements

In April 2015, the FASB issued an Accounting Standards Update (“ASU”) that clarified when fees paid in a cloud computing arrangement pertain to the acquisition of a software license and/or services.  When a cloud computing arrangement includes a license of software, the fee attributable to the software license portion of the arrangement will be capitalized when the criteria for capitalization of internal-use software are met.  When a cloud computing arrangement does not include a license of software, the arrangement will be treated as a service contract and the cost will be expensed as the services are received.  This ASU is effective for annual and interim periods in fiscal years beginning after December 15, 2015. Early adoption is permitted and entities may elect to adopt this ASU either prospectively, for all arrangements entered into or materially modified after the effective date, or retrospectively. The Partnership concluded this ASU will not have a material impact on its consolidated financial statements.

In July 2015, the FASB agreed to defer by one year the mandatory effective date of its revenue recognition standard to annual and interim periods in fiscal years beginning after December 15, 2017, but will also provide entities the option to adopt it as of the original effective date. The option to use either a retrospective or cumulative-effect transition method will not change.  The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

Also in July 2015, the FASB issued an ASU that changes the measurement principle for inventory from the lower of cost or market to the lower of cost and net realizable value.  This ASU requires prospective adoption for inventory measurements for annual and interim periods in fiscal years beginning after December 15, 2016. Early adoption is permitted. The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

(14)Commitments and Contingencies

(a) Operating Leases

Rent expense for office space, warehouse facilities and certain corporate equipment for the years ended December 31, 2015, 2014 and 2013 was $2.9 million, $2.3 million and $1.6 million, respectively. Commitments for future minimum lease payments for non-cancelable leases are as follows (in thousands):

2016	$	1,645
2017		1,460
2018		1,160
2019		1,028
2020		27
Thereafter		—
Total	$	5,320

(b) Major Customers

The Partnership did not have revenue from any single customer greater than 10% of total revenue for the year ended December 31, 2015. The Partnership had revenue from one customer representing  11.6% and 14.3% of total revenue for the years ended December 31, 2014 and 2013, respectively.  No other customer represented greater than 10% of revenue for the years ended December 31, 2014 and 2013.

F-24

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Notes to Consolidated Financial Statements

December31, 2015, 2014 and 2013  

(c) Litigation

From time to time, the Partnership and its subsidiaries may be involved in various claims and litigation arising in the ordinary course of business. In management’s opinion, the resolution of such matters is not expected to have a material adverse effect on the Partnership’s consolidated financial position, results of operations or cash flows.

(d) Equipment Purchase Commitments

The Partnership’s future capital commitments are comprised of binding commitments under purchase orders for new compression units ordered but not received. The commitments as of December 31, 2015 were $20.8 million, all of which are expected to be settled within the next twelve months.

(15)   Subsequent Events

Phantom Units

On February 9, 2016, an aggregate of 36,361 phantom units (including the corresponding DERs) were granted under the LTIP to the independent directors of the Partnership’s General Partner.  The phantom units (including the corresponding DERs) awarded are subject to restrictions on transferability, customary forfeiture provisions and will vest in full on February 15, 2017.

F-25

Supplemental Selected Quarterly Financial Data

(Unaudited)

In the opinion of the Partnership’s management, the summarized quarterly financial data below (in thousands, except per unit amounts) contains all appropriate adjustments, all of which are normally recurring adjustments, considered necessary to present fairly the Partnership’s financial position and the results of operations for the respective periods.

	March 31,		June 30,		September 30,		December 31,
	2015		2015		2015		2015
Revenue	$	65,000	$	66,390	$	70,540	$	68,615
Gross profit (1)		45,789		47,311		48,621		47,285
Net income (loss)		11,456		(15,904)		9,805		(159,630)
Income (loss) per common unit - basic and diluted	$	0.24	$	(0.34)	$	0.21	$	(3.02)
Income per subordinated unit - basic and diluted		0.24		(0.35)		0.16		(3.03)

	March 31,		June 30,		September 30,		December 31,
	2014		2014		2014		2014
Revenue	$	50,202	$	53,266	$	57,045	$	60,995
Gross profit		32,485		35,269		37,615		42,105
Net income		3,915		7,518		5,013		8,501
Income per common unit - basic and diluted	$	0.10	$	0.20	$	0.11	$	0.18
Income per subordinated unit - basic and diluted		0.10		0.14		0.11		0.18

(1) Gross profit is defined as revenue less cost of operations, exclusive of depreciation and amortization expense.

S-1

EX-10.13

Exhibit 10.13

USA COMPRESSION PARTNERS, LP
2013 LONG-TERM INCENTIVE PLAN

FORM OF
EMPLOYEE PHANTOM UNIT AGREEMENT

Pursuant to this Phantom Unit Agreement, dated as of Grant Date identified in the Grant Notice below (this “Agreement”), USA Compression GP, LLC (the “Company”), as the general partner of USA Compression Partners, LP (the “Partnership”), hereby grants to _______ (the “Participant”) the following award of Phantom Units (“Phantom Units”), pursuant and subject to the terms and conditions of this Agreement and the USA Compression Partners, LP 2013 Long-Term Incentive Plan (the “Plan”), the terms and conditions of which are hereby incorporated into this Agreement by reference. Each Phantom Unit shall constitute a Phantom Unit under the terms of the Plan and is hereby granted in tandem with a corresponding distribution equivalent right (“DER”), as further detailed in Section 3 below. Except as otherwise expressly provided herein, all capitalized terms used in this Agreement, but not defined, shall have the meanings provided in the Plan. 

GRANT NOTICE

Subject to the terms and conditions of this Agreement, the principal features of this Award are as follows:

Number of Phantom Units: _____Phantom Units, comprised of _____ Standard Units and _____ Performance Units (each as defined below). The number of Performance Units set forth in this paragraph shall be referred to herein as the “Target Number.”

Grant Date: _____, 20__

Vesting of Phantom Units:  

(a) All Phantom Units granted hereunder other than Performance Units (“Standard Units”) shall vest in three essentially equal annual installments, with the first installment (____ Standard Units) vesting on ______, 20__ and the other two installments (____ Standard Units for 20__ and ____ Standard Units for 20__) vesting on the next two succeeding anniversaries thereof (with the second of such two succeeding anniversaries being termed the “Final Scheduled Vesting Date”), subject in each case to the Participant continuing in Service through the applicable vesting date;  provided that the Standard Units shall be subject to accelerated vesting in certain circumstances as set forth in Section 4(b) below.

(b) All remaining Phantom Units (the “Performance Units”) shall vest, subject to (d) below, on the earlier to occur of (i) immediately prior to a Change in Control or (ii) the Final Scheduled Vesting Date. 

(c) If vesting under (b) occurs as a result of a Change in Control, the Target Number of the Performance Units shall vest (subject, however, to the Committee’s discretion to vest a greater portion (up to ___% of the Target Number) of Performance Units based

on factors at the time of such event (such as, without limitation, time left until the Final Scheduled Vesting Date, the Partnership’s performance relative to similarly situated companies in the Partnership’s industry, etc.)), and any potential remaining Performance Units (i.e., those above the Target Number that were not vested in the Committee’s discretion) shall be forfeited.

(d) If vesting under (b) occurs as a result of the occurrence of the Final Scheduled Vesting Date, the Performance Units shall (subject to the Committee’s discretion to vest a greater portion (up to ____% of the Target Number) or lesser portion of Performance Units based on other relevant factors (such as, without limitation, the Partnership’s performance relative to similarly situated companies in the Partnership’s industry)) vest from ___%-____% of the Target Number, based on _______, with the number of Performance Units vesting to be determined in accordance with the provisions of  Appendix A hereto.

(e) The number of Performance Units deemed granted hereunder (for all purposes other than DERs) shall be up to _____ the number of Performance Units as the Target Number.

Forfeiture of Phantom Units: Subject to (b) above and Section 4(b) below, in the event of a cessation (not including any approved leave of absence) of the Participant’s Service for any reason, all Phantom Units that have not vested prior to or in connection with such cessation of Service shall thereupon automatically be forfeited by the Participant without further action and without payment of consideration therefor.

Payment of Phantom Units: Vested Phantom Units shall be paid to the Participant as set forth in Section 5 below.

DERs: Each Phantom Unit granted under this Agreement shall be issued in tandem with a corresponding DER, which shall entitle the Participant to receive payments in an amount equal to the Partnership distributions in accordance with Section 3 below.  For purposes of clarity, DERs that are granted with respect to Performance Units will be granted based upon the Target Number of Performance Units (with no adjustment upwards or downwards at vesting).  

TERMS AND CONDITIONS OF PHANTOM UNITS

1. Grant. The Company hereby grants to the Participant, as of the Grant Date, an award of Phantom Units in the amount set forth in the Grant Notice above, subject to all of the terms and conditions contained in this Agreement and the Plan.

2. Phantom Units. Subject to Section 4 below and (c) above (regarding Performance Units), each Phantom Unit that vests shall represent the right to receive payment, in accordance with Section 5 below, in the form of one (1) Unit. Unless and until a Phantom Unit vests, the Participant will have no right to payment in respect of such Phantom Unit. Prior to actual payment in respect of any vested Phantom Unit, such Phantom Unit will represent an unsecured obligation of the Partnership, payable (if at all) only from the general assets of the Partnership. 

3. Grant of Tandem DER. Each Phantom Unit granted hereunder is hereby granted in tandem with a corresponding DER, which shall remain outstanding from the Grant Date until

the earlier of the payment or forfeiture of the related Phantom Unit.  Each DER shall entitle the Participant to receive payments, subject to and in accordance with this Agreement, in an amount equal to any distributions made by the Partnership following the Grant Date and while the DER is outstanding in respect of the Unit underlying the Phantom Unit to which such DER relates. The Company shall make each such payment to the Participant in cash as soon as reasonably practicable, but not later than forty-five days after each such distribution is paid by the Partnership.

4. Vesting and Forfeiture.

(a) Vesting. Subject to Section 4(b) or 4(c) below, the Phantom Units shall vest in such amounts and at such times as are set forth in the Grant Notice above.

(b) Accelerated Vesting. Subject to Section 4(c) below, if a Change in Control occurs after the Grant Date and following such occurrence, the Participant incurs a termination of Service due to the Participant’s termination by the Company or one of its Affiliates without Cause or the Participant’s resignation for Good Reason, then 100% of the then-unvested Standard Units shall vest in full as of immediately prior to such termination.1Accelerated vesting of Performance Units is covered under (c) of the Grant Notice above.  For purposes of this Agreement, the following definitions shall apply:

(i) “Cause” shall have the meaning set forth in a written employment or other similar agreement between the Participant on one hand and the Partnership, the Company or any of their Affiliates on the other hand. In the event the Participant is not a party to a written agreement containing a definition of “Cause” or similar term, “Cause” (solely for purposes of this Agreement and not for the purpose of establishing any standard of termination for employment) shall mean a finding by the Committee, before or after the Participant’s termination of Service, of:  any material failure by the Participant to perform the Participant’s duties and responsibilities as an Employee;  any significant act of fraud, embezzlement, theft or misappropriation by the Participant relating to the Company, the Partnership or any of their Affiliates that is demonstrably and significantly injurious to the Partnership or any of its Affiliates;  the Participant’s conviction of a felony or a crime involving moral turpitude;  any gross negligence or intentional misconduct on the part of the Participant in the conduct of the Participant’s duties and responsibilities with the Company, the Partnership or any of their Affiliates that is demonstrably and significantly injurious to the Partnership or any of its Affiliates; or  any material breach by the Participant of any agreement between the Company, the Partnership or any of their Affiliates, on the one hand, and the Participant on the other; provided, that with respect to items (i), (iv) and (v), the Participant shall have not been able to remedy such deficiencies within 15 days of receiving written notice thereof from the Company (as long as any such types of deficiencies have not previously been noticed in writing to Participant in the immediately preceding six months). The findings and decision of the Committee with respect to such matter, including those regarding the acts of the Participant and the impact thereof, will be final for all purposes.

1.Accelerated vesting for the President and Chief Executive Officer will occur immediately prior to a Change in Control, with or without any such termination.

(ii) “Good Reason” shall have the meaning set forth in a written employment or other similar agreement between the Participant on one hand and the Partnership, the Company or any of their Affiliates on the other hand, provided that in no event shall any event or occurrence constitute Good Reason for purposes of this Agreement unless such event or occurrence constitutes a “material negative change” (within the meaning of Treasury Regulation 1.409A-1(n)(2)) to the Participant in his or her service relationship with the Company, the Partnership and its Affiliates. In the event the Participant is not a party to a written agreement containing a definition of “Good Reason” or similar term, “Good Reason” (solely for purposes of this Agreement and not for the purpose of establishing any standard of termination for employment) shall mean the occurrence of one or more of the following actions without the Participant’s consent:  a material reduction in the duties and responsibilities held by the Participant, except in connection with a termination of the Participant’s Service for Cause;  a material reduction in the Participant’s base salary, other than a reduction that is generally applicable to all similarly situated employees of the Company; or  a material change (i.e., more than 50 miles) in the geographic location at which the Participant must perform services for the Company, the Partnership or its Affiliates; provided, however, that no termination of Service by the Participant shall constitute a termination for Good Reason unless  the Participant has first provided the Company, the Partnership or its applicable Affiliate with written notice specifically identifying the acts or omissions constituting the grounds for Good Reason within thirty (30) days after the Participant has or should reasonably be expected to have had knowledge of the occurrence thereof,  the Company, the Partnership or its Affiliate, as applicable, has not cured such acts or omissions within thirty (30) days of its actual receipt of such notice, and  the effective date of the Participant’s termination for Good Reason occurs no later than ninety (90) days after the initial existence of the facts or circumstances constituting Good Reason.

(a) Forfeiture. Notwithstanding the foregoing, in the event of a cessation (not including any approved leave of absence) of the Participant’s Service for any reason, all Phantom Units that have not vested prior to or in connection with such cessation of Service shall thereupon automatically be forfeited by the Participant without further action and without payment of consideration therefor. No portion of the Phantom Units which has not become vested at the date of the Participant’s cessation (not including any approved leave of absence) of Service shall thereafter become vested.

(b) Payment. Vested Phantom Units shall be subject to the payment provisions set forth in Section 5 below.

5. Payment of Phantom Units and DERs.

(a) Phantom Units. Unpaid, vested Phantom Units shall be paid to the Participant in the form of Units in a lump sum as soon as reasonably practical, but not later than forty-five (45) days, following the date on which such Phantom Units vest. Payments of any Phantom Units that vest in accordance herewith shall be made to the Participant (or in the event of the Participant’s death, to the Participant’s estate) in whole Units in accordance with this Section 5. In lieu of the foregoing, the Committee may elect in its discretion to pay the Phantom

Units in cash equal to the Fair Market Value of the Units that would otherwise be distributed as of the date of vesting.

(b) DERs. DERs shall be paid to the Participant as provided above in Section 3.

(c) Potential Delay. Notwithstanding anything to the contrary in this Agreement, no amounts payable under this Agreement shall be paid to the Participant prior to the expiration of the six (6)-month period following his “separation from service” (within the meaning of Treasury Regulation Section 1.409A-1(h)) (a “Separation from Service”) to the extent that the Company determines that paying such amounts prior to the expiration of such six (6)-month period would result in a prohibited distribution under Section 409A(a)(2)(B)(i) of the Code. If the payment of any such amounts is delayed as a result of the previous sentence, then on the first business day following the end of the applicable six (6)-month period (or such earlier date upon which such amounts can be paid under Section 409A of the Code without resulting in a prohibited distribution, including as a result of the Participant’s death), such amounts shall be paid to the Participant.

6. Tax Withholding. The Company and/or its Affiliates shall have the authority and the right to deduct or withhold, or to require the Participant to remit to the Company and/or its Affiliates, an amount sufficient to satisfy all applicable federal, state and local taxes (including the Participant’s employment tax obligations) required by law to be withheld with respect to any taxable event arising in connection with the Phantom Units and the DERs. In satisfaction of the foregoing requirement the Company and/or its Affiliates shall withhold, solely at the election of the Participant,  Units otherwise issuable in respect of such Phantom Units having a Fair Market Value equal to the sums required to be withheld,  cash, or  a combination of cash and Units otherwise issuable in respect of such Phantom Units. In the event that Units that would otherwise be issued in payment of the Phantom Units are used to satisfy all or part of such withholding obligations, the number of Units which shall be so withheld shall be limited to the number of Units which have a Fair Market Value (which, in the case of a broker-assisted transaction (if a broker assisted transaction is permitted by the Participant), shall be determined by the Committee, consistent with applicable provisions of the Code) on the date of withholding equal to the aggregate amount of such liabilities based on the minimum statutory withholding rates for federal, state, local and foreign income tax and payroll tax purposes that are applicable to such supplemental taxable income, less any cash withheld.

7. Rights as Unit Holder. Neither the Participant nor any person claiming under or through the Participant shall have any of the rights or privileges of a holder of Units in respect of any Units that may become deliverable hereunder unless and until certificates representing such Units shall have been issued or recorded in book entry form on the records of the Partnership or its transfer agents or registrars, and delivered in certificate or book entry form to the Participant or any person claiming under or through the Participant.

8. Non-Transferability. Except as set forth in the next sentence, neither the Phantom Units nor any right of the Participant under the Phantom Units may be assigned, alienated, pledged, attached, sold or otherwise transferred or encumbered by the Participant (or any permitted transferee) other than by will or the laws of descent and distribution and any such

purported assignment, alienation, pledge, attachment, sale, transfer or encumbrance shall be void and unenforceable against the Company, the Partnership and any of their Affiliates. Notwithstanding the foregoing,  the Phantom Units or any right of the Participant under the Phantom Units may be transferred by a Participant without consideration to any “family member” of the Participant, as defined in the instructions to use of the Form S-8 Registration Statement under the Securities Act, as applicable, or any other transferee specifically approved by the Committee after taking into account any state, federal, local or foreign tax and securities laws applicable to transferable Awards; and  vested Units may be transferred to the extent permitted by the Partnership Agreement and not otherwise prohibited by this Agreement or any other agreement restricting the transfer of such Units.

9. Distribution of Units. Unless otherwise determined by the Committee or required by any applicable law, rule or regulation, neither the Company nor the Partnership shall deliver to the Participant certificates evidencing Units issued pursuant to this Agreement and instead such Units shall be recorded in the books of the Partnership (or, as applicable, its transfer agent or equity plan administrator). All certificates for Units issued pursuant to this Agreement and all Units issued pursuant to book entry procedures hereunder shall be subject to such stop transfer orders and other restrictions as the Company may deem advisable under the Plan or the rules, regulations, and other requirements of the Securities Exchange Commission, any stock exchange upon which such Units are then listed, and any applicable federal or state laws, and the Company may cause a legend or legends to be inscribed on any such certificates or book entry to make appropriate reference to such restrictions. In addition to the terms and conditions provided herein, the Company may require that the Participant make such covenants, agreements, and representations as the Company, in its sole discretion, deems advisable in order to comply with any such laws, regulations, or requirements. No fractional Units shall be issued or delivered pursuant to the Phantom Units and the Committee shall determine the amount of cash, other securities, or other property that shall be paid or transferred in lieu of fractional Units.

10. Partnership Agreement. Units issued upon payment of the Phantom Units shall be subject to the terms of the Plan and the Partnership Agreement. Upon the issuance of Units to the Participant, the Participant shall, automatically and without further action on his or her part,  be admitted to the Partnership as a Limited Partner (as defined in the Partnership Agreement) with respect to the Units, and  become bound, and be deemed to have agreed to be bound, by the terms of the Partnership Agreement.

11. No Effect on Service. Nothing in this Agreement or in the Plan shall be construed as giving the Participant the right to be retained in the employ or service of the Company or any Affiliate thereof or establish standards regarding the termination from employment of the Participant. Furthermore, the Company and its Affiliates may at any time dismiss the Participant from employment or consulting free from any liability or any claim under the Plan or this Agreement, unless otherwise expressly provided in the Plan, this Agreement or any other written agreement between the Participant and the Company or an Affiliate thereof.

12. Non-Solicitation of Customers and Employees.

(a) During the period beginning on the Grant Date and for a period of 12 months following the termination of the Participant’s Service (the “Restricted Period”) for any

reason, the Participant agrees to not, directly or indirectly, recruit or otherwise solicit or induce any employee, customer, subscriber or supplier of the Company to terminate its employment or arrangement with the Company, to engage in business with the Participant (or any future employer, affiliate or service recipient of the Participant) or to otherwise change its relationship with the Company, the Partnership or any of their Affiliates. Further, during the Restricted Period, the Participant agrees not to, directly or indirectly, hire or attempt to hire, or assist another person, firm, corporation, partnership or business in hiring or attempting to hire any employee (or former employee for six months after termination of employment) of the Company.

(b) It is recognized and acknowledged by the Participant that a breach of the covenants contained in this Section 12 will cause irreparable damage to the Company, the Partnership and their Affiliates and their goodwill, the exact amount of which will be difficult or impossible to ascertain, and that the remedies at law for any such breach will be inadequate. Accordingly, the Participant agrees that in the event of a breach of any of the covenants contained in this Section 12, in addition to any other remedy which may be available at law or in equity, the Company, the Partnership and their Affiliates will be entitled to specific performance and injunctive relief without having to prove damages. In the event any term of this Section 12 shall be determined by any court of competent jurisdiction to be unenforceable by reason of its extending for too great a period of time or over too great a geographical area or by reason of its being too extensive in any other respect, it will be interpreted to extend only over the maximum period of time for which it may be enforceable, over the maximum geographical area as to which it may be enforceable, or to the maximum extent in all other respects as to which it may be enforceable, all as determined by such court in such action.

13. Non-Disparagement. The Participant agrees to refrain from making any oral or written statements to a third party about the Company, the Partnership, or any of their Affiliates that are slanderous, libelous or defamatory with the effect of damaging the business or reputation of the Company, the Partnership, or any of their Affiliates. If the Participant violates the terms of this Section 13, the violation shall be deemed an Act of Misconduct under the Plan and the Phantom Units, DERs, and Units issuable hereunder, whether vested or unvested and whether or not previously issued, shall be subject to the clawback described in Section 8(o) of the Plan only to the extent that the violation resulted in actual demonstrable harm to the Company, the Partnership, or any of their Affiliates.

14. Severability. If any provision of this Agreement is or becomes or is deemed to be invalid, illegal, or unenforceable in any jurisdiction, such provision shall be construed or deemed amended to conform to the applicable law or, if it cannot be construed or deemed amended without, in the determination of the Committee, materially altering the intent of this Agreement, such provision shall be stricken as to such jurisdiction, and the remainder of this Agreement shall remain in full force and effect.

15. Tax Consultation. None of the Board, the Committee, the Company or the Partnership has made any warranty or representation to Participant with respect to the income tax consequences of the issuance of the Phantom Units, the DERs, the Units or the transactions contemplated by this Agreement, and the Participant represents that he or she is in no manner relying on such entities or their representatives for tax advice or an assessment of such tax consequences. The Participant understands that the Participant may suffer adverse tax

consequences in connection with the Phantom Units and DERs granted pursuant to this Agreement. The Participant represents that the Participant has consulted with any tax consultants that the Participant deems advisable in connection with the Phantom Units and DERs.

16. Amendments, Suspension and Termination. Solely to the extent permitted by the Plan, this Agreement may be wholly or partially amended or otherwise modified, suspended or terminated at any time or from time to time by the Board or the Committee. Except as provided in the preceding sentence, this Agreement cannot be modified, altered or amended, except by an agreement, in writing, signed by both the Partnership and the Participant.

17. Lock-Up Agreement. The Participant shall agree, if so requested of all executive management personnel by the Company or the Partnership and any underwriter in connection with any public offering of securities of the Partnership or any Affiliate thereof, not to directly or indirectly offer, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant for the sale of or otherwise dispose of or transfer any Units held by him or her for such period, not to exceed one hundred eighty (180) days following the effective date of the relevant registration statement filed under the Securities Act in connection with such public offering, as such underwriter shall specify reasonably and in good faith. The Company or the Partnership may impose stop-transfer instructions with respect to securities subject to the foregoing restrictions until the end of such 180-day period. Notwithstanding the foregoing, the 180-day period may be extended for up to such number of additional days as is deemed necessary by such underwriter or the Company or Partnership to continue coverage by research analysts in accordance with FINRA Rule 2711 or any successor rule.

18. Conformity to Securities Laws. The Participant acknowledges that the Plan and this Agreement are intended to conform to the extent necessary with all provisions of the Securities Act and the Exchange Act, any and all regulations and rules promulgated by the Securities and Exchange Commission thereunder, and all applicable state securities laws and regulations. Notwithstanding anything herein to the contrary, the Plan shall be administered, and the Phantom Units and DERs are granted, only in such a manner as to conform to such laws, rules and regulations. To the extent permitted by applicable law, the Plan and this Agreement shall be deemed amended to the extent necessary to conform to such laws, rules and regulations.

19. Code Section 409A. None of the Phantom Units, the DERs or any amounts paid pursuant to this Agreement are intended to constitute or provide for a deferral of compensation that is subject to Section 409A of the Code. Nevertheless, to the extent that the Committee determines that the Phantom Units or DERs may not be exempt from (or compliant with) Section 409A of the Code, the Committee may (but shall not be required to) amend this Agreement in a manner intended to comply with the requirements of Section 409A of the Code or an exemption therefrom (including amendments with retroactive effect), or take any other actions as it deems necessary or appropriate to  exempt the Phantom Units or DERs from Section 409A of the Code and/or preserve the intended tax treatment of the benefits provided with respect to the Phantom Units or DERs, or  comply with the requirements of Section 409A of the Code. To the extent applicable, this Agreement shall be interpreted in accordance with the provisions of Section 409A of the Code. Notwithstanding anything in this Agreement to the contrary, to the extent that any payment or benefit hereunder constitutes non-exempt “nonqualified deferred

compensation” for purposes of Section 409A of the Code, and such payment or benefit would otherwise be payable or distributable hereunder by reason of the Participant’s cessation of Service, all references to the Participant’s cessation of Service shall be construed to mean a Separation from Service, and the Participant shall not be considered to have a cessation of Service unless such cessation constitutes a Separation from Service with respect to the Participant.

20. Adjustments; Clawback. The Participant acknowledges that the Phantom Units are subject to modification and forfeiture in certain events as provided in this Agreement and Section 7 of the Plan. The Participant further acknowledges that the Phantom Units, DERs and Units issuable hereunder, whether vested or unvested and whether or not previously issued, are subject to clawback as provided in Section 8(o) of the Plan.

21. Successors and Assigns. This Agreement shall inure to the benefit of the successors and assigns of the Company and the Partnership. Subject to the restrictions on transfer contained herein, this Agreement shall be binding upon the Participant and his or her heirs, executors, administrators, successors and assigns.

22. Governing Law. The validity, construction, and effect of this Agreement and any rules and regulations relating to this Agreement shall be determined in accordance with the laws of the State of Delaware without regard to its conflicts of laws principles.

23. Headings. Headings are given to the sections and subsections of this Agreement solely as a convenience to facilitate reference. Such headings shall not be deemed in any way material or relevant to the construction or interpretation of this Agreement or any provision hereof.

24. Forfeiture. The Award granted under this Agreement shall automatically be deemed forfeited by the Participant on ______, 20__ unless prior to such date the Participant shall have executed and delivered to the Partnership this Agreement and  an NDA and Assignment in favor of the Partnership (except that (ii) is not required for Participants who already have entered into  a written employment agreement with the Partnership, one of its subsidiaries or USA Compression Management Services, LLC or  a Nondisclosure and Assignment of Inventions Agreement in form satisfactory to the Partnership (a “Form NDA and Assignment”)).

[Signature page follows]

The Participant’s signature below indicates the Participant’s agreement with and understanding that this award is subject to all of the terms and conditions contained in the Plan and in this Agreement, and that, in the event that there are any inconsistencies between the terms of the Plan and the terms of this Agreement, the terms of this Agreement shall control. The Participant further acknowledges that the Participant has read and understands the Plan and this Agreement, which contains the specific terms and conditions of this grant of Phantom Units. The Participant hereby agrees to accept as binding, conclusive and final all decisions or interpretations of the Committee upon any questions arising under the Plan or this Agreement.

USA Compression Partners, LP

a Delaware limited partnership

By:USA Compression GP, LLC

Its:General Partner

By:_______________________________________________

Name: Eric D. Long

Title: President and CEO

“PARTICIPANT”

[                    ]

Appendix A

EX-10.7

Exhibit 10.7

EMPLOYMENT AGREEMENT

This Employment Agreement (“Agreement”) is made and entered into as of July 15, 2013 (the “Effective Date”) by and between USACompression Management Services, LLC, a Delaware limited liability company (hereafter the “Company”), and William G. Manias (“Employee”).

WHEREAS, Employee and the Company desire to enter into this Agreement as set forth herein.

NOW, THEREFORE, in consideration of the foregoing and the mutual covenants contained herein, Employee and the Company, intending to be legally bound, do hereby agree as follows:

1. Employment.During the Employment Period (as defined in Section4 below), the Company shall employ Employee, and Employee shall serve, as Vice President and Chief Operating Officer of the Company.

2. Duties and Responsibilities of Employee.

(a) During the Employment Period, Employee shall:(i) devote all of Employee’s business time and attention to the business of the Company and its Affiliates (as defined below) (collectively, the “Company Group”, which term shall include, for the avoidance of doubt, any subsidiaries or other entities that become Affiliates of the Company from and after the date hereof), as applicable, (ii)will act in the best interests of the Company Group and (iii)will perform with due care Employee’s duties and responsibilities.Employee’s duties will include those normally incidental to the position of Chief Operating Officer, as well as whatever additional duties may be assigned to Employee by the Chief Executive Officer or the board of directors of USACompression GP, LLC (the “Board”), which duties may include, without limitation, providing services to members of the Company Group in addition to the Company.Employee agrees to cooperate fully with the Board and not to engage in any activity that interferes with the performance of Employee’s duties hereunder.During the Employment Period, Employee will not hold any type of outside employment, engage in any type of consulting or otherwise render services to or for any other person or business concern without the advance written consent of the Board; provided, that the foregoing shall not preclude Employee from managing private investments, participating in industry and/or trade groups, engaging in volunteer civic, charitable or religious activities, serving on boards of directors of charitable not‑for‑profit entities or, with the consent of the Board, which consent is not to be unreasonably withheld, serving on the board of directors of other entities, in each case as long as such activities, individually or in the

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aggregate, do not materially interfere or conflict with Employee’s responsibilities to the Company.

(b) Employee represents and covenants that Employee is not the subject of or a party to any employment agreement, non‑competition covenant, nondisclosure agreement, or any other agreement, covenant, understanding, or restriction that would prohibit Employee from executing this Agreement or the Amended and Restated Limited Liability Company Agreement of USACompression Holdings, LLC, dated as of December23, 2010 (as amended, the “Operating Agreement”) and fully performing Employee’s duties and responsibilities hereunder or thereunder, or would in any manner, directly or indirectly, limit or affect the duties and responsibilities that may now or in the future be assigned to Employee hereunder.

(c) Employee acknowledges and agrees that Employee owes the Company Group a duty of loyalty as a fiduciary of the Company Group, and that the obligations described in this Agreement are in addition to, and not in lieu of, the obligations Employee owes the Company Group under the common law.

3. Compensation.

(a) During the Employment Period, the Company shall pay to Employee an annualized base salary of $275,000 (the “Base Salary”) in consideration for Employee’s services under this Agreement, payable on a bi‑weekly basis, in conformity with the Company’s customer payroll practices for similarly situated employees.The Board will annually review the Base Salary, which may be increased but not decreased during the Employment Period based on Employee’s performance and market conditions.

(b) During the Employment Period, Employee shall be entitled to participate in the bonus programs established for employees of the Company, as may be amended from time to time.The performance targets that must be achieved in order to be eligible for certain bonus levels shall be established by the Board each year within 90days following the start of the applicable fiscal year, in its sole discretion, and communicated to Employee.If the Board determines that Employee meets the performance targets established for a particular fiscal year, then his bonus for that year (the “Annual Bonus”) will be in an amount up to $137,500 (the “Target Annual Bonus”), in accordancewith the terms of the bonus program in effect for the applicable year, which amount shall be prorated for less than a full year of service for the fiscal year ending December31, 2013.In addition, in the event Employee outperforms and exceeds the performance targets established for a particular fiscal year, Employee may receive an additionaloutperformance bonus for the applicable year, in an amount determined in the sole discretion of the Board (an “Outperformance

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Bonus”).The Annual Bonus and any Outperformance Bonus shall be paid no later than March15 of the year following the year in which the AnnualBonus or Outperformance Bonus is earned, and shallnotbepayable unless Employee remains employed by the Company on the date that such bonus is paid, except in the case of a termination of Employee due to the death or Disability of Employee, by the Company for convenience, or a resignation by Employee for Good Reason, in which case Employee will be entitled to (i)theentireamount of any earned Annual Bonus for the year preceding the year in which Employee dies, becomesDisabled, is terminated by theCompany for convenience or resigns for Good Reason and (ii)a pro rata portion (based on the number of days employedduring the year) of any earned Annual Bonus for the year in which Employee dies, becomes Disabled, is terminated by the Company for convenienceor resigns for Good Reason in each case in the year following the year to which the applicable bonus relates.

4. Term of Employment.The initial term of this Agreement shall be for the period beginning on the Effective Date and ending on the second anniversary of the Effective Date (the “InitialTerm”). OnthesecondanniversaryoftheEffectiveDateandoneachsubsequent anniversarythereafter,thisAgreementshallautomaticallyrenewandextendfor aperiodof 12months(eachsuch12‑monthperiodbeinga “RenewalTerm”) unless written notice of non‑renewal is delivered from either party to the other not less than 90days prior to the expiration of the then‑existing Initial Term or Renewal Term.Notwithstanding any other provision of this Agreement, Employee’s employment pursuant to this Agreement may be terminatedat any time in accordancewith Section6. The period fromthe EffectiveDate throughtheexpirationofthisAgreementor,if sooner,theterminationofEmployee’s employmentpursuant to this Agreement,regardless of the time or reason for such termination, shall be referred to herein as the “Employment Period.”

5. Benefits. Subject to the terms and conditions of this Agreement, Employee shall be entitled to the following benefits during the Employment Period:

(a) ReimbursementofBusinessExpenses.SubjecttoSection24hereof (regarding section409A compliance), the Company agrees to reimburse Employeefor Employee’s reasonablebusiness‑relatedexpensesincurred in the performanceof Employee’s duties under this Agreement; provided, that Employee timely submitsall documentationfor such reimbursement, as requiredby Company policy in effect from time‑to‑time.Employeeis not permittedto receive a paymentin lieuof reimbursementunder this Section5(a).

(b) Benefits.During the Employment Period, Employee and where applicable Employee’s spouse and dependentsshall be eligibleto participatein the samebenefit plansorfringebenefit policies, other thanseverance programs, such as health, dental, life insurance, vision, and 401(k), as are offered to members of the Company’s executive management and in each case on no less favorable than the terms of benefits generally available to

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theemployeesoftheCompany(basedonseniorityandsalarylevel), subject to applicable eligibilityrequirementsand the terms and conditions of all plans and policies.

(c) Paid Time Off.During the Employment Period, Employee shall accrue paid time off (“Paid Time Off”) at a rate of 20days per calendar year during the Employment Period; provided,  however, that Employee shall cease accruing Paid Time Off once Employee has accrued 20 unused days’ worth of Paid Time Off, and such accrual will begin again only after Employee has used accrued Paid Time Off such that Employee’s accrued entitlement to Paid Time Off is once again less than 20days.Employee shall take Paid Time Off in accordance with all Company policies and with due regard for the needs of the Company Group.

6. Termination of Employment.

(a) Company’s Right to Terminate Employee’s Employment for Cause.The Company shall have the right to terminate Employee’s employment hereunder at any time for “Cause.” For purposes of this Agreement, “Cause” shall mean:

(i) any material breach of this Agreement or the Operating Agreement by Employee, including, without limitation, the material breach of any representation, warranty or covenant made under this Agreement or the Operating Agreement by Employee;

(ii) Employee’sbreach ofanyapplicabledutiesofloyaltytothe Company or any of its Affiliates, gross negligence or material misconduct, or a significant act or acts of personal dishonesty or deceit, taken by Employee, in the performance of duties and services requiredofEmployeethat isdemonstrablyand significantly injurious to the Company or any of its Affiliates;

(iii) conviction of Employee of a felony or crime involving moral turpitude;

(iv) Employee’s willful and continued failure or refusal to perform substantially Employee’s material obligations pursuant to this Agreement or the Operating Agreement or follow any lawful and reasonabledirectivefromtheChiefExecutiveOfficerorthe Board, other than as a result of Employee’s incapacity; or

(v) a violation of a federal, state or local law or regulation applicable to the business of the Company that is demonstrably and significantly injurious to the Company.

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PriortoEmployee’sterminationforCause,theCompanymustgive written notice to Employee describing the act or omission of Employee giving rise to the determination of Cause and, in respect of circumstances capable of cure, such circumstances must remain uncured for 15days following receipt by Employee of such written notice, provided, thatEmployee shall not be entitled to cure any such acts or omissions if Employee has previously cured any acts or omissions in the immediately preceding six months.

(b) Company’s Right to Terminate for Convenience.The Company shall have the right to terminate Employee’s employment for convenience at any time and for any reason, or no reason at all, with written notice to Employee, subject to the provisions of Section6(g) regarding the severance benefits. For purposes of this Agreement, the Company’s failure to renew the Agreement at the end of Initial Term or a Renewal Term shall be deemed a termination of Employee’s employment for convenience.

(c) Employee’s Right to Terminate for Good Reason.Employee shall have the right to terminate Employee’s employment with the Company at any timefor“GoodReason.” ForpurposesofthisAgreement, “Good Reason” shall mean:

(i) a material breach by the Company of any of its covenants or obligations under this Agreement, the Operating Agreement or any other material agreement with Employee;

(ii) any material reduction in Employee’s Base Salary, other than a reduction that is generally applicable to all similarly situated employees of the Company;

(iii) amaterialreductionbytheCompanyinEmployee’sduties, authority, responsibilities, job title or reporting relationships as in effect immediately prior to such reduction, or the assignment to Employee of such reduced duties, authority, responsibilities, job title or reporting relationships;

(iv) a material reduction of the facilities and perquisites available to Employee immediately prior to such reduction, other than a reduction that is generally applicable to all similarly situated employees of the Company; or

(v) the relocation of the geographic location of Employee’sprincipal place ofemploymentbymorethan50milesfrom

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the location of Employee’sprincipal place of employment as of the Effective Date.

Notwithstanding the foregoing provisions of this Section6(c) or any other provision of this Agreement to the contrary, any assertion of Employee of a termination for Good Reason shall not be effective unless all of the following conditions are satisfied: (A)the condition giving rise to Employee’sterminationofemploymentmust havearisenwithoutEmployee’swritten consent; (B)Employee must provide written notice to the Board of such condition within 30days of the initial existence of the condition; (C)the condition specified in such notice must remain uncorrected for 30days after receipt of such notice by the Board; and (D)the date of Employee’sterminationof employmentmust occur within the 90‑day period after the initial existence of the condition specifiedin such notice, in which case, if Good Reason is found to exist and Employee otherwise complies with Section6(g), Employee will be entitled to receive the severance benefits provided in Section6(g).

(d) Death or Disability.Upon the death or Disability (as defined below) of Employee,Employee’semploymentwith Companyshallterminateand the Company shall have no further obligation to Employee, or Employee’s successor(s)in interest; provided, that the Company shall pay to Employee or the estate of Employee the amounts set forth in Section6(h), plus any Annual Bonus or Outperformance Bonus provided for in Section3(b).For purposesofthisAgreement,“Disability”shallmeanthatEmployeeis unable to perform the essential functions of Employee’s position, with reasonable accommodation,due to an illness or physical or mental impairment or other incapacitywhich continues for a period in excess of 20consecutiveweeks. The determinationof Disabilitywill be madebyaphysicianselectedbyEmployeeandacceptabletothe Company or its insurers, with such agreement to the acceptability not to be unreasonably withheld.

(e) Employee’s Right to Terminate for Convenience.Employee shall have the right to terminate Employee’s employment with the Company for convenience at any time and for any reason, or no reason at all, upon 30days’ advance written notice to the Company.

(f) Termination upon Non‑Renewal of the Agreement.Except as otherwise mutually agreed between the Company and Employee, if the Company or Employee provides the other party with a written notice of non‑renewal of thisAgreementin accordancewithSection4, Employee’semployment with Companyshallautomaticallyterminateuponthe expirationofthe then-applicable Initial Term or Renewal Term, as applicable.

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(g) Effect of Termination for Convenience or Good Reason Resignation. If Employee incurs a Separation from Service (as defined below) due to Employee’s employment terminating pursuant to Sections6(b) or 6(c) (regarding termination for convenience and resignation for Good Reason) above and Employee:(x)executeswithin 45days following the date of Employee’sSeparationfrom Service,and does not revoke, a releaseof all claims in a formsatisfactoryto the Company,which such form will be promptly provided by Company to Employee on or before his Separationfrom Service substantiallyin the form of release containedat ExhibitA(the“Release”);and(y)abidesbyEmployee’scontinuingobligationshereunder,including,withoutlimitation, theprovisions of Sections8 and 9 hereof (regarding confidentiality and non‑competition), thenEmployeeshallbeentitledtothefollowing,inadditiontothe amounts described in Section6(h), and any Annual Bonus or Outperformance Bonus provided for in Section3(b):

(i) Severance Pay.The Company shall make severance payments to Employee in an aggregate amount equal to one times Employee’s Base Salary as in effect as of the date of Employee’s termination of employment (or Base Salary for any preceding year in the Employment Period, if greater) (the “SeverancePayment”). If payable, the Severance Payment will be made, as applicable, in equalsemi‑monthly installments overtheone‑yearperiod following the date of Employee’s Separation from Service (the “SeverancePeriod’), in accordance with the Company’sregular payroll practices, provided, that any such installment payments that wouldotherwisebepaidpriortotheCompany’sfirstregular payrolldatethatoccursonorafterthe60thday following the date ofEmployee’sSeparation from Service (the “FirstPay Date”)shall be paid on the First Pay Date. Notwithstanding the foregoing, in the event of Employee’s death during the Severance Period, all remaining Severance Payments due him shall be paid in a lump sum within 30days of Employee’s death.Likewise, notwithstanding the other provisions ofthis Section6(g)(i),intheeventofaterminationfor convenienceby theCompany orterminationbyEmployee for Good Reason within two years following the occurrence of a “change in control event” within the meaning of Treasury Regulation Section1.409A‑3(i)(5), the Severance Payment shall be paidinalumpsumon the Company’s first regular payroll date that occurs on or after30daysofthedateof Employee’s Separation from Service.

(ii) Continued Health Insurance Benefits.For a period of 24monthsfollowingEmployee’sSeparationfromService

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(which period of 24months shall include and run concurrently with any so‑called COBRA continuation period applicabletoEmployeeand/orhiseligibledependentsunder Section4980BoftheCode, andmaybe subject toEmployee and/or his eligibledependentselecting suchcontinuation coverage), provided,  however, that (A)during the first 12months of such coverage, the Company shall continue to provide health insurance benefits to Employee and any eligible dependents at the Company’sexpense (other than Employee’smonthly cost‑sharing contribution under the Company’s group health plan, as in effect on the date of Employee’s Separation from Service), and (B)during the remaining 12months of such coverage, the Company shall continue to provide health insurance benefits toEmployee and any eligible dependents at Employee’s expense. Notwithstanding the previous sentence, if the Company determines in its sole discretion that it cannot provide the foregoing benefit without potentially violating applicable law (including, without limitation, Section2716 of the Public Health Service Act and any applicablenon‑discriminationrequirementthereunderor otherwise), the Company shall in lieu thereof provide to Employee a taxable monthly payment in an amount equal to the monthly COBRA premium that Employee would be required to pay to continue his and his covered dependents’ group health coverage in effect on the Date of Termination for the 12month period following the date of Employee’s Separation from Service (which amount shall be based on the premium for the first month of COBRA coverage), less the amount of Employee’s monthly cost‑sharing contribution under the Company’s group health plan, as in effect on the date of Employee’s Separation from Service at employee rates in effect thereunder as of the Separation from Service.

(h) Effectof Termination.Subject to Section24 hereof (regarding section409A compliance), upon the termination of Employee’s employment for any reason, all earned, unpaid Base Salary and all accrued, unused Paid Time Off shall be paid to Employee within 30days of the date of Employee’stermination ofemployment, orearlier ifrequired by law. With the exception of any payments to which Employee may be entitled pursuant to Section5(a)(regarding business expenses) and Section6(g) (regarding severance benefits), the Company shall have no further obligation under this Agreement to make any payments to Employee.

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7. Conflicts of Interest. Employee agrees that Employee shall promptly disclose to the Board any conflict of interest involving Employee upon Employee becoming aware of such conflict.

8. Confidentiality. Employeeacknowledgesandagreesthat,inthecourseof Employee’s employment with the Company and the performance of Employee’s duties on behalf of the Company Group hereunder, Employee will be provided with, and have access to, valuable Confidential Information (as defined below) of the Company Group and exchange for other valuable consideration provided hereunder, Employee agrees to comply with this Section8 and Section9.

(a) Employee covenants and agrees, both during the term of the Employment Periodandthereafterthat, except asexpresslypermittedbythis Agreement or by directive of the Board, Employee shall not disclose any Confidential Information to any person or entity and shall not use any Confidential, Information except for the benefit of the Company Group. Employee shall take all reasonable precautions to protect the physical securityofalldocumentsandothermaterialcontainingConfidentialInformation (regardless of the medium on which the Confidential Information is stored). This covenant shall apply to all Confidential Information, whether now known or later to become known to Employee during the Employment Period.

(b) NotwithstandingSection 5(a),Employeemaymakethefollowing disclosures and uses of Confidential Information:

(i) disclosurestootheremployeesof theCompanyGroupin connectionwiththe faithfulperformanceofdutiesforthe Company Group;

(ii) disclosures to customers and suppliers when, in the reasonable and good faith belief of Employee, such disclosure is in connection with Employee’sperformance of services under this Agreement and is in the best interests of the Company Group;

(iii) disclosures and uses that are approved by the Board;

(iv) disclosures to a person or entity that has been retained by the Company Group to provide services to the Company Group, and has agreed in writing to abide by the terms of a confidentiality agreement;

(v) disclosures for the purpose of complying with any applicable laws or regulatory requirements;

(vi) disclosures to Employee’slegal, tax or financial advisors for the purposeof assistingsuchadvisorsinproviding

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advice to Employee, provided, however, that such advisors agree to maintain the confidentiality of such disclosures; or

(vii) disclosuresthatEmployeeislegallycompelledtomakeby deposition, interrogatory, request for documents, subpoena, civil investigative demand, order of a court of competent jurisdiction, or similar process, or otherwise by law; provided,  however, that, prior to any such disclosure, Employee shall, to the extent legally permissible:

(A) provide the Board with prompt notice of such requirements so that the Board may seek a protective order or other appropriate remedy or waive compliance with the terms of this Section;

(B) consult with the Board on the advisability of taking steps to resist or narrow such disclosure; and

(C) cooperatewiththeBoard(attheCompany’scostand expense) in any attempt the Board may make to obtain a protective order or other appropriate remedy or assurance that confidential treatment will be afforded the Confidential Information; and in the event such protective order or other remedy is not obtained, Employee agrees (y)to furnish only that portion of the Confidential Information that is legally required to be furnished, as advised by counsel to Employee,and(z)toexercise (at the Company’s reasonablecostandexpense)allreasonableeffortsto obtainassurance that confidentialtreatmentwill be accorded such Confidential Information.

(c) Upon the expiration of the Employment Period and at any other time upon request of the Company, Employee shall surrender and deliver to the Company all documents (including, without limitation, electronically stored information) and other material of any nature containing or pertaining to all Confidential Information in Employee’s possession and shall not retain any such document or other material.Within 10days of any such request, Employee shall certify to the Company in writing that all such materials have been returned to the Company.

(d) Allnon‑publicinformation,designs,ideas,concepts,improvements, product developments, discoveries and inventions, whether patentable or not, that are conceived, made, developed or acquired by Employee, individually or in conjunction with others, during the Employment Period (whetherduringbusinesshours orotherwiseandwhetheron the

10

Company’s premises or otherwise) that relate to the Company Group’s businessesor properties, productsorservices(including,without limitation,allsuchinformationrelatingtocorporateopportunities, business plans, strategies for developing business and market share, research, financial and sales data, pricing terms, evaluations, opinions, interpretations, acquisition prospects, the identity of customers or their requirements, the identity of key contacts within customers’ organizations or within the organization of acquisition prospects, or marketing and merchandising techniques, prospective names and marks) is defined as “ConfidentialInformation.”Moreover,alldocuments,videotapes, written presentations, brochures, drawings, memoranda, notes, records, files,correspondence,manuals,models,specifications,computer programs, e‑mail, voice mail, electronic databases, maps, drawings, architectural renditions, models and all other writings or materials of any type including or embodying any of such information, ideas, concepts, improvements,discoveries,inventionsand other similarformsof expressionareandshallbethesoleandexclusivepropertyofthe Company Group and be subject to the same restrictions on disclosure applicable to all Confidential Information pursuant to this Agreement.

9. Non‑Competition.

(a) TheCompanyshallprovideEmployeeaccesstotheConfidential Information for use only during the Employment Period, and Employee acknowledges and agrees that the Company Group will be entrusting Employee, in Employee’sunique and special capacity, with developing the goodwill of the Company Group, and in consideration thereof and in consideration of the access to Confidential Information, has voluntarily agreed to the covenants set forth in this Section.Employee further agrees and acknowledges that the limitations and restrictions set forth herein, including, but not limited to, geographical and temporal restrictions on certain competitive activities, are reasonable and not oppressive and are material and substantial parts of this Agreement intended and necessary to prevent unfair competition and to protect the Company Group’s Confidential Information and substantial and legitimate business interests and goodwill.

(b) During the Employment Period and for a period of two years (the “RestrictedPeriod”) following the termination of the Employment Period forany reason, Employee shallnot, forwhateverreason and withor without cause, either individually or in partnership or jointly or in conjunctionwithanyotherPersonorPersonsasprincipal,agent, employee, shareholder (other than holding equity interests listed on a United States stock exchange or automated quotation system that do not exceed 5% of the outstanding shares so listed), owner, investor, partner or in any other manner whatsoever, directly or indirectly, engage in or compete with the Business anywhere in the world.

11

(c) During the Restricted Period, Employee shall not (i)knowingly induce or attempt to induce any other Person known to Employee to be a customer of the Company or its affiliates (each, a “Customer”) to cease doing any business with the Company or its affiliates anywhere in the world or (ii)solicit business involving the Business from, or provide services related to the Business to, any Customer.

(d) During the Restricted Period, Employee shall not solicit the employment of any individual who is an employee of the Company or its affiliates, except that Employee shall not be precluded from soliciting the employment of, or hiring, any such individual (i)whose employment with the Company or one of its affiliates has been terminated before entering into employmentdiscussionswithsuchSeller, (ii)whoinitiates discussions with Employee regarding employment opportunities with Employee or (iii)responds to a general advertisement or other similarly broad form of solicitation for employees.

(e) ForpurposesofthisSection9,thefollowingtermsshallhavethe following meanings:

(i) “Business”shall mean the business of providing natural gas compression services through the deployment and maintenance of on‑sitecompressor packages and any otherline ofbusinessin which the Company Group is engaged at the time of termination or has taken substantial steps to enter during the Employment Period and is actively pursuing at the time of termination.

(ii) “Person”means any individual, corporation, partnership, limited liability company, association, trust, incorporated organization, otherentityorgroup(asdefinedinSection13(d)(3)ofthe Securities Exchange Act of 1934, as amended).

(f) Because of the difficulty of measuring economic losses to the Company Group as a result of a breach of the foregoing covenants, and because of theimmediateandirreparabledamagethatcouldbecausedtothe Company Group for which it would have no other adequate remedy, Employee agrees that the foregoing covenant may be enforced by the Company, in the event of breach by Employee, by injunctions and restraining orders and that such enforcement shall not be the Company’s exclusive remedy for a breach but instead shall be in addition to all other rights and remedies available to the Company.

(g) The covenants in this Section9 are severable and separate, and the unenforceability of any specific covenant shall not affect the provisions of any other covenant. Moreover, in the event any arbitrator or court of

12

competent jurisdiction shall determine that the scope, time or territorial . restrictions set forth are unreasonable, then it is the intention of the parties that such restrictions be enforced to the fullest extent which the panel or court deems reasonable, and this Agreement shall thereby be reformed.

(h) All of the covenants in this Section9 shall be construed as an agreement independent of any other provision in this Agreement; and the existence of any claim or cause of action of Employee against the Company, whether predicated on this Agreement or otherwise, shall not constitute a defense to the enforcement by the Company of such covenants.

10. Ownership of IntellectualProperty. Employee agrees that the Company shall own, and Employee agrees to assign and does hereby assign, all right, title and interest (including, but not limited, to patent rights, copyrights, trade secret rights, mask work rights, trademark rights, and all other intellectual and industrial property rights of any sort throughout the world) relating to any and all inventions (whether or not patentable), works of authorship, mask works, designs, ideas and information authored, created, contributed to, made or conceived or reduced to practice, inwhole or in part, by Employee during theEmployment Period which either (a)relate, at the time of conception, reduction to practice, creation, derivation or development, to the Company Group’sbusinesses or actual or anticipated research or development, or (b)were developed on any amount of the Company’s time or with the use of any of the Company Group’s equipment, supplies, facilitiesortradesecretinformation(alloftheforegoing collectivelyreferred to herein as “Company Intellectual Property”); and Employee will promptly disclose all Company Intellectual Property to the Company. All of Employee’sworks of authorship and associated copyrights created during the Employment Period and in the scope of Employee’s employment shall be deemed to be “works made for hire” within the meaning of the Copyright Act.Employee agrees to perform, during and after the Employment Period, all reasonable acts deemed necessary by the Company Group to assist the Company, at the Company’s expense, in obtaining and enforcing its rights throughout the world in the Company Intellectual Property. Such acts may include, but are not limited to, execution of documents and assistance or cooperation (a)in the filing, prosecution, registration, and memorialization of assignment of any applicable patents, copyrights, mask work, or other applications, (b)in the enforcement of any applicable patents, copyrights, mask work, moral rights, trade secrets, or other proprietary rights, and (c)in other legal proceedings related to the Company Intellectual Property.

11. Arbitration.

(a) Subject to Section11(b), any dispute, controversy or claim between Employee and the Company arising out of or relating to this Agreement or Employee’s employment with the Company will be finally settled by arbitration in Austin, Texas before, and in accordance with the rules for the resolution of employment disputes then in effect of, the American Arbitration Association (“AAA”).The arbitration award shall be final and binding on both parties.

13

(b) Any arbitration conducted under this Section11 shall be heard by a single arbitrator(the“Arbitrator”)selectedinaccordancewiththethen applicable rules of the AAA.The Arbitrator shall expeditiously (and, if possible, within 90days after the selection of the Arbitrator) hear and decide all matters concerning the dispute.Except as expressly provided to the contrary in this Agreement, the Arbitrator shall have the power to (i)gather such materials, information, testimony and evidence as he or she deems relevant tothe disputebefore him orher (and eachparty will provide such materials, information, testimony and evidence requested by the Arbitrator, except to the extent any information so requested is subject to an attorney‑client or other privilege and, if the information so requested is proprietary or subject to a third party confidentiality restriction, the arbitrator shall enter an order providing that such material will be subject to a confidentiality agreement), and (ii)grant injunctive relief and enforce specific performance.The decision of the Arbitrator shall be rendered in writing, be final, non‑appealable and binding upon the disputing parties and the parties agree that judgment upon the award may be entered by any court of competent jurisdiction; provided, that the parties agree that the Arbitrator and any court enforcing the award of the Arbitrator shall not have the right or authority to award punitive or exemplary damages to any disputing party.

(c) Each side shall share equally the cost of the arbitration and bear its own costsandattorneys’feesincurredinconnectionwithanyarbitration,unlesstheArbitratordeterminesthatcompellingreasonsexistfor allocating all or a portion of such costs and fees to the other side.

(d) Notwithstanding Section11(a), an application for emergency or temporary injunctive relief by either party shall not be subject to arbitration under this Section; provided,  however, that the remainder of any such dispute (beyond the application foremergency ortemporary injunctive relief) shall be subject to arbitration under this Section.

(e) ByenteringintothisAgreementandenteringintothearbitration provisions of this Section11, THE PARTIESEXPRESSLY ACKNOWLEDGEANDAGREETHATTHEYAREKNOWINGLY, VOLUNTARILY AND INTENTIONALLY WAIVING THEIRRIGHTS TO A JURY TRIAL.

(f) Nothing in this Section11 shall prohibit a party to this Agreement from (i)institutinglitigationtoenforceanyarbitrationaward,or(ii)joining another party to this Agreement in a litigation initiated by a person or entity which is not a party to this Agreement.

12. Defense of Claims.Employee agrees that, during the Employment Period and thereafter, uponrequestfromthe Company, Employeewillreasonably cooperatewiththeCompany Group in the defense of any claims or actions that may be made by or against the

14

Company Group that relate to Employee’s actual or prior areas of responsibility, except if Employee’s reasonable interests are adverse to the Company or its Affiliate(s), as applicable, in such claim or action.The Company agrees to pay or reimburse Employee for all of Employee’s reasonable travel and other direct expenses incurred, or to be reasonably incurred, to comply with Employee’s obligations under this Section, provided, Employee provides reasonable documentation of same and obtains the Company’s prior approval for incurring such expenses. After the expiration of one year following the date of Employee’s Separation from Service, the Company will compensate Employee for the time Employee spends on reasonable cooperation and assistance at the Company’s request at a rate per hour calculated, by dividing his annualized Base Salary at the end of the Employment Period by 2,080.

13. Withholdings;Deductions. The Company may withhold and deduct from any payments made or to be made pursuant to this Agreement (a)all federal, state, local and other taxes or other amounts as may be required pursuant to any law or governmental regulation or ruling and (b)any deductions consented to in writing by Employee.

14. Title and Headings; Construction.Titles and headings to Sections hereof are for the purpose of reference only and shall in no way limit, define or otherwise affect the provisions hereof.Any andallExhibits orAttachments referredtointhisAgreementare,bysuch reference, incorporated herein and made a part hereof for all purposes. The words “herein”, “hereof, “hereunder”andothercompoundsoftheword“here”shallrefertotheentire Agreement and not to any particular provision hereof.

15. ApplicableLaw;SubmissiontoJurisdiction.ThisAgreementshallinall respects be construed according to the laws of the State of Texas.With respect to any claim or dispute related to or arising under this Agreement, the parties hereby consent to the arbitration provisions of Section11 above and recognize and agree that should any resort to a court be necessary and permitted under this Agreement, then they consent to the exclusive jurisdiction, forum and venue of the state and federal courts located in Austin, Texas.

16. Entire Agreement and Amendment. This Agreement,-including the Operating Agreement,thetermsofwhichareincorporatedhereinbyreference,contains theentire agreement of the parties with respect to the matters covered herein; moreover, this Agreement supersedes all prior and contemporaneous agreements and understandings, oral or written, between the parties hereto concerning the subject matter hereof; provided,  however, that, notwithstanding anything to the contrary in the Operating Agreement, the definitions of “Cause” and “Good Reason” in this Agreement shall apply in lieu of those same defined terms in the Operating Agreement when and to the extent those defined terms are applicable to Employee under the Operating Agreement.This Agreement may be amended only by a written instrument executed by both parties hereto.

17. Waiver of Breach.Any waiver of this Agreement must be executed by the party to be bound by such waiver.No waiver by either party hereto of a breach of any provision of this Agreement by the other party, or of compliance with any condition or provision of this Agreement to be performed by such other party, will operate or be construed as a waiver of any subsequent breach by such other party or any similar or dissimilar provision or condition at the same or any subsequent time.The failure of either party hereto to take any action by reason of

15

any breach will not deprive such party of the right to take action at any time while such breach continues.

18. Assignment.ThisAgreementispersonaltoEmployee,andneitherthis Agreement nor any rights or obligations hereunder shall be assignable or otherwise transferred by Employee.The Company may assign this Agreement to any member of the Company Group and to any successor (whether by merger, purchase or otherwise) to all or substantially all of the equity, assets or businesses of the Company, if such successor expressly agrees to assume the obligations of the Company hereunder.

19. Affiliates.For purposes of thisAgreement, the term “Affiliates” means any person or entity Controlling, Controlled by or Under Common Control with such person or entity, but with respect to the Company, specifically does not mean Riverstone, the entities Controllingit, andits investment funds,partnersofitsinvestmentfunds,andits portfolio companies other than the Company and its subsidiaries.The term “Control,” including the correlative terms “Controlling,” “Controlled by,” and “Under Common Control with” means possession, directly or indirectly, of the power to direct or cause the direction of management or policies (whether through ownership of securities or any Company or other ownership interest, by contract or otherwise) of a person or entity.For the purposes of the preceding sentence, Control shall be deemed to exist when a person or entity possesses, directly or indirectly, through one or more intermediaries (a)in the case of a corporation more than 50% of the outstanding voting securities thereof; (b)in the case of a limited liability company, partnership or joint venture, the right to more than 50% of the distributions therefrom (includingliquidating distributions); or (c)in the case of any other person or entity, more than 50% of the economic or beneficial interest therein.

20. Notices.Notices provided for in this Agreementshall be in writing and shall be deemedtohavebeendulyreceived(a)whendeliveredinpersonorsentbyfacsimile transmission,(b)on the firstbusinessday aftersuchnoticeis sentby airexpressovernight courierservice,or (c)on the thirdbusiness day followingdepositin the UnitedStatesmail, registeredorcertifiedmail,returnreceiptrequested,postageprepaidandaddressed,tothe following address, as applicable:

If to the Company, addressed to:

USACompression ManagementServices, LLC

100 Congress Avenue, Suite1550

Austin, TX78701

Attn: J. Gregory Holloway

Facsimile: (512)473‑2616

16

and a copy to:

R/CIV USACP Holdings, L.P.

c/oRiverstone Holdings, LLC

712Fifth Avenue, 51stFloor

New York, NY10019

Attn: AndrewW. Ward

Facsimile:  (212) 993‑0077

and a copy to:

Vinson & Elkins

1001 Fannin Street

Suite2500

Houston, Texas 77002-6760

Attn: E. Ramey Layne

Facsimile: (713)751‑5396

If to Employee, addressed to:

William G. Manias

Facsimile:  (___) ___‑____

21. Counterparts. This Agreementmay be executedin any numberof counterparts, including by electronic mail or facsimile, each of which when so executed and delivered shall be an original, but all such counterparts shall together constitute one and the same instrument. Each counterpart may consist of a copy hereof containing multiple signature pages, each signed by one party, but together signed by both parties hereto.

22. Deemed Resignations.Unless otherwise agreed to in writing by the Company andEmployeepriortotheterminationofEmployee’semployment,anyterminationof Employee’s employment shall constitute: (a)an automatic resignation of Employee as an officer of the Company and each member of the Company Group, as applicable, and (b)an automatic resignation of Employee from the Board (if applicable), from the board of directors or managers ofany member ofthe Company Group (ifapplicable) and from theboard ofdirectors or managers or any similar governing body of any corporation, limited liability entity or other entity in which the Company or any Affiliate holds an equity interest and with respect to which board or similar governing body Employee serves as the Company’s or such Affiliate’s designee or other representative (if applicable).

23. Key Person Insurance.AtanytimeduringtheEmploymentPeriod,the Company shall have the right to insure the life of Employee for the Company’s sole benefit. The Company shall have the right to determine the amount of insurance and the type of policy.Employee shall cooperate with the Company in obtaining such insurance by submitting to physical examinations, by supplying all information reasonably required by any insurance carrier andbyexecutingallnecessarydocumentsreasonablyrequiredbyanyinsurancecarrier.

17

Employee shall incur no financial obligation by executing any required document, and shall have no interest in any such policy.

24. Compliance with Section409A.

(a) TheseverancepayandbenefitsprovidedunderthisAgreementare intended to be exempt from or comply with Section409A of the Internal Revenue Code (the “Code”), and any ambiguous provision shall be construed in a manner consistent with such intent. For purposes of this Agreement, a “Separation from Service” shall mean Employee’s “separation from service” as such term is defined in Treasury Regulation Section 1.409A‑1(h)oranysuccessorregulation. Eachseparate severancepaymentandeachseveranceinstallmentpaymentshallbe treated as a separate payment under this Agreement for all purposes.To the extent that Employee is a “specified employee” within the meaning of Section1.409A‑l(i)(l)of the Department of Treasury Regulations, any amounts that would otherwise be payable by reason of such separation from service and are not otherwise exempt from the provisions of Section409A of the Code will delayed for a period of six months from the date of such Separation from Service, in which case the payments that would otherwise have been paid during such six month period shall be paid in a lump sum on the first day of the seventh month after the date of the Separation from Service and the remainder of such payments, if any, will be made pursuant to their terms.

(b) NotwithstandinganythingtothecontraryinthisAgreement,in‑kind benefits and reimbursements provided under this Agreement during any calendar year shall not affect in‑kind benefits or reimbursements to be provided in any other calendar year, other than an arrangement providing for the reimbursement of medical expenses referred to in Section105(b) oftheCode, and arenot subjecttoliquidation orexchange foranother benefit. Notwithstanding anything to the contrary in this Agreement, reimbursement requests must be timely submitted by Employee and, if timely submitted, reimbursement payments shallbe promptly made to Employee following such submission, but in no event later than December31stof the calendar year following the calendar year in which the expense was incurred.In no event shall Employee be entitled to any reimbursement payments after December 31stof the calendar year following the calendar year in which the expense was incurred. This paragraph shall only apply to in‑kind benefits and reimbursements that would result in taxable compensation income to Employee.

(c) If any amount payable hereunder would be subject to additional taxes and interest under Section409A of the Code because the timing of such payment is not delayed as provided in Section409A(a)(2)(B) of the Code, then the payment of such amount shall be delayed and paid, without interest, in a lump sum on the earliest of: (i)Employee’sdeath, (ii)the

18

date that is six months after the date of Employee’s Separation from Service with the Company (or if such payment date does not fall on a business day of Company, the next following business day of the Company), or (iii)such earlier date upon which such payment can be paid under Section409A of the Code without being subject to such additional taxes and interest.

[Signature Page Follows]

19

INWITNESSWHEREOF,EmployeeandtheCompanyeachhavecausedthisAgreement to be executed in its name and on its behalf, as of the Effective Date.

EMPLOYEE:

/s/ William G. Manias

William G. Manias

COMPANY:

USA COMPRESSION MANAGEMENT SERVICES, LLC

By:/s/Joseph C. Tusa, Jr.

Joseph C. Tusa, Jr.

President

Signature Page to
Employment Agreement

EXHIBITA

FORM OF RELEASE AGREEMENT

This Release Agreement (this “Agreement”) constitutes the release referred to in that certain Employment Agreement (the “Employment Agreement”)dated as ofJuly __, 2013by andamongWilliam G. Manias(“Employee”)andUSACompressionManagement Services,LLC(the “Company”).

(a) For good and valuable consideration, including the Company’s provision of a severance payment to Employee in accordance with Section6(f) of the Employment Agreement, Employee hereby releases, discharges and forever acquits each member of the Company Group and their respective Affiliates (each as defined in the Employment Agreement, provided,  however, that for purposes of this Agreement, “Affiliates” shall expresslyincludeRiverstone,theentitiesControllingit,anditsinvestmentfunds, partners of its investment funds, and its and their portfolio companies other than the Company) and subsidiaries and the past, present and future stockholders, members, partners, directors, managers, employees, agents, attorneys, heirs, representatives, successors and assigns of the foregoing, in their personal and representative capacities (collectively, the “Company Parties”), from liability for, and hereby waives, any and all claims, damages, or causes of action of any kind related to Employee’s employment with anyCompanyParty,theterminationofsuchemployment,andanyotheractsor omissions related to any matter on or prior to the date of the execution of this Agreement including, without limitation, any alleged violation through the date of this Agreement of: (i)the Age Discrimination in Employment Act of 1967, as amended; (ii)TitleVII of the Civil Rights Act of 1964, as amended; (iii)the Civil Rights Act of 1991; (iv)Section1981through 1988 of Title42 of the United States Code, as amended; (v)Employee Retirement Income Security Act of 1974, as amended; (vi)the Immigration Reform Control Act, as amended; (vii)the Americans with Disabilities Act of 1990, as amended; (viii)the National Labor Relations Act, as amended; (ix)the Occupational Safety and Health Act, as amended; (x)the Family and Medical Leave Act of 1993; (xi)any state anti‑discrimination law; (xii)any state wage and hour law; (xiii)any other local, state or federal law, regulation or ordinance; (xiv)any public policy, contract, tort, or common law claim; (xv)any allegation for costs, fees, or other expenses including attorneys’ fees incurred in these matters; (xvi)any and all rights, benefits or claims Employee may have under any employment contract, incentive compensation plan or stock option plan with anyCompany Partyortoany ownershipinterestinanyCompanyParty exceptas expressly provided in the Employment Agreement and any stock option or other equity compensation agreement between Employee and the Company and (xvii)any claim for compensationorbenefitsofanykindnotexpresslysetforthintheEmployment Agreement oranysuchstockoptionorotherequitycompensationagreement (collectively, the “Released Claims”).In no event shall the Released Claims include (i)any claim which arises after the date of this Agreement, (ii)any claim to vested benefits under an employee benefit plan, (iii)any claims for contractual payments under the EmploymentAgreement, or(iv)anyclaimsundertheOperatingAgreementoftheCompany.This Agreement is not intended to indicate that any such claims exist or

Exhibit A‑1

that, if they do exist, they are meritorious.Rather, Employee is simply agreeing that, in exchange for the consideration recited in the first sentence of this paragraph, any and all potential claims of this nature that Employee may have against the Company Parties, regardless of whether they actually exist, are expressly settled, compromised and waived. By signing this Agreement, Employee is bound by it. Anyone who succeeds to Employee’srights and responsibilities, suchas heirs or theexecutor ofEmployee’s estate, is also bound by this Agreement.This release also applies to any claims brought by any person or agency or class action under which Employee may have a right or benefit. Notwithstanding the release of liability contained herein, nothing in this Agreement prevents Employee from filing any non‑legally waivable claim (including a challenge to the validity of this Agreement) with the Equal Employment Opportunity Commission (“EEOC”) or comparable state or local agency or participating in any investigation or proceeding conducted by the .EEOC or comparable state or local agency; however, Employee understands and agrees that Employee is waiving any and all rights to recover any monetary or personal relief or recovery as a result of such EEOC or comparable state or local agency proceeding or subsequent legal actions.THIS RELEASE INCLUDES MATTERS ATTRIBUTABLE TO THE SOLE OR PARTIAL NEGLIGENCE (WHETHER GROSS OR SIMPLE) OR OTHER FAULT, INCLUDING STRICT LIABILITY, OF ANY OF THE COMPANY PARTIES.

(b) Employee agreesnot tobringor join anylawsuit against anyofthe Company Parties in any court relating to any of the Released Claims. Employee represents that Employee has not brought or joined any lawsuit or filed any charge or claim against any of the Company Parties in any court or before any government agency and has made no assignment of any rights Employee has asserted or may have against any of the Company Parties to any person or entity, in each case, with respect to any Released Claims.

(c) By executing and delivering this Agreement, Employee acknowledges that:

(i) He has carefully read this Agreement;

(ii) He has had at least [21][45]days to consider this Agreement before the execution and delivery hereof to the Company.  [Add if 45days applies: , and he acknowledges that attached to this Agreement are (A)a list of the positions and ages of those employees selected for termination (or participation in the exit incentive or other employment termination program); (B)a list of the ages of those employees not selected for termination (or participationin such program); and (C)information about the unit affected by the employment termination program of which his termination was a part, including any eligibility factors for such program and any time limits applicable to such program];

Exhibit A‑2

(iii) He has been and hereby is advised in writing that he may, at his option, discuss this Agreement with an attorney of his choice and that he has had adequate opportunity to do so;

(iv) He fully understands the final and binding effect of this Agreement; the only promises made to him to sign this Agreement are those stated in the Employment Agreement and herein; and he is signing this Agreement voluntarily and of his own free will, and that he understands and agrees to each of the terms of this Agreement; and

(v) With the exception of any sums that he may be owed pursuant to Section6(f) of the Employment Agreement, he has been paid all wages and other compensation to which he is entitled under the Agreement and received all leaves (paid and unpaid) to which he was entitled during the Employment Period (as defined in the Employment Agreement).

Notwithstanding the initial effectiveness of this Agreement, Employee may revoke the delivery (and therefore the effectiveness) of this Agreement within the seven‑day period beginning on the date Employee delivers this Agreement to the Company (such seven day period being referenced to herein as the “Release Revocation Period”).To be effective, such revocation must be in writing signed by Employee and must be delivered to [name, address]before 11:59p.m., Austin, Texas time, on the last day of the Release Revocation Period. If an effective revocation is delivered in the foregoing manner and timeframe, this Agreement shall be of no force or effect and shall be null and void ab initio.No consideration shall be paid if this Agreement is revoked by Employee in the foregoing manner.

Executed on this_____ day of _________________________, 201__.

William G. Manias

Exhibit A‑3

EX-21.1

Exhibit21.1

List of Subsidiaries

USA Compression Finance Corp., a Delaware corporation

USA Compression Partners, LLC, a Delaware limited liability company

USAC Leasing, LLC, a Delaware limited liability company

USAC OpCo 2, LLC, a Texas limited liability company

USAC Leasing 2, LLC, a Texas limited liability company

EX-23.1

Exhibit23.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Partners
USA Compression Partners, LP:

We consent to the incorporation by reference in the registration statements on Form S-8 (No. 333-187166)  and Form S-3 (No. 333-193724 and No. 333-195526) of USA Compression Partners, LP of our report dated February 11, 2016, with respect to the consolidated balance sheets of USA Compression Partners, LP as of December 31, 2015 and 2014, and the related consolidated statements of operations, changes in partners’ capital, and cash flows for each of the years in the three-year period ended December 31, 2015, which report appears in the December 31, 2015 annual report on Form 10-K of USA Compression Partners, LP.

/s/ KPMG LLP

Dallas, Texas

February11, 2016

EX-31.1

Exhibit31.1

CERTIFICATION

I, Eric D. Long, certify that:

1. I have reviewed this Annual Report on Form10-K of USA Compression Partners, LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s)and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules13a-15(e)and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules13a-15(f)and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ Eric D. Long
Name:	Eric D. Long
Title:	President and Chief Executive Officer

Dated: February 11, 2016

EX-31.2

Exhibit 31.2

CERTIFICATION

I, Matthew C. Liuzzi, certify that:

1. I have reviewed this Annual Report on Form 10-K of USA Compression Partners, LP (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ Matthew C. Liuzzi
Name:	Matthew C. Liuzzi
Title:	Vice President, Chief Financial Officer and Treasurer

Dated: February 11, 2016

EX-32.1

Exhibit 32.1

USA COMPRESSION PARTNERS, LP
CERTIFICATION PURSUANT TO
18 U.S.C. §1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of USA Compression Partners, LP (the “Partnership”) for the year ended December 31, 2015 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Eric D. Long, as President and Chief Executive Officer of the Partnership’s general partner, hereby certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to his knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

/s/ Eric D. Long

Eric D. Long

President and Chief Executive Officer

Dated: February 11, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.2

Exhibit 32.2

USA COMPRESSION PARTNERS, LP
CERTIFICATION PURSUANT TO
18 U.S.C. §1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of USA Compression Partners, LP (the “Partnership”) for the year ended December 31, 2015 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Matthew C. Liuzzi, as Vice President, Chief Financial Officer and Treasurer of the general partner of the Partnership’s general partner, hereby certifies, pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to his knowledge:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

/s/ Matthew C. Liuzzi

Matthew C. Liuzzi

Vice President, Chief Financial Officer and Treasurer

Dated: February 11, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the Partnership and will be retained by the Partnership and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Feb. 09, 2016	Jun. 30, 2015
Entity Registrant Name	USA Compression Partners, LP
Entity Central Index Key	0001522727
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 303,972,286
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	FY
Common units
Entity Common Stock, Shares Outstanding		38,556,245
Subordinated units
Entity Common Stock, Shares Outstanding		14,048,588

XML

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 7	$ 6
Accounts receivable, net:
Trade, net	28,465	25,159
Other	3,023	2,926
Inventory, net	18,872	8,923
Prepaid expenses	2,600	1,020
Total current assets	52,967	38,034
Property and equipment, net	1,318,043	1,162,637
Installment receivable	17,275	20,241
Identifiable intangible assets, net	78,773	82,357
Goodwill	35,866	208,055
Other assets	6,847	5,158
Total assets	1,509,771	1,516,482
Current liabilities:
Accounts payable	23,840	44,535
Accrued liabilities	20,582	21,708
Deferred revenue	17,000	15,855
Total current liabilities	61,422	82,098
Revolving Credit Facility	729,187	594,864
Other liabilities	874
Partners' capital:
Total partners' capital	718,288	839,520
Total liabilities and partners' capital	1,509,771	1,516,482
Limited partner | Common units
Partners' capital:
Total partners' capital	557,583	600,401
Limited partner | Subordinated units
Partners' capital:
Total partners' capital	150,787	225,221
General partner | General partner units
Partners' capital:
Total partners' capital	$ 9,918	$ 13,898

XML

Condensed Consolidated Balance Sheets (Parenthetical) - shares	Dec. 31, 2015	Dec. 31, 2014
Common units
Limited partner units issued (in shares)	38,556,245	31,307,116
Limited partner units outstanding (in shares)	38,556,245	31,307,116
Subordinated units
Limited partner units issued (in shares)	14,048,588	14,048,588
Limited partner units outstanding (in shares)	14,048,588	14,048,588

XML

Condensed Consolidated Statements of Operations - USD ($) $ in Thousands		12 Months Ended
	Jan. 18, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues:
Contract operations		$ 263,816	$ 217,361	$ 150,360
Parts and service		6,729	4,148	2,558
Total revenues		270,545	221,509	152,918
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		81,539	74,035	48,097
Selling, general, and administrative		40,950	38,718	27,587
Depreciation and amortization		85,238	71,156	52,917
Loss (gain) on sale of assets		(1,040)	(2,233)	284
Impairment of compression equipment		27,274	2,266	203
Impairment of goodwill		172,189
Total costs and expenses		406,150	183,942	129,088
Operating income (loss)		(135,605)	37,567	23,830
Other income (expense):
Interest expense, net		(17,605)	(12,529)	(12,488)
Other		22	11	9
Total other expense		(17,583)	(12,518)	(12,479)
Net income (loss) before income tax expense		(153,188)	25,049	11,351
Income tax expense		1,085	103	280
Net income (loss)		(154,273)	24,946	11,071
Net income (loss) allocated to:
General partner’s interest in net income (loss)	$ 5	(1,477)	760	211
Limited partners' interest in net income (loss)	$ 530
Net Income (Loss) Subsequent to Initial Public Offering		$ (154,273)	$ 24,946	$ 10,536
Net income per unit:
Distributions declared per limited partner unit for respective periods (in dollars per unit)		$ 2.09	$ 2.01	$ 1.73
Common units
Net income (loss) allocated to:
Limited partners' interest in net income (loss)		$ (107,513)	$ 16,811	$ 5,805
Weighted average units outstanding:
Basic (in units)		34,109,547	28,087,498	18,043,075
Diluted (in units)		34,109,547	28,146,446	18,086,745
Net income per unit:
Basic (in dollars per unit)		$ (3.15)	$ 0.60	$ 0.32
Diluted (in dollars per unit)		$ (3.15)	$ 0.60	$ 0.32
Subordinated units
Net income (loss) allocated to:
Limited partners' interest in net income (loss)		$ (45,283)	$ 7,375	$ 4,520
Weighted average units outstanding:
Basic and diluted (in units)		14,048,588	14,048,588	14,048,588
Net income per unit:
Basic and diluted (in dollars per unit)		$ (3.22)	$ 0.52	$ 0.32

XML

Condensed Consolidated Statements of Changes in Partners' Capital - USD ($) $ in Thousands	Common units Limited partner	Common units	Subordinated units Limited partner	Subordinated units	General partner units General partner	General partner	Limited partner	Total
Partners' capital at Dec. 31, 2012						$ 2,396	$ 341,130	$ 343,526
Increase (Decrease) in Partners' Capital
Conversion of Partners' capital for common and subordinated units, Incentive Distribution Rights, and General Partner interest	$ 74,526		$ 258,605		$ 10,930	$ (2,401)	$ (341,660)
Conversion of Partners' capital for common and subordinated units, Incentive Distribution Rights, and General Partner interest (in units)	4,049,000		14,049,000
Issuance of common units in initial public offering	$ 180,555							180,555
Issuance of units in common units in initial public offering (in units)	11,000,000
Vesting of phantom units (in units)	4,000
General partner contribution					4,251			4,251
Distributions and DERs	$ (22,872)		$ (17,533)		(819)			(41,224)
Issuance of common units	$ 26,286							26,286
Issuance of common units	1,084,000
Unit-based compensation	$ 1,343							1,343
Acquisition of S&R compression assets	$ 181,919							181,919
Acquisition of S&R compression assets (in units)	7,425,000
Net loss								11,071
Partners' capital at Dec. 31, 2013	$ 447,562		$ 245,592		14,573			707,727
Increase (Decrease) in Partners' Capital
Partners' Capital Account, Units	23,562,000		14,049,000
Vesting of phantom units	$ 1,707							1,707
Vesting of phantom units (in units)	76,000
General partner contribution					294			294
Distributions and DERs	$ (53,854)		$ (27,746)		(1,729)			(83,329)
Issuance of common units	$ 188,992							188,992
Issuance of common units	7,669,000
Unit-based compensation	$ 353							353
Modification of unit-based compensation	(1,170)							(1,170)
Net loss	16,811		7,375		760			24,946
Partners' capital at Dec. 31, 2014	$ 600,401		$ 225,221		13,898			839,520
Increase (Decrease) in Partners' Capital
Partners' Capital Account, Units	31,307,000		14,049,000
Limited Partners' Capital Account, Units Outstanding		31,307,116		14,048,588
Vesting of phantom units	$ 1,844							1,844
Vesting of phantom units (in units)	101,000
Distributions and DERs	$ (69,480)		$ (29,151)		(2,503)			(101,134)
Issuance of common units	$ 132,006							132,006
Issuance of common units	7,148,000
Unit-based compensation	$ 325							325
Net loss	(107,513)		(45,283)		(1,477)			(154,273)
Partners' capital at Dec. 31, 2015	$ 557,583		$ 150,787		$ 9,918			$ 718,288
Increase (Decrease) in Partners' Capital
Partners' Capital Account, Units	38,556,000		14,049,000
Limited Partners' Capital Account, Units Outstanding		38,556,245		14,048,588

XML

Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net income (loss)	$ (154,273)	$ 24,946	$ 11,071
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	85,238	71,156	52,917
Amortization of debt issue costs	1,702	1,224	2,192
Unit-based compensation expense	3,863	3,034	1,343
Net (gain) loss on sale of assets	(1,040)	(2,233)	284
Impairment of compression equipment	27,274	2,266	203
Impairment of goodwill	172,189
Changes in assets and liabilities:
Accounts receivable	(439)	(2,659)	(11,674)
Inventory	(14,340)	(4,942)	(5,725)
Prepaids	(1,580)	1,380	(600)
Other noncurrent assets	(3)	(39)	3,824
Accounts payable	(3,310)	(1,431)	8,132
Accrued liabilities and deferred revenue	2,120	9,189	6,223
Net cash provided by operating activities	117,401	101,891	68,190
Cash flows from investing activities:
Capital expenditures	(281,050)	(381,943)	(159,547)
Proceeds from sale of property and equipment	1,735	1,420	2,227
Proceeds from insurance recovery	1,157
Acquisitions, net of cash			3,374
Net cash used in investing activities	(278,158)	(380,523)	(153,946)
Cash flows from financing activities:
Proceeds from long-term debt	480,004	538,644	243,501
Payments on long-term debt	(345,681)	(364,714)	(324,834)
Cash paid for taxes related to net settlement of unit-based awards	(210)	(334)
Cash distributions	(45,078)	(32,345)	(14,669)
General partner contribution		294	4,251
Financing costs	(3,388)	(961)	(3,048)
Net proceeds from issuance of common units	75,111	138,047	180,555
Net cash provided by financing activities	160,758	278,631	85,756
Increase (decrease) in cash and cash equivalents	1	(1)
Cash and cash equivalents, beginning of period	6	7	7
Cash and cash equivalents, end of period	7	6	7
Supplemental cash flow information:
Cash paid for interest	17,110	12,622	10,603
Cash paid for taxes	282	115	196
Supplemental non-cash transactions:
Non-cash distribution to certain limited partners (DRIP)	56,895	51,707	26,286
Change in capital expenditures included in accounts payable and accrued liabilities	$ (19,256)	16,515	$ 15,846
Capital Lease Transaction
Installment receivable		(24,820)
Property and equipment write-off		22,134
(Gain) on transaction		$ (2,686)

XML

The Partnership, Nature of Business, and Recent Transactions

12 Months Ended

Dec. 31, 2015

The Partnership, Nature of Business, and Recent Transactions

The Partnership, Nature of Business, and Recent Transactions

(1)  The Partnership, Nature of Business, and Recent Transactions

USA Compression Partners, LP, a Texas limited partnership (the “Former Partnership”), was formed on July 10, 1998. In October 2008, the Former Partnership entered into several transactions through which the Former Partnership was reorganized into a holding company, USA Compression Holdings, LP (the “Partnership”). The owners of the Former Partnership caused the Partnership to be formed as a Texas limited partnership to conduct its affairs as the holding company of an operating and leasing structure of entities. The Former Partnership’s owners then transferred their equity interests in the Former Partnership to the Partnership in exchange for identical interests in the Partnership. The Former Partnership became a wholly-owned subsidiary of the Partnership, and was converted into USA Compression Partners, LLC, a Delaware, single-member, limited liability company (the “Operating Subsidiary”) to continue providing compression services to customers of the Former Partnership. Concurrently, the Operating Subsidiary formed a wholly-owned subsidiary, USAC Leasing, LLC, as a Delaware limited liability company (the “Leasing Subsidiary”), and agreed to sell its then existing compressor fleet to the Leasing Subsidiary for assumption of debt relating to the then existing fleet. On June 7, 2011, the Partnership converted from a Texas limited partnership into a Delaware limited partnership and changed its name from USA Compression Holdings, LP to USA Compression Partners, LP. USA Compression GP, LLC, a Delaware limited liability Company and the general partner of the Partnership, is referred to herein as the “General Partner.”  In connection with the S&R Acquisition (as defined below), the Partnership acquired all of the membership interests in USAC OpCo 2, LLC, a Texas limited liability company (“OpCo 2”), which owned all of the membership interests in USAC Leasing 2, LLC, a Texas limited liability company (“LeaseCo 2”). LeaseCo 2 owns all of the compression assets acquired in the S&R Acquisition as well as certain compression assets acquired after the acquisition.  Each of Leasing Subsidiary and LeaseCo 2 leases its compressor fleet to Operating Subsidiary and OpCo 2, respectively, for use in providing compression services to customers. The Partnership is a guarantor to Operating Subsidiary’s revolving credit facility and each of Leasing Subsidiary, OpCo2 and LeaseCo2 are co-borrowers on the revolving credit facility (see Note 8). The accompanying consolidated financial statements include the accounts of the Partnership, the Operating Subsidiary, the Leasing Subsidiary, OpCo 2 and LeaseCo 2, and all intercompany balances and transactions have been eliminated in consolidation. The Operating Subsidiary, the Leasing Subsidiary, OpCo 2 and LeaseCo 2, are collectively referred to herein, as the “Operating Subsidiaries.”

The Partnership, through the Operating Subsidiaries, provides compression services under term contracts with customers in the natural gas and crude oil industry, using natural gas compression packages that it designs, engineers, owns, operates and maintains.

Partnership net income (loss) is allocated to the partners, both general and limited, in proportion to their respective interest in the Partnership.

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Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2015

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

(2)  Summary of Significant Accounting Policies

(a)Cash and Cash Equivalents

Cash and cash equivalents consist of all cash balances. The Partnership considers investments in highly liquid financial instruments purchased with an original maturity of 90 days or less to be cash equivalents. 

(b)Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $2.1 million and $0.4 million as of December 31, 2015 and 2014, respectively, is the Partnership’s best estimate of the amount of probable credit losses in the Partnership’s existing accounts receivable. Bad debt expense for the year ended December 31, 2015 was $1.8 million.  The determination of the allowance for doubtful accounts requires us to make estimates and judgments regarding our customers’ ability to pay amounts due.  The Partnership determines the allowance based upon historical write-off experience, specific customer circumstances and the overall business climate in which our customers operate. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

(c)Inventories

Inventory consists of serialized and non-serialized parts used primarily in the repair of compression units. Serialized parts inventories are valued at the lower of cost or market value using the specific identification method, while non-serialized parts inventory is valued using the weighted average cost method. Purchases of these assets are considered operating activities in the consolidated statement of cash flows. 

Significant components of inventories as of December 31, 2015 and 2014 are as follows (in thousands):

	2015		2014
Serialized parts	$	18,361	$	9,286
Non-serialized parts		825		—
Total Inventory, gross		19,186		9,286
Less: obsolete and slow moving reserve		(314)		(363)
Total Inventory, net	$	18,872	$	8,923

(d)Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compression equipment are capitalized and depreciated over 3 to 5 years. Ordinary maintenance and repairs are charged to cost of operations, exclusive of depreciation and amortization. Depreciation is calculated using the straight-line method over the estimated useful lives of the assets as follows:

Compression equipment	25years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

Depreciation expense for the years ended December 31, 2015, 2014 and 2013 was $81.7 million, $67.6 million and $49.7 million, respectively.

(e)Impairments of Long-Lived Assets

Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written-down to estimated fair value. An asset shall be tested for impairment when events or circumstances indicate that its carrying value may not be recoverable or will no longer be utilized in the operating fleet. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows associated with the operating fleet, an impairment loss equal to the amount of the carrying value exceeding the fair value of the asset is recognized. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows, the expected net sale proceeds compared to the other similarly configured fleet units the Partnership recently sold or a review of other units recently offered for sale by third parties, or the estimated component value of the equipment the Partnership plans to use.   

Refer to Note 4 for more detailed information about impairment charges during the years ended December 31, 2015 and 2014.

(f)Revenue Recognition

Revenue from contract operations is recorded when earned over the period of the contract, which generally ranges from one month to five years. Parts and service revenue is recorded as parts are delivered or services are performed for the customer.

(g)Income Taxes

The Partnership elected to be treated under SubChapter K of the Internal Revenue Code. Under SubChapter K, a partnership return is filed annually reflecting each partner’s allocable share of the partnership’s income or loss. Therefore, no provision has been made for federal income tax. Partnership net income (loss) is allocated to the partners in proportion to their respective interest in the Partnership.

As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by the Partnership generally flow through to its unitholders. However, Texas imposes an entity-level income tax on partnerships.

Refer to Note 7 for more detailed information about the Revised Texas Franchise Tax for the years ended December 31, 2015, 2014 and 2013.

(h)Fair Value Measurements

Accounting standards on fair value measurements establish a framework for measuring fair value and stipulate disclosures about fair value measurements. The standards apply to recurring and nonrecurring financial and non-financial assets and liabilities that require or permit fair value measurements. Among the required disclosures is the fair value hierarchy of inputs the Partnership uses to value an asset or a liability. The three levels of the fair value hierarchy are described as follows:

Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Partnership has the ability to access at the measurement date.

Level 2 inputs are those other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly.

Level 3 inputs are unobservable inputs for the asset or liability.

As of December 31, 2015 and 2014, the Partnership’s financial instruments consisted primarily of cash and cash equivalents, trade accounts receivable, trade accounts payable and long-term debt. The book values of cash and cash equivalents, trade accounts receivable, and trade accounts payable are representative of fair value due to their short-term maturity. The carrying amount of long-term debt approximates fair value due to the floating interest rates associated with the debt.

Phantom unit awards granted to employees under the USA Compression Partners, LP 2013 Long-Term Incentive Plan (the “LTIP”) are accounted for as a liability, and such liability is re-measured on a quarterly basis.  The liability is based on the publicly quoted price of the Partnership’s common units, which is considered a Level 1 input.  Refer to Note 10 for more detailed information about unit-based compensation for the years ended December 31, 2015, 2014 and 2013.

As part of the impairment analysis of goodwill, the fair value of the Partnership’s goodwill was re-measured using Level 3 inputs.  Refer to the Goodwill section of Note 2 below for more detailed information about the valuation as of December 31, 2015 and 2014.

(i)Pass Through Taxes

Sales taxes incurred on behalf of, and passed through to, customers are accounted for on a net basis.

(j)Use of Estimates

The preparation of the consolidated financial statements of the Partnership in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires the management of the Partnership to make estimates and assumptions that affect the amounts reported in these consolidated financial statements and the accompanying results. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could differ from these estimates.

(k)Identifiable Intangible Assets

As of December 31, 2015, identifiable intangible assets consisted of the following (in thousands):

	Customer
	Relationships		Trade Names		Non-compete		Total
Gross Balance at December 31, 2013	$	78,700		15,600		900	$	95,200
Additions		—		—		—		—
Accumulated amortization		(10,047)		(2,496)		(300)		(12,843)
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Gross Balance at December 31, 2014		78,700		15,600		900		95,200
Additions		—		—		—		—
Accumulated amortization		(12,782)		(3,120)		(525)		(16,427)
Net Balance at December 31, 2015	$	65,918	$	12,480	$	375	$	78,773

Identifiable intangible assets are amortized using the straight-line method over their estimated useful lives, which is the period over which the assets are expected to contribute directly or indirectly to the Partnership’s future cash flows. The estimated useful lives range from 4 to 30 years. Amortization expense for the years ended December 31, 2015, 2014 and 2013 was $3.6 million, $3.6 million and $3.2 million, respectively.  The expected amortization of the identifiable intangible assets for each of the five succeeding years is as follows (in thousands):

Year ending December 31,	Total
2016	$	3,584
2017		3,509
2018		3,359
2019		3,359
2020		3,359

The Partnership assesses identifiable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The Partnership did not record any impairment of identifiable intangible assets in the years ended December 31, 2015,  2014 or 2013.

(l)Goodwill

Goodwill represents consideration paid in excess of the fair value of the identifiable net assets acquired in a business combination. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of October 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.

As of October 1, 2015, a quantitative assessment was performed to determine whether the fair value of the Partnership’s single reporting unit was greater than its carrying value.  As of October 1, 2015, the fair value was determined to be in excess of the carrying value. Due to the identification of certain impairment indicators during the fourth quarter of 2015, specifically (1) the decline in the market price of the Partnership’s common units, (2) the sustained decline in global commodity prices, and (3) the decline in performance of the Alerian MLP Index, the Partnership prepared a quantitative assessment as of December 31, 2015.  This assessment indicated that the calculated fair value was less than the carrying value.  As such, the Partnership prepared a Step 2 impairment test which measures the amount of the impairment loss and involves a hypothetical allocation of the estimated fair value of the reporting unit among all assets and liabilities of the reporting unit.  The carrying value of goodwill exceeded the implied value of goodwill and an impairment charge was recorded for $172.2 million.  The fair value of our single reporting unit was calculated using the Discounted Cash Flow Method, an income approach.  This method utilizes Level 3 inputs from the fair value hierarchy. The impairment of goodwill is primarily the result of the sustained decline in the market price of the Partnership’s common units.  The continued decline in commodity prices has adversely impacted many of the Partnership’s customers and resulted in a significant decline in their future capital expansion plans.  This has in turn reduced the Partnership’s expected future capital expansion plans and in turn, the Partnership’s estimated future cash flows. 

The Partnership had approximately $35.9 million of goodwill remaining on the balance sheet as of December 31, 2015.No impairment of goodwill was recorded in the years ended December 31, 2014 and 2013.

(m)Capitalized Interest

For each of the years ended December 31, 2015 and 2014, the Partnership capitalized $0.3 million of interest expense in accordance with Accounting Standards Codification (“ASC”) Topic 835-20 for interest costs incurred during the period related to upfront payments required in acquiring certain compression units.  The Partnership capitalized no interest during the year ended December 31, 2013.

(n)Operating Segment

The Partnership operates in a single business segment, the compression services business. 

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Acquisitions

12 Months Ended

Dec. 31, 2015

Acquisitions

Acquisitions

(3)  Acquisition

On August 30, 2013, the Partnership completed the acquisition of assets and certain liabilities related to S&R Compression, LLC’s (“S&R”) business of providing gas lift compression services to third parties engaged in the exploration, production, gathering, processing, transportation or distribution of oil and gas in exchange for 7,425,261 common units, which were valued at $181.9 million at the time of issuance (the “S&R Acquisition”). The S&R Acquisition was consummated pursuant to the contribution agreement with S&R and Argonaut Private Equity L.L.C. (“Argonaut”). The S&R Acquisition had an effective date (from a standpoint of settling working capital) of June 30, 2013. The consolidated financial statements reflect the operating results of the S&R Acquisition for the period subsequent to the August 30, 2013 acquisition. At the time of the closing of the acquisition, the common units issued in the S&R Acquisition were not registered pursuant to the Securities Act of 1933, as amended(the “Securities Act”), or any applicable state securities laws, and, at the time of issuance, were restricted securities under the federal securities laws. The resale of the common units issued in the S&R Acquisition was registered pursuant to the Shelf Registration Statement (as defined below). The effective purchase price of $178.5 million reflects customary effective-date adjustments such as a $3.4 million purchase price adjustment due to working capital changes from the effective date to the closing date.

The transaction was accounted for in accordance with ASC Topic 805, Business Combinations. The purchase price allocation as of August 30, 2013 is comprised of the following components (in thousands):

Issuance of limited partner units	$	181,919
Less cash received for working capital adjustment		(3,374)
Total consideration	$	178,545
Trucks and Trailers	$	2,158
Compression equipment		117,784
Computers		23
Intangibles
Customer relationships		6,700
Non-compete		900
Total intangibles		7,600
Goodwill		50,980
Allocation of Purchase Consideration	$	178,545

Expenses associated with acquisition activities and transaction activities related to the S&R Acquisition for the year ended December 31, 2013 were $2.1 million and were included in selling, general and administrative expenses (“SG&A”). The acquisition was recorded at fair value, which was determined using the cost and market approaches for the fixed assets, the multi-period excess earnings method for the customer relationships asset and the with-and-without method for the non-compete agreement. In applying these accounting principles, the Partnership estimated the fair value of the S&R assets acquired to be $127.6 million. This measurement resulted in the recognition of goodwill totaling approximately $51.0 million. Goodwill was calculated as the excess of the consideration transferred to acquire S&R over the acquisition date estimated fair value of the assets acquired. Goodwill recorded in the S&R Acquisition primarily represents the value of the opportunity to expand into gas lift operations with a high quality fleet, the experience and technical expertise of former S&R employees who have joined the Partnership and the addition of strategic areas of operations in which the Partnership did not previously have a significant presence. This goodwill was included as a component of the goodwill impairment, as described in Note 2.  The intangible asset customer relationships will be amortized over a life of 20 years and the intangible asset non-compete will be amortized over the 4-year term of the agreement.

Revenue, Net Income and Pro Forma Financial Information — Unaudited

For the period of August 30, 2013 to December 31, 2013, the S&R Acquisition accounted for $14.5 million of revenue, $4.4 million of direct operating expenses, and $0.6 million of SG&A and $3.7 million of depreciation and amortization, resulting in $5.8 million of net income. The net income attributable to these assets does not reflect certain expenses, such as certain SG&A and interest expense; therefore, this information is not intended to report results as if these operations were managed on a stand-alone basis.

The unaudited pro forma financial information was prepared assuming the S&R Acquisition occurred on January 1, 2013. The financial information was derived from the Partnership’s audited historical consolidated financial statements for the year ended December 31, 2013 and S&R’s unaudited interim financial statements from January 1, 2013 through August 30, 2013.

The pro forma adjustments were based on currently available information and certain estimates and assumptions by management. If the S&R Acquisition had been in effect on the dates or for the periods indicated, the results may have been substantially different. For example, the Partnership may have operated the assets differently than S&R, realized revenue may have been different and costs of operation of the compression assets may have been different. This pro forma financial information is provided for illustrative purposes only and may not provide an indication of results in the future.  The following table presents a summary of pro forma financial information (in thousands, except for unit amounts):

	Year Ended December 31,
	2013
	(unaudited)
Total revenues	$	176,254
Net income		15,919
Net income allocated to:
General partner’s interest in net income		318
Limited partner’s interest in net income:
Common units		10,054
Subordinated units		5,546
Basic and diluted net income per common unit	$	0.39
Basic and diluted net income per subordinated unit	$	0.39

In preparing the pro forma financial information, certain information was derived from financial records and certain information was estimated. The sources of information and significant assumptions are described below:

(a) Revenues and direct operating expenses for S&R were derived from the historical financial records of S&R. Incremental revenue adjustments related to the S&R Acquisition were $27.1 million for the year ended December 31, 2013. Incremental operating costs related to the S&R Acquisition were $12.2 million for the year ended December 31, 2013.

(b) Depreciation and amortization was estimated using the straight-line method and reflects the incremental depreciation and amortization expense incurred due to adding the compression assets and intangible fair value assets acquired from S&R. Incremental depreciation and amortization was estimated at $9.7 million for the year ended December 30, 2013.

(c) Incremental transaction expenses related to the S&R Acquisition were $2.1 million and were assumed to be funded from cash on hand.

(d) The S&R Acquisition was financed solely with common units issued in consideration for the assets and liabilities acquired as part of the S&R Acquisition.

(e) The capital contribution made by the General Partner to maintain its then 2% general partner interest in the Partnership in connection with the issuance of common units in the S&R Acquisition was used to pay down the Partnership’s revolving credit facility resulting in a reduction of interest expense. Incremental interest expense reductions were estimated at $90,000for the year ended December 31, 2013.

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Property and Equipment

12 Months Ended

Dec. 31, 2015

Property and Equipment

Property and Equipment

(4)  Property and Equipment

Property and equipment consisted of the following at December 31 (in thousands):

	2015		2014
Compression equipment	$	1,520,835	$	1,311,943
Furniture and fixtures		669		619
Automobiles and vehicles		19,284		17,303
Computer equipment		21,457		11,913
Leasehold improvements		1,197		858
Total Property and equipment, gross		1,563,442		1,342,636
Less: accumulated depreciation and amortization		(245,399)		(179,999)
Total Property and equipment, net	$	1,318,043	$	1,162,637

As of December 31, 2015 and 2014, there was$13.1 million and $32.4 million,  respectively, of property and equipment purchases in accounts payable and accrued liabilities.

For the year ended December 31, 2015, non-cash transfers of inventory to and from property and equipment totaled $4.0 million.  These transfers have been treated as non-cash inventory activities in the Consolidated Statements of Cash Flows.

During the year ended December 31, 2015, insurance recoveries of $1.2 million were received on previously impaired compression equipment and are reported within the Loss (gain) on sale of assets line in the Consolidated Statements of Operations. 

During the year ended December 31, 2015, the Partnership evaluated the future deployment of its idle fleet under current market conditions and determined to retire and either sell or re-utilize the key components of 166 compressor units, or approximately 58,000 horsepower, that were previously used to provide services in the Partnership’s business.  This compression equipment was written down to its respective estimated salvage value, measured using quoted market prices, or the estimated component value of the equipment the Partnership plans to use.  The Partnership recorded $27.3 million,  $2.3 million and $0.2 million in impairment of compression equipment for the years ended December 31, 2015, 2014 and 2013, respectively.

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Installment Receivable

12 Months Ended

Dec. 31, 2015

Installment Receivable

Installment Receivable

(5)  Installment Receivable

On June 30, 2014, the Partnership entered into a FMV Bargain Purchase Option Grant Agreement (the “Capital Lease Transaction”) with a customer, pursuant to which the Partnership granted a bargain purchase option to the customer with respect to certain compressor packages leased to the customer (each a “Subject Compressor Package”). The bargain purchase option provides the customer with an option to acquire the equipment at a value significantly less than the fair market value at the end of the lease term.

The Capital Lease Transaction was accounted for as a sales type lease and, as of December 31, 2015 and 2014, resulted in a current installment receivable of $3.0 million and $2.8 million, respectively, included in other accounts receivable and a long-term installment receivable of $17.3 million and $20.2 million, respectively. Additionally, the Partnership recorded a $2.6 million gain on sale of assets related to the Capital Lease Transaction for the year ended December 31, 2014. 

For the year ended December 31, 2015, non-cash transfers from long-term installment receivable to current installment receivable totaled $3.0 million.  These transfers have been treated as non-cash accounts receivable activities in the Consolidated Statements of Cash Flows.

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Accrued Liabilities

12 Months Ended

Dec. 31, 2015

Accrued Liabilities

Accrued Liabilities

(6)  Accrued Liabilities

Other current liabilities included accrued payroll and benefits and accrued property taxes.  The Partnership recognized $7.1 million and $5.5 million of accrued payroll and benefits as of December 31, 2015 and 2014, respectively.  The Partnership recognized $4.1 million and $4.8 million of accrued property taxes as of December 31, 2015 and 2014, respectively.

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Income Tax Expense

12 Months Ended

Dec. 31, 2015

Income Tax Expense Disclosure Abstract

Income tax expense

(7) Income Tax Expense

The Partnership is subject to the Revised Texas Franchise Tax (“Texas Margin Tax”). The Partnership does not do business in any other state where a similar tax is applied.

The Texas Margin Tax became effective for tax reports originally due on or after January 1, 2008. This margin tax requires certain forms of legal entities, including limited partnerships, to pay a tax of 1.0% (or 0.75% for 2015 and forward) on its “margin,” as defined in the law, based on annual results. The margin tax base to which the tax rate is applied is the least of (1) 70% of total revenues for federal income tax purposes, (2) total revenue less cost of goods sold or (3) total revenue less compensation for federal income tax purposes. For the years ended December 31, 2015, 2014 and 2013, the Partnership recorded expense related to the Texas margin tax of $1.1 million,  $0.1 million and $0.3 million, respectively.

Components of income tax expense are as follows (in thousands):

	2015		2014		2013
Current tax expense:
State income tax	$	211	$	103	$	280
Total current tax expense		211		103		280
Deferred tax expense:
State income tax	$	874	$	—	$	—
Total deferred tax expense		874		—		—
Total income tax expense	$	1,085	$	103	$	280

Deferred income tax balances are the direct effect of temporary differences between the financial statement carrying amounts and the tax basis of assets and liabilities at the enacted tax rates expected to be in effect when the taxes are actually paid or recovered. The tax effects of temporary differences that give rise to deferred tax liabilities are as follows (in thousands):

	2015		2014
Deferred tax liabilities
Property and equipment	$	874	$	—
Total deferred tax liabilities		874		—
Net deferred tax liabilities	$	874	$	—

The Financial Accounting Standards Board’s (“FASB”) ASC Topic 740-10 (“ASC 740-10”) provides guidance on measurement and recognition in accounting for income tax uncertainties and provides related guidance on derecognition, classification, disclosure, interest, and penalties. As of December 31, 2015, the Partnership had no material unrecognized tax benefits (as defined in ASC 740-10). The Partnership does not expect to incur interest charges or penalties related to its tax positions, but if such charges or penalties are incurred, the Partnership’s policy is to account for interest charges as Interest expense, net and penalties as Income tax expense in the Consolidated Statements of Operations.

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Long-Term Debt

12 Months Ended

Dec. 31, 2015

Long-Term Debt

Long-Term Debt

(8)  Long-Term Debt

The long-term debt of the Partnership consisted of the following as of December 31 (in thousands):

	2015		2014
Revolving Credit Facility	$	729,187	$	594,864

On December 13, 2013, the Partnership entered into a Fifth Amended and Restated Credit Agreement (the “revolving credit facility”) whereby the aggregate commitment under the facility increased from $600 million to $850 million (subject to availability under the Partnership’s borrowing base and a further potential increase of $100 million) and reduced the applicable margin for BBA London Interbank Offering Rate (“LIBOR”) loans to a range of 150 to 225 basis points above LIBOR, depending on the Partnership’s leverage ratio. The Partnership’s revolving credit facility is secured by a first priority lien against its assets.

On June 30, 2014, the Partnership entered into a letter agreement regarding a limited consent, amendment and subordination relating to the revolving credit facility to (a) permit the Capital Lease Transaction, (b) permit the customer’s lien with respect to the Subject Compressor Packages, (c) to subordinate the lien of JPMorgan Chase Bank, N.A., as administrative agent under our revolving credit facility, for the benefit of itself and the lenders under the revolving credit facility, to the lien and purchase option of the customer with respect to the Subject Compressor Packages, (d) authorize the release of the lien of the administrative agent, for the benefit of itself and the lenders, upon the exercise by the customer of its purchase option with respect to a specific Subject Compressor Package and (e) amend certain other provisions of the revolving credit facility.

On January 6, 2015, the Partnership entered into a Second Amendment to our revolving credit facility, whereby, the aggregate commitment under the revolving credit facility increased from $850.0 million to $1.1 billion (subject to availability under our borrowing base), with a further potential increase of $200 million and the maturity date of the revolving credit facility was extended to January 6, 2020.  In addition, this Second Amendment provided additional flexibility under the financial covenants of the revolving credit facility.

The revolving credit facility permits the Partnership to make distributions of available cash to unitholders so long as (a) no default under the facility has occurred, is continuing or would result from the distribution, (b) immediately prior to and after giving effect to such distribution, the Partnership is in compliance with the facility’s financial covenants and (c) immediately after giving effect to such distribution, the Partnership has availability under the revolving credit facility of at least $20 million. In addition, the revolving credit facility contains various covenants that may limit, among other things, the Partnership’s ability to (subject to exceptions):

· grant liens;

· make certain loans or investments;

· incur additional indebtedness or guarantee other indebtedness;

· enter into transactions with affiliates;

· merge or consolidate;

· sell the Partnership’s assets; or

· make certain acquisitions.

The revolving credit facility also contains various financial covenants, including covenants requiring the Partnership to maintain:

· a minimum EBITDA to interest coverage ratio of 2.5 to 1.0; and

· a maximum funded debt to EBITDA ratio, determined as of the last day of each fiscal quarter, for the annualized trailing three months of (a) 5.50to 1.0 through December 31, 2014, (b) 5.95to 1.0 through the end of the fiscal quarter ending June 30, 2015, (c) 5.50to 1.0 through the end of the fiscal quarter ending June 30, 2016 and (d) 5.00 to 1.0 thereafter, in each case subject to a provision for increases to such thresholds by 0.5 in connection with certain future acquisitions for the six consecutive month period following the period in which any such acquisition occurs.

If a default exists under the revolving credit facility, the lenders will be able to accelerate the maturity on the amount then outstanding and exercise other rights and remedies.

The Partnership paid various loan fees and incurred costs in respect of the revolving credit facility in the amount of $3.4 million,$0.2 million, and $3.0 million in 2015, 2014 and 2013,  respectively, which were capitalized to loan costs and will be amortized through January 2020. The Partnership wrote off $0.3 million in 2013 related to certain third parties that exited the credit facility.

As of December 31, 2015 and 2014, the Partnership was in compliance with all of its covenants under the revolving credit facility.

As of December 31, 2015, the Partnership had outstanding borrowings under its revolving credit facility of $729.2 million, $370.8 million of borrowing base availability and,subject to compliance with the applicable financial covenants, available borrowing capacity of $101.0 million. The borrowing base consists of eligible accounts receivable, inventory and compression units. The largest component, representing 91% and 94% of the borrowing base as of December 31, 2015 and 2014, respectively, was eligible compression units.  Eligible compression units consist of compressor packages that are leased, rented or under service contracts to customers and carried in the financial statements as fixed assets. The Partnership’s interest rate in effect for all borrowings under its revolving credit facility as of December 31, 2015 and 2014 was 2.26% and 2.16%, respectively, with an average interest rate of 2.24%,2.22%, and 2.43% during 2015, 2014 and 2013, respectively. There were no letters of credit issued as of December 31, 2015 and 2014.

The revolving credit facility matures in January 2020 and the Partnership expects to maintain this facility for the term. The facility is a “revolving credit facility” that includes a “springing” lock box arrangement, whereby remittances from customers are forwarded to a bank account controlled by the Partnership, and the Partnership is not required to use such remittances to reduce borrowings under the facility, unless there is a default or excess availability under the facility is reduced below $20 million. As the remittances do not automatically reduce the debt outstanding absent the occurrence of a default or a reduction in excess availability below $20 million, the debt has been classified as long-term as of December 31, 2015 and 2014.

Maturities of long-term debt (in thousands):

Year ending December 31,
2016		—
2017		—
2018		—
2019		—
2020		729,187
Total Debt	$	729,187

In the event that any of the Operating Subsidiaries guarantees any series of the debt securities as described in the Partnership’s registration statement filed on Form S-3 (Reg. No. 333-193724), such guarantees will be full and unconditional and made on a joint and several basis for the benefit of each holder and the Trustee. However, such guarantees will be subject to release, subject to certain limitations, as follows (i) upon the sale, exchange or transfer, whether by way of a merger or otherwise, to any Person that is not an Affiliate of the Partnership, of all the Partnership’s direct or indirect limited partnership or other equity interest in such Subsidiary Guarantor; or (ii) upon the Partnership’s or USA Compression Finance Corp.’s (together, the “Issuers”) delivery of a written notice to the Trustee of the release or discharge of all guarantees by such Subsidiary Guarantor of any Debt of the Issuers other than obligations arising under the indenture governing such debt and any debt securities issued under such indenture, except a discharge or release by or as a result of payment under such guarantees. Capitalized terms used but not defined in this paragraph are defined in the Form of Indenture filed as exhibit 4.1 to such registration statement.

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Partners' Capital

12 Months Ended

Dec. 31, 2015

Partners' Capital.

Partners' Capital

(9)  Partner’s Capital

As of February 9, 2016, USA Compression Holdings held 7,267,511 common units and 14,048,588 subordinated units and controlled the General Partner which held an approximate 1.46% general partner interest (the “General Partner’s Interest”) and the incentive distribution rights (“IDRs”). See the Consolidated Statement of Changes in Partners’ Capital.

Subordinated Units

All of the subordinated units are held by USA Compression Holdings. The Partnership’s limited partnership agreement (the “Partnership Agreement”) provides that, during the subordination period, the common units have the right to receive distributions of Available Cash from Operating Surplus (each as defined in the Partnership Agreement) each quarter in an amount equal to $0.425 per common unit (the “Minimum Quarterly Distribution”), plus any arrearages in the payment of the Minimum Quarterly Distribution from Operating Surplus on the common units from prior quarters, before any distributions of Available Cash from Operating Surplus may be made on the subordinated units. These units are deemed “subordinated” because for a period of time, referred to as the subordination period, the subordinated units will not be entitled to receive any distributions from Operating Surplus until the common units have received the Minimum Quarterly Distribution plus any arrearages from prior quarters. The practical effect of the subordinated units is to increase the likelihood that during the subordination period there will be Available Cash from Operating Surplus to be distributed on the common units. The subordination period will end on the first business day after the Partnership has earned and paid at least (i) $1.70 (the Minimum Quarterly Distribution on an annualized basis) on each outstanding unit and the corresponding distribution on the General Partner’s Interest, for each of three consecutive, non-overlapping four-quarter periods ending on or after December 31, 2015 or (ii) $2.55(150.0% of the annualized Minimum Quarterly Distribution) on each outstanding unit and the corresponding distributions on the General Partner’s Interest and the related distribution on the incentive distribution rights for the four-quarter period immediately preceding that date. When the subordination period ends, all subordinated units will convert into common units on a one-for-one basis, and all common units thereafter will no longer be entitled to arrearages.  All of our outstanding subordinated units will convert to common units on a one-for-one basis on February 16, 2016 upon the Partnership’s payment of its quarterly distribution on February 12, 2016.

Incentive Distribution Rights

The General Partner holds all of the IDRs. The following table illustrates the percentage allocations of Available Cash from Operating Surplus between the unitholders and the General Partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of the General Partner and the unitholders in any Available Cash from Operating Surplus the Partnership distributes up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit.” The percentage interests shown for the Partnership’s unitholders and the General Partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for the General Partner include its General Partner’s Interest, and assume the General Partner has contributed any additional capital necessary to maintain its General Partner’s Interest, the General Partner has not transferred the IDRs and there are no arrearages on common units.

		Marginal Percentage Interest in
	Total Quarterly	Distributions
	Distributions per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.54	%	1.46	%
First Target Distribution	up to $0.4888	98.54	%	1.46	%
Second Target Distribution	above $0.4888 up to $0.5313	85.54	%	14.46	%
Third Target Distribution	above $0.5313 up to $0.6375	75.54	%	24.46	%
Thereafter	above $0.6375	50.54	%	49.46	%

Cash Distributions

The Partnership has declared quarterly distributions per unit to limited partner unitholders of record, including holders of common, subordinated and phantom units and distributions paid to the General Partner, including the General Partner’s Interest and IDRs, as follows (dollars in millions, except distribution per unit):

	Distribution per			Amount Paid to		Amount Paid to		Amount Paid to		Amount Paid to
	Limited Partner			Common		Subordinated		General		Phantom		Total
Payment Date	Unit			Unitholders		Unitholder		Partner		Unitholders		Distribution
May 15, 2013	$	0.348	(1)	$	5.2	$	4.9	$	0.2	$	—	$	10.3
August 14, 2013		0.440			6.7		6.2		0.3		—		13.2
November 14, 2013		0.460			10.6		6.5		0.3		—		17.4
February 14, 2014		0.480			11.3		6.7		0.4		—		18.4
May 15, 2014		0.490			11.8		6.9		0.4		0.2		19.3
August 14, 2014		0.500			15.1		7.0		0.5		0.2		22.8
November 14, 2014		0.505			15.5		7.1		0.5		0.2		23.3
February 13, 2015		0.510			16.0		7.2		0.5		0.1		23.8
May 15, 2015		0.515			16.6		7.2		0.6		0.2		24.6
August 14, 2015		0.525			17.2		7.4		0.7		0.2		25.5
November 13, 2015		0.525			19.7		7.4		0.7		0.2		28.0

(1) Prorated to reflect 72 days of quarterly cash distribution rate of $0.435 per unit.

Announced Quarterly Distribution

On January 21, 2016, the Partnership announced a cash distribution of $0.525 per unit on its common and subordinated units. The distribution will be paid on February 12, 2016 to unitholders of record as of the close of business on February 2, 2016. USA Compression Holdings, the owner of approximately 41% of the Partnership’s outstanding limited partner interests has elected to reinvest all of this distribution with respect to its units pursuant to the Partnership’s distribution reinvestment plan (the “DRIP”).

Dividend Reinvestment Program

For the years ended December 31, 2015, 2014 and 2013, distributions of $56.9 million, $51.7 million and $26.3 million, respectively, were reinvested under the DRIP resulting in the issuance of 3.1 million, 2.1 million and 1.1 million common units, respectively.  Such distributions are treated as non-cash transactions in the accompanying Consolidated Statements of Cash Flows.

Equity Offerings

On September 15, 2015, the Partnership closed a public offering of 4,000,000 common units at a price to the public of $19.33 per common unit.  The Partnership used the net proceeds of $74.4 million (net of underwriting discounts and commission and offering expenses) to reduce the indebtedness outstanding under its revolving credit facility.

On May 21, 2015, the Partnership issued 34,921 common units in a private placement to Argonaut for $0.7 million in a transaction that was exempt from registration under Section 4(a)(2) of the Securities Act. The Partnership used the proceeds from the private placement for general partnership purposes.  There were no other unregistered sales of securities during the years ended December 31, 2015 or 2014.

On May 19, 2014, the Partnership closed a public offering of 6,600,000 common units, of which 5,600,000 common units were sold by the Partnership and 1,000,000 common units were sold by certain selling unitholders, including USA Compression Holdings and Argonaut (the “Selling Unitholders”), at a price to the public of $25.59 per common unit. USA Compression Holdings and Argonaut granted the underwriters an option to purchase up to an additional 990,000 common units to cover over-allotments, which was exercised by the underwriters in full and closed on May 27, 2014. The Partnership used the net proceeds of $138.0 million (net of underwriting discounts and commissions and offering expenses) to reduce the indebtedness outstanding under the revolving credit facility.

On April 23, 2014, the Partnership’s registration statement on Form S-3 (Reg. No. 333-193724) (as amended, the “Shelf Registration Statement”) was declared effective by the Securities and Exchange Commission. Under the Shelf Registration Statement, the Partnership registered the offer and sale of (1) up to $1.0 billion aggregate principal amount of Partnership securities, including common units and other classes of units representing limited partner interests in the Partnership, debt securities and guarantees of debt securities and (2) up to 27,074,118 common units held by certain selling unitholders and up to 6,266,024 common units that may be issued to such selling unitholders under the Partnership’s DRIP.

Earnings Per Common and Subordinated Unit

The computations of earnings per common unit and subordinated unit are based on the weighted average number of common units and subordinated units, respectively, outstanding during the applicable period. The subordinated units and the General Partner’s Interest (including its IDRs) meet the definition of participating securities as defined by the FASB’s ASC Topic 260 Earnings Per Share; therefore, the Partnership is required to use the two-class method in the computation of earnings per unit. Basic earnings per common and subordinated unit are determined by dividing net income (loss) allocated to the common and subordinated units, respectively, after deducting the amount allocated to the General Partner (including distributions to the General Partner on the General Partner Interest and its IDRs), by the weighted average number of outstanding common and subordinated units, respectively, during the period. Net income (loss) is allocated to the common units, subordinated units and the General Partner Interest (including its IDRs) based on their respective shares of the distributed and undistributed earnings for the period. To the extent cash distributions exceed net income (loss) for the period, the excess distributions are allocated to all participating units outstanding based on their respective ownership percentages. Diluted earnings per unit are computed using the treasury stock method, which considers the potential issuance of limited partner units associated with the LTIP. Unvested phantom units are not included in basic earnings per unit, as they are liability classified and as such are not considered to be participating securities, but are included in the calculation of diluted earnings per unit.  For the year ended December 31, 2015, approximately 121,000incremental phantom units were excluded from the calculation of diluted units because the impact was anti-dilutive.

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Employee Benefit Plans

12 Months Ended

Dec. 31, 2014

Employee Benefit Plans

Employee Benefit Plans

(11)  Employee Benefit Plans

A 401(k) plan is available to all of the Partnership’s current employees. The plan permits employees to make contributions up to 20% of their salary, up to statutory limits, which was $18,000 in 2015. The plan provides for discretionary matching contributions by the Partnership on an annual basis. Aggregate matching contributions made by the Partnership were $0.8 million, $0.7 million and $0.6 million for the years ended December 31, 2015, 2014 and 2013, respectively.

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Unit-based Compensation

12 Months Ended

Dec. 31, 2015

Unit-based Compensation

Unit-based Compensation

(10)  Unit-Based Compensation

Class B Units

During 2011 and 2013, USA Compression Holdings issued to certain employees and members of its management, who provide services to the Partnership, Class B non-voting units. These Class B units are liability-classified profits interest awards which have a service condition.

The holders of Class B units in USA Compression Holdings are entitled to a cash payment of 10% of net proceeds primarily from a monetization event, as defined under the provisions of the Amended and Restated Limited Liability Company Agreement of USA Compression Holdings, or the Holdings Operating Agreement, related to these Class B unit awards, in excess of USA Compression Holdings’ Class A unitholder’s capital contributions and an 8% return on each Class A unitholder’s capital account, compounded annually, (both of which are due upon a monetization event) to the extent of vested units over total units of the respective class. Each holder of Class B units is then allocated their pro-rata share of the respective class of unit’s entitlement based on the number of units held over the total number of units in that class of units. The Class B units vest 25% on the first anniversary date of the grant date and then monthly for the next three years (at the rate of 1/48 per month) subject to certain continued employment. The units have no expiry date provided the employee remains employed with USA Compression Holdings or one of its subsidiaries.

The Class B units vesting schedule consisted of the following at December 31 (in thousands, except unit amounts):

	Class B Interest Units
					Unit-based
	Grant date fair				compensation
	value per unit		Vested	Unvested	expense
Balance of awards as of December 31, 2012			570,313	617,187
Issuance of profit interest units	$	—	—	187,500
Vesting			531,250	(531,250)
Forfeitures			(62,500)	(62,500)
Balance of awards as of December 31, 2013			1,039,063	210,937
Expense recorded in 2013					$	—
Issuance of profit interest units	$	—	—	—
Vesting			80,078	(80,078)
Forfeitures			—	—
Balance of awards as of December 31, 2014			1,119,141	130,859
Expense recorded in 2014					$	—
Issuance of profit interest units	$	—	—	—
Vesting			42,968	(42,968)
Forfeitures			(125,000)	—
Balance of awards as of December 31, 2015			1,037,109	87,891
Expense recorded in 2015					$	—

Fair value of the Class B units is based on enterprise value calculated by a predetermined formula. As of December 31, 2015 and 2014, there was no unit-based compensation expense or liability recorded related to these Class B units.

The Partnership’s initial public offering constituted a qualified public offering for purposes of certain vesting provisions of the employee holder’s Class B Units, which resulted in 50% of certain employee’s unvested Class B Units vesting.  Any remaining unvested Class B Units generally (i) vest 25% percent on the first anniversary date of the grant date and (ii) with respect to the remaining Class B Units, will vest monthly for the next three years (at the rate of 1/48 per month) subject to the employee’s continued employment on each applicable vesting date. If any employee holder’s employment is terminated by the General Partner without cause or the employee resigns for good reason, the remaining unvested Class B Units will vest in full. As used in the Holdings Operating Agreement, “good reason” and “cause” have the meanings set forth in each employee’s employment agreement.

Long-Term Incentive Plan

In connection with the Partnership’s initial public offering, the board of directors of the General Partner (the “Board”) adopted the LTIP for employees, consultants and directors of the General Partner and any of its affiliates who perform services for the Partnership. The LTIP consists of unit options, unit appreciation rights, restricted units, phantom units, DERs, unit awards, profits interest units and other unit-based awards. The LTIP initially limits the number of common units that may be delivered pursuant to awards under the plan to 1,410,000 common units. Awards that are forfeited, cancelled, paid or otherwise terminate or expire without the actual delivery of units will be available for delivery pursuant to other awards. The LTIP is administered by the Board or a committee thereof.

In February 2014, the Board approved a modification to all of the phantom unit awards that were granted to employees pursuant to the LTIP during the 2013 fiscal year. The modification provided all employees with phantom unit awards granted during 2013 with an option of settling a portion of their award in cash and a portion in units.  The amount that can be settled in cash is in excess of the employee’s minimum statutory tax-withholding rate.  ASC Topic 718, Compensation-Stock Compensation, requires the entire amount of an award with such features to be accounted for as a liability.  Liability accounting requires the Partnership to re-measure the fair value of the award at each financial statement date until the award is vested or cancelled.  The fair value is re-measured at the end of each reporting period using the market price of the common units.  During the requisite service period, compensation cost is recognized using the proportionate amount of the award’s fair value that has been earned through service to date. The total incremental compensation cost recorded in February 2014 as a result of the modification was $1.2 million.

During the years ended December 31, 2015 and 2014, an aggregate of 320,636 and 187,856, respectively, phantom units (including the corresponding DERs) were granted under the LTIP to the General Partner’s executive officers and employees and independent directors. The phantom units granted in 2015 and 2014 provide the employees with an option of settling a portion of their award in cash and a portion in units. The phantom units (including the corresponding DERs) awarded are subject to restrictions on transferability, customary forfeiture provisions and time vesting provisions generally in which, for employees, one-third of each award vests on the first, second, and third anniversaries of the date of grant. The phantom units will generally vest in full in the event of a change in control and a termination of employment.  Grants of phantom units to the independent directors of the General Partner generally vest in full on the one year anniversary of the grant date. Award recipients do not have all the rights of a unitholder in the partnership with respect to the phantom units until the units have vested. Phantom units granted to employees during the years ended December 31, 2015 and 2014 are accounted for as a liability and are re-measured at the end of each reporting period using the market price of the common units. As of December 31, 2015 and 2014, the total unit-based compensation liability was $2.0 million and $1.3 million, respectively.  Phantom units granted to independent directors do not have the cash settlement option and as such are subject to equity treatment.  During the requisite service period, compensation cost is recognized using the proportionate amount of the award’s fair value that has been earned through service to date.

The General Partner’s executive officers, employees and independent directors were granted these awards to incentivize them to help drive the Partnership’s future success and to share in the economic benefits of that success. The compensation costs associated with these awards are recorded in selling, general and administrative expense. During the years ended December 31, 2015, 2014 and 2013, the Partnership recognized $3.9 million, $3.0 million and $1.3 million, respectively, of compensation expense associated with these awards, net of expense related to forfeited units. During the years ended December 31, 2015 and 2014, amounts paid by the Partnership for income tax withholdings related to the vesting of awards under the LTIP were $0.2 million in each year and the value of phantom units that vested and were redeemed by the Partnership for cash was immaterial and$0.1 million, respectively.  During the year ended December 31, 2013, no employee awards under the LTIP plan vested.  The total fair value and intrinsic value of the phantom units vested under the LTIP was $2.2 million, $2.4 million, and $0.1 million during the years ended December 31, 2015, 2014 and 2013, respectively. 

The following table summarizes information regarding phantom unit awards for the periods presented:

		Weighted-Average
		Grant Date Fair
	Number of Units	Value per Unit(1)
Phantom units outstanding at December 31, 2012	—	$	—
Granted	269,521		19.96
Vested	3,816		19.65
Forfeited	35,714		19.60
Phantom units outstanding at December 31, 2013	229,991	$	20.02
Granted	187,856		26.29
Vested	88,707		17.20
Forfeited	60,038		18.81
Phantom units outstanding at December 31, 2014	269,102	$	23.65
Granted	320,636		19.04
Vested	111,991		22.96
Forfeited	20,666		21.77
Phantom units outstanding at December 31, 2015	457,081	$	22.10

(1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

The unrecognized compensation cost associated with phantom unit awards was an aggregate $3.6 million as of December 31, 2015. The Partnership expects to recognize the unrecognized compensation cost for these awards on a weighted-average basis over a period of 1.7 years.

Each phantom unit granted to an independent director is granted in tandem with a corresponding DER, which shall remain outstanding and unpaid from the grant date until the earlier of the payment or forfeiture of the related phantom units. Each vested DER shall entitle the participant to receive payments in the amount equal to any distributions made by the Partnership following the grant date in respect of the common unit underlying the phantom unit to which such DER relates. Accumulated but unpaid DERs are never paid if the underlying phantom unit award is forfeited.

Each phantom unit granted to an executive officer or an employee is granted in tandem with a corresponding DER, which is paid quarterly on the distribution date from the grant date until the earlier of the settlement or the forfeiture of the related phantom units.

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Transactions with Related Parties

12 Months Ended

Dec. 31, 2015

Transactions with Related Parties

Transactions with Related Parties

(12)  Transactions with Related Parties

William Shea, Jr., who has served as a director of the General Partner since June 2011, served as Chief Executive Officer of the general partner of a customer from March 2010 to March 2014. For the years ended December 31, 2014 and 2013, subsidiaries of this customer made compression service payments to us of approximately $0.6 million and $3.0 million, respectively.

John Chandler, who has served as a director of the General Partner since October 2013, has served as a director of a customer since October 2014. During the year ended December 31, 2015 and the period of Mr. Chandler’s appointment for the year ended December 31, 2014, the Partnership recognized approximately $8.8 million and $1.7 million, respectively, in revenue on compression services and $1.3 million and $0.1 million, respectively, in accounts receivable from this customer on the Consolidated Balance Sheets as of December 31, 2015 and 2014.

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Recent Accounting Pronouncement

12 Months Ended

Dec. 31, 2015

Recent Accounting Pronouncement

Recent Accounting Pronouncement

(13)Recent Accounting Pronouncements

In April 2015, the FASB issued an Accounting Standards Update (“ASU”) that clarified when fees paid in a cloud computing arrangement pertain to the acquisition of a software license and/or services.  When a cloud computing arrangement includes a license of software, the fee attributable to the software license portion of the arrangement will be capitalized when the criteria for capitalization of internal-use software are met.  When a cloud computing arrangement does not include a license of software, the arrangement will be treated as a service contract and the cost will be expensed as the services are received.  This ASU is effective for annual and interim periods in fiscal years beginning after December 15, 2015. Early adoption is permitted and entities may elect to adopt this ASU either prospectively, for all arrangements entered into or materially modified after the effective date, or retrospectively. The Partnership concluded this ASU will not have a material impact on its consolidated financial statements.

In July 2015, the FASB agreed to defer by one year the mandatory effective date of its revenue recognition standard to annual and interim periods in fiscal years beginning after December 15, 2017, but will also provide entities the option to adopt it as of the original effective date. The option to use either a retrospective or cumulative-effect transition method will not change.  The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

Also in July 2015, the FASB issued an ASU that changes the measurement principle for inventory from the lower of cost or market to the lower of cost and net realizable value.  This ASU requires prospective adoption for inventory measurements for annual and interim periods in fiscal years beginning after December 15, 2016. Early adoption is permitted. The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

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Commitments and Contingencies

12 Months Ended

Dec. 31, 2015

Commitments and Contingencies

Commitments and Contingencies

(14)  Commitments and Contingencies

(a) Operating Leases

Rent expense for office space, warehouse facilities and certain corporate equipment for the years ended December 31, 2015, 2014 and 2013 was $2.9 million, $2.3 million and $1.6 million, respectively. Commitments for future minimum lease payments for non-cancelable leases are as follows (in thousands):

2016	$	1,645
2017		1,460
2018		1,160
2019		1,028
2020		27
Thereafter		—
Total	$	5,320

(b) Major Customers

The Partnership did not have revenue from any single customer greater than 10% of total revenue for the year ended December 31, 2015. The Partnership had revenue from one customer representing11.6% and 14.3% of total revenue for the years ended December 31, 2014 and 2013, respectively.  No other customer represented greater than 10% of revenue for the years ended December 31, 2014 and 2013.

(c) Litigation

From time to time, the Partnership and its subsidiaries may be involved in various claims and litigation arising in the ordinary course of business. In management’s opinion, the resolution of such matters is not expected to have a material adverse effect on the Partnership’s consolidated financial position, results of operations or cash flows.

(d) Equipment Purchase Commitments

The Partnership’s future capital commitments are comprised of binding commitments under purchase orders for new compression units ordered but not received. The commitments as of December 31, 2015 were $20.8 million, all of which are expected to be settled within the next twelve months.

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Subsequent Event

12 Months Ended

Dec. 31, 2015

Subsequent Events

Subsequent Event

(15)   Subsequent Events

Phantom Units

On February 9, 2016, an aggregate of 36,361 phantom units (including the corresponding DERs) were granted under the LTIP to the independent directors of the Partnership’s General Partner.  The phantom units (including the corresponding DERs) awarded are subject to restrictions on transferability, customary forfeiture provisions and will vest in full on February 15, 2017.

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Summary of Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2015

Summary of Significant Accounting Policies

Cash and Cash Equivalents

(a)Cash and Cash Equivalents

Cash and cash equivalents consist of all cash balances. The Partnership considers investments in highly liquid financial instruments purchased with an original maturity of 90 days or less to be cash equivalents. 

Trade Accounts Receivable

(b)Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $2.1 million and $0.4 million as of December 31, 2015 and 2014, respectively, is the Partnership’s best estimate of the amount of probable credit losses in the Partnership’s existing accounts receivable. Bad debt expense for the year ended December 31, 2015 was $1.8 million.  The determination of the allowance for doubtful accounts requires us to make estimates and judgments regarding our customers’ ability to pay amounts due.  The Partnership determines the allowance based upon historical write-off experience, specific customer circumstances and the overall business climate in which our customers operate. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

Inventories

(c)Inventories

Inventory consists of serialized and non-serialized parts used primarily in the repair of compression units. Serialized parts inventories are valued at the lower of cost or market value using the specific identification method, while non-serialized parts inventory is valued using the weighted average cost method. Purchases of these assets are considered operating activities in the consolidated statement of cash flows. 

Significant components of inventories as of December 31, 2015 and 2014 are as follows (in thousands):

	2015		2014
Serialized parts	$	18,361	$	9,286
Non-serialized parts		825		—
Total Inventory, gross		19,186		9,286
Less: obsolete and slow moving reserve		(314)		(363)
Total Inventory, net	$	18,872	$	8,923

Property and Equipment

(d)Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compression equipment are capitalized and depreciated over 3 to 5 years. Ordinary maintenance and repairs are charged to cost of operations, exclusive of depreciation and amortization. Depreciation is calculated using the straight-line method over the estimated useful lives of the assets as follows:

Compression equipment	25years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

Depreciation expense for the years ended December 31, 2015, 2014 and 2013 was $81.7 million, $67.6 million and $49.7 million, respectively.

Impairments of Long-Lived Assets

(e)Impairments of Long-Lived Assets

Long-lived assets with recorded values that are not expected to be recovered through future cash flows are written-down to estimated fair value. An asset shall be tested for impairment when events or circumstances indicate that its carrying value may not be recoverable or will no longer be utilized in the operating fleet. The carrying value of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If the carrying value exceeds the sum of the undiscounted cash flows associated with the operating fleet, an impairment loss equal to the amount of the carrying value exceeding the fair value of the asset is recognized. The fair value of the asset is measured using quoted market prices or, in the absence of quoted market prices, is based on an estimate of discounted cash flows, the expected net sale proceeds compared to the other similarly configured fleet units the Partnership recently sold or a review of other units recently offered for sale by third parties, or the estimated component value of the equipment the Partnership plans to use.   

Refer to Note 4 for more detailed information about impairment charges during the years ended December 31, 2015 and 2014.

Revenue Recognition

(f)Revenue Recognition

Revenue from contract operations is recorded when earned over the period of the contract, which generally ranges from one month to five years. Parts and service revenue is recorded as parts are delivered or services are performed for the customer.

Income Taxes

(g)Income Taxes

The Partnership elected to be treated under SubChapter K of the Internal Revenue Code. Under SubChapter K, a partnership return is filed annually reflecting each partner’s allocable share of the partnership’s income or loss. Therefore, no provision has been made for federal income tax. Partnership net income (loss) is allocated to the partners in proportion to their respective interest in the Partnership.

As a partnership, all income, gains, losses, expenses, deductions and tax credits generated by the Partnership generally flow through to its unitholders. However, Texas imposes an entity-level income tax on partnerships.

Refer to Note 7 for more detailed information about the Revised Texas Franchise Tax for the years ended December 31, 2015, 2014 and 2013.

Fair Value Measurements

(h)Fair Value Measurements

Accounting standards on fair value measurements establish a framework for measuring fair value and stipulate disclosures about fair value measurements. The standards apply to recurring and nonrecurring financial and non-financial assets and liabilities that require or permit fair value measurements. Among the required disclosures is the fair value hierarchy of inputs the Partnership uses to value an asset or a liability. The three levels of the fair value hierarchy are described as follows:

Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the Partnership has the ability to access at the measurement date.

Level 2 inputs are those other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly.

Level 3 inputs are unobservable inputs for the asset or liability.

As of December 31, 2015 and 2014, the Partnership’s financial instruments consisted primarily of cash and cash equivalents, trade accounts receivable, trade accounts payable and long-term debt. The book values of cash and cash equivalents, trade accounts receivable, and trade accounts payable are representative of fair value due to their short-term maturity. The carrying amount of long-term debt approximates fair value due to the floating interest rates associated with the debt.

Phantom unit awards granted to employees under the USA Compression Partners, LP 2013 Long-Term Incentive Plan (the “LTIP”) are accounted for as a liability, and such liability is re-measured on a quarterly basis.  The liability is based on the publicly quoted price of the Partnership’s common units, which is considered a Level 1 input.  Refer to Note 10 for more detailed information about unit-based compensation for the years ended December 31, 2015, 2014 and 2013.

As part of the impairment analysis of goodwill, the fair value of the Partnership’s goodwill was re-measured using Level 3 inputs.  Refer to the Goodwill section of Note 2 below for more detailed information about the valuation as of December 31, 2015 and 2014.

Pass Through Taxes

(i)Pass Through Taxes

Sales taxes incurred on behalf of, and passed through to, customers are accounted for on a net basis.

Use of Estimates

(j)Use of Estimates

The preparation of the consolidated financial statements of the Partnership in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires the management of the Partnership to make estimates and assumptions that affect the amounts reported in these consolidated financial statements and the accompanying results. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could differ from these estimates.

Identifiable Intangible Assets

(k)Identifiable Intangible Assets

As of December 31, 2015, identifiable intangible assets consisted of the following (in thousands):

	Customer
	Relationships		Trade Names		Non-compete		Total
Gross Balance at December 31, 2013	$	78,700		15,600		900	$	95,200
Additions		—		—		—		—
Accumulated amortization		(10,047)		(2,496)		(300)		(12,843)
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Gross Balance at December 31, 2014		78,700		15,600		900		95,200
Additions		—		—		—		—
Accumulated amortization		(12,782)		(3,120)		(525)		(16,427)
Net Balance at December 31, 2015	$	65,918	$	12,480	$	375	$	78,773

Identifiable intangible assets are amortized using the straight-line method over their estimated useful lives, which is the period over which the assets are expected to contribute directly or indirectly to the Partnership’s future cash flows. The estimated useful lives range from 4 to 30 years. Amortization expense for the years ended December 31, 2015, 2014 and 2013 was $3.6 million, $3.6 million and $3.2 million, respectively.  The expected amortization of the identifiable intangible assets for each of the five succeeding years is as follows (in thousands):

Year ending December 31,	Total
2016	$	3,584
2017		3,509
2018		3,359
2019		3,359
2020		3,359

The Partnership assesses identifiable intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The Partnership did not record any impairment of identifiable intangible assets in the years ended December 31, 2015,  2014 or 2013.

Goodwill

(l)Goodwill

Goodwill represents consideration paid in excess of the fair value of the identifiable net assets acquired in a business combination. Goodwill is not amortized, but is reviewed for impairment annually based on the carrying values as of October 1, or more frequently if impairment indicators arise that suggest the carrying value of goodwill may not be recovered.

As of October 1, 2015, a quantitative assessment was performed to determine whether the fair value of the Partnership’s single reporting unit was greater than its carrying value.  As of October 1, 2015, the fair value was determined to be in excess of the carrying value. Due to the identification of certain impairment indicators during the fourth quarter of 2015, specifically (1) the decline in the market price of the Partnership’s common units, (2) the sustained decline in global commodity prices, and (3) the decline in performance of the Alerian MLP Index, the Partnership prepared a quantitative assessment as of December 31, 2015.  This assessment indicated that the calculated fair value was less than the carrying value.  As such, the Partnership prepared a Step 2 impairment test which measures the amount of the impairment loss and involves a hypothetical allocation of the estimated fair value of the reporting unit among all assets and liabilities of the reporting unit.  The carrying value of goodwill exceeded the implied value of goodwill and an impairment charge was recorded for $172.2 million.  The fair value of our single reporting unit was calculated using the Discounted Cash Flow Method, an income approach.  This method utilizes Level 3 inputs from the fair value hierarchy. The impairment of goodwill is primarily the result of the sustained decline in the market price of the Partnership’s common units.  The continued decline in commodity prices has adversely impacted many of the Partnership’s customers and resulted in a significant decline in their future capital expansion plans.  This has in turn reduced the Partnership’s expected future capital expansion plans and in turn, the Partnership’s estimated future cash flows. 

The Partnership had approximately $35.9 million of goodwill remaining on the balance sheet as of December 31, 2015.No impairment of goodwill was recorded in the years ended December 31, 2014 and 2013.

Capitalized Interest

m)Capitalized Interest

For each of the years ended December 31, 2015 and 2014, the Partnership capitalized $0.3 million of interest expense in accordance with Accounting Standards Codification (“ASC”) Topic 835-20 for interest costs incurred during the period related to upfront payments required in acquiring certain compression units.  The Partnership capitalized no interest during the year ended December 31, 2013.

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Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2015

Summary of Significant Accounting Policies

Significant components of inventories

Significant components of inventories as of December 31, 2015 and 2014 are as follows (in thousands):

	2015		2014
Serialized parts	$	18,361	$	9,286
Non-serialized parts		825		—
Total Inventory, gross		19,186		9,286
Less: obsolete and slow moving reserve		(314)		(363)
Total Inventory, net	$	18,872	$	8,923

Schedule of estimated useful lives of assets

Compression equipment	25years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

Schedule of identifiable intangible assets

As of December 31, 2015, identifiable intangible assets consisted of the following (in thousands):

	Customer
	Relationships		Trade Names		Non-compete		Total
Gross Balance at December 31, 2013	$	78,700		15,600		900	$	95,200
Additions		—		—		—		—
Accumulated amortization		(10,047)		(2,496)		(300)		(12,843)
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Gross Balance at December 31, 2014		78,700		15,600		900		95,200
Additions		—		—		—		—
Accumulated amortization		(12,782)		(3,120)		(525)		(16,427)
Net Balance at December 31, 2015	$	65,918	$	12,480	$	375	$	78,773

Schedule of expected amortization of the intangible assets for each of the five succeeding years

The expected amortization of the identifiable intangible assets for each of the five succeeding years is as follows (in thousands):

Year ending December 31,	Total
2016	$	3,584
2017		3,509
2018		3,359
2019		3,359
2020		3,359

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Acquisitions (Tables)

12 Months Ended

Dec. 31, 2015

Acquisitions

Schedule of purchase price allocation (in thousands)

Issuance of limited partner units	$	181,919
Less cash received for working capital adjustment		(3,374)
Total consideration	$	178,545
Trucks and Trailers	$	2,158
Compression equipment		117,784
Computers		23
Intangibles
Customer relationships		6,700
Non-compete		900
Total intangibles		7,600
Goodwill		50,980
Allocation of Purchase Consideration	$	178,545

Summary of pro forma financial information (in thousands, except dollars per share)

	Year Ended December 31,
	2013
	(unaudited)
Total revenues	$	176,254
Net income		15,919
Net income allocated to:
General partner’s interest in net income		318
Limited partner’s interest in net income:
Common units		10,054
Subordinated units		5,546
Basic and diluted net income per common unit	$	0.39
Basic and diluted net income per subordinated unit	$	0.39

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Property and Equipment (Tables)

12 Months Ended

Dec. 31, 2015

Property and Equipment

Schedule of property and equipment (in thousands)

	2015		2014
Compression equipment	$	1,520,835	$	1,311,943
Furniture and fixtures		669		619
Automobiles and vehicles		19,284		17,303
Computer equipment		21,457		11,913
Leasehold improvements		1,197		858
Total Property and equipment, gross		1,563,442		1,342,636
Less: accumulated depreciation and amortization		(245,399)		(179,999)
Total Property and equipment, net	$	1,318,043	$	1,162,637

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Income Tax Expense (Tables)

12 Months Ended

Dec. 31, 2015

Income Tax Expense Disclosure Abstract

Schedule of Components of Income Tax Expense (Benefit)

Components of income tax expense are as follows (in thousands):

	2015		2014		2013
Current tax expense:
State income tax	$	211	$	103	$	280
Total current tax expense		211		103		280
Deferred tax expense:
State income tax	$	874	$	—	$	—
Total deferred tax expense		874		—		—
Total income tax expense	$	1,085	$	103	$	280

Schedule of tax effects of temporary differences that gave rise to deferred tax liabilities

The tax effects of temporary differences that give rise to deferred tax liabilities are as follows (in thousands):

	2015		2014
Deferred tax liabilities
Property and equipment	$	874	$	—
Total deferred tax liabilities		874		—
Net deferred tax liabilities	$	874	$	—

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Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2015

Long-Term Debt

Schedule of long-term debt of the Partnership (in thousands)

	2015		2014
Revolving Credit Facility	$	729,187	$	594,864

Schedule of maturities of long term debt (in thousands)

Year ending December 31,
2016		—
2017		—
2018		—
2019		—
2020		729,187
Total Debt	$	729,187

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Partners' Capital (Tables)

12 Months Ended

Dec. 31, 2015

Partners' Capital.

Schedule of cash distributions (in millions, except distribution per unit)

	Distribution per			Amount Paid to		Amount Paid to		Amount Paid to		Amount Paid to
	Limited Partner			Common		Subordinated		General		Phantom		Total
Payment Date	Unit			Unitholders		Unitholder		Partner		Unitholders		Distribution
May 15, 2013	$	0.348	(1)	$	5.2	$	4.9	$	0.2	$	—	$	10.3
August 14, 2013		0.440			6.7		6.2		0.3		—		13.2
November 14, 2013		0.460			10.6		6.5		0.3		—		17.4
February 14, 2014		0.480			11.3		6.7		0.4		—		18.4
May 15, 2014		0.490			11.8		6.9		0.4		0.2		19.3
August 14, 2014		0.500			15.1		7.0		0.5		0.2		22.8
November 14, 2014		0.505			15.5		7.1		0.5		0.2		23.3
February 13, 2015		0.510			16.0		7.2		0.5		0.1		23.8
May 15, 2015		0.515			16.6		7.2		0.6		0.2		24.6
August 14, 2015		0.525			17.2		7.4		0.7		0.2		25.5
November 13, 2015		0.525			19.7		7.4		0.7		0.2		28.0

(1) Prorated to reflect 72 days of quarterly cash distribution rate of $0.435 per unit.

Announced Quarterly Distribution

Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner

		Marginal Percentage Interest in
	Total Quarterly	Distributions
	Distributions per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.54	%	1.46	%
First Target Distribution	up to $0.4888	98.54	%	1.46	%
Second Target Distribution	above $0.4888 up to $0.5313	85.54	%	14.46	%
Third Target Distribution	above $0.5313 up to $0.6375	75.54	%	24.46	%
Thereafter	above $0.6375	50.54	%	49.46	%

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Unit-based Compensation (Tables)

12 Months Ended

Dec. 31, 2015

Unit-based Compensation

Schedule of Class B units activity (in thousands, except unit amounts)

	Class B Interest Units
					Unit-based
	Grant date fair				compensation
	value per unit		Vested	Unvested	expense
Balance of awards as of December 31, 2012			570,313	617,187
Issuance of profit interest units	$	—	—	187,500
Vesting			531,250	(531,250)
Forfeitures			(62,500)	(62,500)
Balance of awards as of December 31, 2013			1,039,063	210,937
Expense recorded in 2013					$	—
Issuance of profit interest units	$	—	—	—
Vesting			80,078	(80,078)
Forfeitures			—	—
Balance of awards as of December 31, 2014			1,119,141	130,859
Expense recorded in 2014					$	—
Issuance of profit interest units	$	—	—	—
Vesting			42,968	(42,968)
Forfeitures			(125,000)	—
Balance of awards as of December 31, 2015			1,037,109	87,891
Expense recorded in 2015					$	—

Summary of information regarding phantom unit awards

		Weighted-Average
		Grant Date Fair
	Number of Units	Value per Unit(1)
Phantom units outstanding at December 31, 2012	—	$	—
Granted	269,521		19.96
Vested	3,816		19.65
Forfeited	35,714		19.60
Phantom units outstanding at December 31, 2013	229,991	$	20.02
Granted	187,856		26.29
Vested	88,707		17.20
Forfeited	60,038		18.81
Phantom units outstanding at December 31, 2014	269,102	$	23.65
Granted	320,636		19.04
Vested	111,991		22.96
Forfeited	20,666		21.77
Phantom units outstanding at December 31, 2015	457,081	$	22.10

(1) Determined by dividing the aggregate grant date fair value of awards by the number of awards issued.

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Commitments and Contingencies (Tables)

12 Months Ended

Dec. 31, 2015

Commitments and Contingencies

Schedule of commitments for future minimum lease payments on noncancelable leases (in thousands)

2016	$	1,645
2017		1,460
2018		1,160
2019		1,028
2020		27
Thereafter		—
Total	$	5,320

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The Partnership, Nature of Business, and Recent Transactions (Details) - USD ($) $ / shares in Units, $ in Thousands					12 Months Ended
	Sep. 15, 2015	May. 21, 2015	May. 19, 2014	Aug. 30, 2013	Dec. 31, 2013
The partnership, nature of business, and recent transactions
Issuance of units in common units in initial public offering (in units)	4,000,000	34,921	5,600,000
Issuance of units in public offering (in dollars per unit)	$ 19.33
Net proceeds from issuance of common units	$ 74,400	$ 700	$ 138,000		$ 180,555
S&R
The partnership, nature of business, and recent transactions
Value of common units issued in exchange for contribution of assets				$ 181,919
Common units
The partnership, nature of business, and recent transactions
Issuance of units in public offering (in dollars per unit)			$ 25.59
Common units | S&R
The partnership, nature of business, and recent transactions
Number of common units issued in exchange for contribution of assets				7,425,261

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Summary of Significant Accounting Policies - Assets (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Trade accounts receivable
Allowance for doubtful accounts	$ 2,100	$ 400
Bad debt expense	1,800
Inventories
Serialized parts	18,361	9,286
Non-serialized parts	825
Total Inventory, gross	19,186	9,286
Less: obsolete and slow moving reserve	(314)	(363)
Total Inventory, net	$ 18,872	$ 8,923

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Summary of Significant Accounting Policies - Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property and equipment
Depreciation expense	$ 81,700	$ 67,600	$ 49,700
Impairments of Long-Lived Assets
Impairment of long-lived assets	$ 27,274	2,266	203
Overhauls and major improvements | Minimum
Property and equipment
Estimated useful lives	3 years
Overhauls and major improvements | Maximum
Property and equipment
Estimated useful lives	5 years
Compression equipment
Property and equipment
Estimated useful lives	25 years
Impairments of Long-Lived Assets
Impairment of long-lived assets	$ 27,300	$ 2,300	$ 200
Furniture and fixtures
Property and equipment
Estimated useful lives	7 years
Vehicles and computer equipment | Minimum
Property and equipment
Estimated useful lives	3 years
Vehicles and computer equipment | Maximum
Property and equipment
Estimated useful lives	7 years
Leasehold improvements
Property and equipment
Estimated useful lives	5 years

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Summary of Significant Accounting Policies - Revenue and Expense (Details)	12 Months Ended
	Dec. 31, 2015
Minimum
Revenue recognition
Contract revenues, period over which revenue is recorded when earned	1 month
Maximum
Revenue recognition
Contract revenues, period over which revenue is recorded when earned	5 years

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Summary of Significant Accounting Policies - Taxes (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income taxes
Provision for federal income tax	$ 0
Expense related to Texas margin tax	$ 1,085	$ 103	$ 280
Texas
Income taxes
Texas margin tax rate (as a percent)		1.00%
Texas margin tax, percent of total revenues that may be taxed	70.00%
Expense related to Texas margin tax	$ 1,100	$ 100	$ 300

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Summary of Significant Accounting Policies - Intangibles (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Identifiable intangible assets, net
Gross Carrying Amount		$ 95,200	$ 95,200
Accumulated Amortization	$ (16,427)	(12,843)
Net Balance	78,773	82,357
Amortization	(3,600)	(3,600)	(3,200)
Expected aggregate amortization expense of the intangible assets for each of the five succeeding years
2016	3,584
2017	3,509
2018	3,359
2019	3,359
2020	3,359
Impairment of intangible assets	0	0	0
Impairment of goodwill	172,200	0	0
Goodwill	35,866	208,055
Interest Costs Capitalized	$ 300	300	0
Minimum
Identifiable intangible assets, net
Finite-Lived Intangible Asset, Useful Life	4 years
Maximum
Identifiable intangible assets, net
Finite-Lived Intangible Asset, Useful Life	30 years
Customer Relationships
Identifiable intangible assets, net
Gross Carrying Amount		78,700	78,700
Accumulated Amortization	$ (12,782)	(10,047)
Net Balance	65,918	68,653
Trade Names
Identifiable intangible assets, net
Gross Carrying Amount		15,600	15,600
Accumulated Amortization	(3,120)	(2,496)
Net Balance	12,480	13,104
Non-compete
Identifiable intangible assets, net
Gross Carrying Amount		900	$ 900
Accumulated Amortization	(525)	(300)
Net Balance	$ 375	$ 600

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Acquisition (Details) - USD ($)		4 Months Ended	12 Months Ended
	Aug. 30, 2013	Dec. 31, 2013	Dec. 31, 2015	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014
Revenue, Net Income and Pro Forma Financial Information - Unaudited
Estimated incremental interest expense reductions due to payment of revolving credit facility				$ 90,000
Purchase price allocation
Goodwill			$ 35,866,000			$ 208,055,000
S&R
Cost of acquisition
Value of common units issued in exchange for contribution of assets	$ 181,919,000
Purchase price adjustment due to working capital changes	(3,374,000)
Total consideration	178,545,000
Expenses associated with acquisition activities and transaction activities		$ 2,100,000		2,100,000
Revenue, Net Income and Pro Forma Financial Information - Unaudited
Total revenues				176,254,000
Net income (loss)				15,919,000
Revenue		14,500,000
Direct operating expenses		4,400,000
SG & A		600,000
Depreciation and amortization		3,700,000
Net income (loss)		$ 5,800,000
Incremental revenue adjustments				27,100,000
Incremental operating costs				12,200,000
Incremental depreciation and amortization				9,700,000	$ 9,700,000
General partner interest (as a percent)			2.00%
Purchase price allocation
Total intangibles	7,600,000
Goodwill	50,980,000
Allocation of Purchase Consideration	178,545,000
Fair value of assets acquired	127,600,000
Incremental transaction expenses				2,100,000
S&R | Trucks and Trailers
Purchase price allocation
Plant, property and equipment	2,158,000
S&R | Compression equipment
Purchase price allocation
Plant, property and equipment	117,784,000
S&R | Computer equipment
Purchase price allocation
Plant, property and equipment	23,000
S&R | Customer Relationships
Purchase price allocation
Total intangibles	$ 6,700,000
Amortization period of identifiable intangible asset	20 years
S&R | Non-compete
Purchase price allocation
Total intangibles	$ 900,000
Amortization period of identifiable intangible asset	4 years
S&R | General partner units
Revenue, Net Income and Pro Forma Financial Information - Unaudited
Net income (loss)				318,000
S&R | Common units
Acquisition of compression assets
Number of common units issued in exchange for contribution of assets	7,425,261
Revenue, Net Income and Pro Forma Financial Information - Unaudited
Net income (loss)				$ 10,054,000
Basic and diluted net income (in dollars per unit)				$ 0.39
S&R | Subordinated units
Revenue, Net Income and Pro Forma Financial Information - Unaudited
Net income (loss)				$ 5,546,000
Basic and diluted net income (in dollars per unit)				$ 0.39

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Property and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property and Equipment
Property and Equipment, gross	$ 1,563,442	$ 1,342,636
Less accumulated depreciation and amortization	(245,399)	(179,999)
Property and Equipment, net	1,318,043	1,162,637
Compression equipment
Property and Equipment
Property and Equipment, gross	1,520,835	1,311,943
Furniture and fixtures
Property and Equipment
Property and Equipment, gross	669	619
Automobiles and vehicles
Property and Equipment
Property and Equipment, gross	19,284	17,303
Computer equipment
Property and Equipment
Property and Equipment, gross	21,457	11,913
Leasehold improvements
Property and Equipment
Property and Equipment, gross	$ 1,197	$ 858

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Property and Equipment - Additional Disclosures (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015 USD ($) item	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
Property and Equipment
Depreciation expense	$ 81,700	$ 67,600	$ 49,700
Transfers to inventory from property and equipment	4,000
Transfers from inventory to property and equipment	4,000
Impairment of long-lived assets	$ 27,274	2,266	203
Number of compressor units that are to be retired or sold or reutilized. | item	166
Number of horsepower units that are to be retired or sold or reutilized. | item	58,000
Compression equipment
Property and Equipment
Insurance Recoveries	$ 1,200
Impairment of long-lived assets	27,300	2,300	$ 200
Accounts payable and accrued liabilities
Property and Equipment
Purchases of property and equipment	$ 13,100	$ 32,400

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Installment Receivable (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Installment Receivable
Long-term installment receivable	$ 17,275	$ 20,241
Gain on sale of assets		2,686
Non-cash transfers from long-term installment receivable to current	3,000
Sales type lease | Superior Transaction
Installment Receivable
Installment receivable, current	3,000	2,800
Long-term installment receivable	$ 17,300	20,200
Gain on sale of assets		$ 2,600

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Accrued Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Accrued Liabilities
Accrued property taxes	$ 4.1	$ 4.8
Accrued Bonuses, Current	$ 7.1	$ 5.5

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Income Tax Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit), Continuing Operations [Abstract]
State income tax	$ 211	$ 103	$ 280
Total current tax expense	211	103	280
Deferred tax - State income tax	874
Total deferred tax expense	874
Total income tax expense	1,085	$ 103	$ 280
Components of Deferred Tax Liabilities [Abstract]
Property and equipment	874
Total deferred tax liabilities	874
Net deferred tax liabilities	$ 874

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Long-Term Debt (Details) - USD ($) $ in Thousands		12 Months Ended
	Dec. 13, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jan. 06, 2015
Long-term debt
Revolving Credit Facility		$ 729,187	$ 594,864
Long-term debt		729,187
Loan fees and incurred costs paid during period		$ 3,388	$ 961	$ 3,048
Effective interest rate (as a percent)		2.26%	2.16%
Debt, Weighted Average Interest Rate		2.24%	2.22%	2.43%
Letters of credit
Long-term debt
Letter of Credit outstanding amount		$ 0	$ 0
Period ending June 30, 2016
Long-term debt
Maximum Funded debt to EBITDA ratio			5.50
After June 30, 2016
Long-term debt
Maximum Funded debt to EBITDA ratio			5.00
Senior debt
Long-term debt
Long-term debt		729,187	$ 594,864
Maximum borrowing capacity under the credit agreement before amendment	$ 600,000				$ 850,000
Maximum borrowing capacity under the credit agreement after amendment	850,000				1,100,000
Loan fees and incurred costs paid during period		$ 3,400	$ 200	$ 3,000
Amount of further potential increase in maximum capacity	$ 100,000				$ 200,000
Minimum borrowing availability immediately after giving effect to distribution				20,000
Increase in maximum funded debt to EBITDA ratio in connection with certain future acquisitions		0.5
Consecutive period following the period in which any acquisition occurs for maintaining increased maximum funded debt to EBITDA ratio		6 months
Amount written off				$ 300
Borrowing capacity, subject to covenants		$ 101,000
Borrowing Base Availability		$ 370,800
Borrowing base percentage representing eligible compression units		91.00%	94.00%
Excess capacity, if below, entity is required to use remittances from customers to reduce borrowings under the facility		$ 20,000
Senior debt | Minimum
Long-term debt
Minimum EBITDA to interest coverage ratio		2.5
Senior debt | Maximum | Period ending December 31, 2014
Long-term debt
Maximum Funded debt to EBITDA ratio			5.50
Senior debt | Maximum | Period ending June 30, 2015
Long-term debt
Maximum Funded debt to EBITDA ratio		5.95
Senior debt | LIBOR | Minimum
Long-term debt
Applicable margin above reference rate (as a percent)	1.50%
Senior debt | LIBOR | Maximum
Long-term debt
Applicable margin above reference rate (as a percent)	2.25%

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Long-Term Debt - Future Maturities (Details) $ in Thousands	Dec. 31, 2015 USD ($)
Maturities of long term debt
2020	$ 729,187
Total Debt	$ 729,187

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Partners' Capital - Subordinated Units (Details)			12 Months Ended
	Feb. 09, 2016 shares	May. 15, 2013 $ / shares	Dec. 31, 2015 item $ / shares shares	Dec. 31, 2014 shares	Dec. 31, 2013 shares
Limited partner
Partners' Capital
Minimum Quarterly Distribution (in dollars per unit) | $ / shares		$ 0.435
Limited partner | Subordinated units
Partners' Capital
Partners' capital (in units) | shares			14,049,000	14,049,000	14,049,000
Limited partner | Common units
Partners' Capital
Partners' capital (in units) | shares			38,556,000	31,307,000	23,562,000
USA Compression Holdings, LLC | Subordinated units
Partners' Capital
Partners' capital (in units) | shares	14,048,588
USA Compression Holdings, LLC | Subordinated units | Minimum Quarterly Distribution
Partners' Capital
Minimum Quarterly Distribution (in dollars per unit) | $ / shares			$ 0.425
Minimum Quarterly Distribution annualized, level one (in dollars per unit) | $ / shares			$ 1.70
Number of consecutive, non-overlapping four-quarter periods | item			3
Minimum Quarterly Distribution annualized, level two (in dollars per unit) | $ / shares			$ 2.55
Minimum Quarterly Distribution annualized, level two (as a percent)			150.00%
Subordinated unit conversion basis to common units			1
USA Compression Holdings, LLC | Common units
Partners' Capital
Partners' capital (in units) | shares	7,267,511
USA Compression GP, LLC | General partner
Partners' Capital
General Partner, interest (as a percent)	1.46%

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Partners' Capital - Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands																	12 Months Ended
	Feb. 12, 2016	Jan. 21, 2016	Nov. 13, 2015	Sep. 15, 2015	Aug. 14, 2015	May. 21, 2015	May. 15, 2015	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	May. 19, 2014	May. 15, 2014	Feb. 14, 2014	Nov. 14, 2013	Aug. 14, 2013	May. 15, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash Distributions
Distribution per Limited Partner Unit (in dollars per share)			$ 0.525		$ 0.525		$ 0.515	$ 0.510	$ 0.505	$ 0.50		$ 0.49	$ 0.48	$ 0.46	$ 0.440	$ 0.348
Total Distribution			$ 28,000		$ 25,500		$ 24,600	$ 23,800	$ 23,300	$ 22,800		$ 19,300	$ 18,400	$ 17,400	$ 13,200	$ 10,300
Partners' capital account, units, sold in public offering				4,000,000		34,921					5,600,000
Partners' Capital Account, Public Sale of Units Net of Offering Costs				$ 74,400		$ 700					$ 138,000								$ 180,555
Non-cash distributions																	$ 56,895	$ 51,707	26,286
Proceeds from Issuance of Common Limited Partners Units																	$ 75,111	$ 138,047	$ 180,555
Number of common units issued under DRIP																	3,100,000	2,100,000	1,100,000
Cash Distributions
Cash Distributions
Non-cash distributions																	$ 56,900	$ 51,700	$ 26,300
Subordinated units
Cash Distributions
Limited partner units issued (in shares)																	14,048,588	14,048,588
Common units
Cash Distributions
Limited partner units issued (in shares)																	38,556,245	31,307,116
Phantom Unitholders | Cash Distributions
Cash Distributions
Total Distribution			200		200		200	100	200	200		200
Limited partner
Cash Distributions
Period for determining prorated quarterly cash distribution rate																72 days
Limited partner | Subordinated units | Cash Distributions
Cash Distributions
Total Distribution			7,400		7,400		7,200	7,200	7,100	7,000		6,900	6,700	6,500	6,200	$ 4,900
Limited partner | Common and Subordinated Units | Cash Distributions
Cash Distributions
Distribution per Limited Partner Unit (in dollars per share)	$ 0.525
Cash distribution announced per unit (in dollars per share)		$ 0.525
Limited partner | Common units
Cash Distributions
Partners' capital account, units, sold in public offering																			11,000,000
Partners' Capital Account, Public Sale of Units Net of Offering Costs																			$ 180,555
Limited partner | Common units | Cash Distributions
Cash Distributions
Total Distribution			19,700		17,200		16,600	16,000	15,500	15,100		11,800	11,300	10,600	6,700	5,200
General partner | Cash Distributions
Cash Distributions
Total Distribution			$ 700		$ 700		$ 600	$ 500	$ 500	$ 500		$ 400	$ 400	$ 300	$ 300	$ 200
USA Compression Holdings, LLC
Cash Distributions
Ownership interest (as a percent)																	41.00%

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Partners' Capital - Incentive Distribution Rights (Details) - Incentive Distribution Rights	12 Months Ended
	Dec. 31, 2015 $ / shares
Limited partner | Minimum Quarterly Distribution
Partners' Capital
Marginal percentage interest in distributions	98.54%
Limited partner | First Target Distribution
Partners' Capital
Marginal percentage interest in distributions	98.54%
Limited partner | Second Target Distribution
Partners' Capital
Marginal percentage interest in distributions	85.54%
Limited partner | Third Target Distribution
Partners' Capital
Marginal percentage interest in distributions	75.54%
Limited partner | Thereafter
Partners' Capital
Marginal percentage interest in distributions	50.54%
General partner | Minimum Quarterly Distribution
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.425
Marginal percentage interest in distributions	1.46%
General partner | First Target Distribution
Partners' Capital
Marginal percentage interest in distributions	1.46%
General partner | First Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.4888
General partner | Second Target Distribution
Partners' Capital
Marginal percentage interest in distributions	14.46%
General partner | Second Target Distribution | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.4888
General partner | Second Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.5313
General partner | Third Target Distribution
Partners' Capital
Marginal percentage interest in distributions	24.46%
General partner | Third Target Distribution | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.5313
General partner | Third Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.6375
General partner | Thereafter
Partners' Capital
Marginal percentage interest in distributions	49.46%
General partner | Thereafter | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.6375

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Partners' Capital - Equity Offering (Details) - USD ($) $ / shares in Units, $ in Thousands						12 Months Ended
	Sep. 15, 2015	May. 21, 2015	May. 27, 2014	May. 19, 2014	Apr. 23, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Equity Offering
Partnership capital registered for offer and sale					$ 1,000,000
Total Issuance of units in public offering (in units)				6,600,000
Issuance of units in common units in initial public offering (in units)	4,000,000	34,921		5,600,000
Issuance of units in public offering by Selling Unitholders (in units)				1,000,000
Issuance of units in public offering (in dollars per unit)	$ 19.33
Net proceeds from issuance of common units	$ 74,400	$ 700		$ 138,000				$ 180,555
Unregistered sale of securities						0	0
Phantom units
Equity Offering
Antidilutive units excluded from computation of earnings per share						121,000
Common units
Equity Offering
Number of common units held by certain selling unitholders authorized for sale					27,074,118
Number of common units authorized to be issued to selling unitholders under DRIP					6,266,024
Issuance of units in public offering (in dollars per unit)				$ 25.59
USA Compression Holdings, LLC
Equity Offering
Ownership interest (as a percent)						41.00%
USA Compression Holdings and Argonaut, LLC | Common units | Maximum
Equity Offering
Common units additionally authorized for purchase to cover over allotments			990,000

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Unit-based Compensation - Class B Units (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Class B Interest Units
Unvested
Percentage of certain employee's unit vesting at IPO	50.00%
Unit-based compensation expense
Expense recorded	$ 0.0
Class B Interest Units | USA Compression Holdings, LLC
Unit-based Compensation
Cash payment as a percentage of net proceeds from monetization event	10.00%
Annual vesting percentage	25.00%
Number of successive subsequent years in which awards will vest	3 years
Monthly vesting percentage	2.083%
Vested
Balance of awards at the beginning of period (in units)	1,119,141	1,039,063	570,313
Vesting (in units)	42,968	80,078	531,250
Forfeitures (in units)	(125,000)		(62,500)
Balance of awards at the end of period (in units)	1,037,109	1,119,141	1,039,063
Unvested
Balance of awards at the beginning of period (in units)	130,859	210,937	617,187
Issuance of profit interest units (in units)			187,500
Vesting (in units)	(42,968)	(80,078)	(531,250)
Forfeitures (in units)			(62,500)
Balance of awards at the end of period (in units)	87,891	130,859	210,937
Class A Interest Units | USA Compression Holdings, LLC
Unit-based Compensation
Class A cash payment as a percentage of net proceeds from monetization event	8.00%

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Unit-based Compensation - LTIP (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	12 Months Ended
	Feb. 28, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Weighted-Average Grant Date Fair Value per Unit
Cash paid for taxes related to net settlement of unit-based awards		$ 210	$ 334
Phantom units
Number of Units
Total unit-based compensation liability		2,000	1,300
Executive officers, employees and independent directors | Phantom units
Weighted-Average Grant Date Fair Value per Unit
Cash paid for taxes related to net settlement of unit-based awards			200
Value of phantom units that vested and were redeemed for cash			100
Total fair value and intrinsic value of the phantom units vested		$ 2,200	$ 2,400	$ 100
LTIP
Unit-based Compensation
Number of common units that may be delivered pursuant to awards under the plan		1,410,000
LTIP | Phantom units
Unit-based Compensation
Incremental compensation cost	$ 1,200
Number of Units
Granted (in units)		320,636	187,856	269,521
Vested (in units)		111,991	88,707	3,816
Forfeited (in units)		20,666	60,038	35,714
Phantom units outstanding at the end of the period (in units)		457,081	269,102	229,991
Percentage of award vesting on the first, second, and third anniversaries of the date of grant for employees		33.33%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number		457,081	269,102	229,991
Weighted-Average Grant Date Fair Value per Unit
Granted (in dollars per unit)		$ 19.04	$ 26.29	$ 19.96
Vested (in dollars per unit)		22.96	17.20	19.65
Forfeited (in dollars per unit)		21.77	18.81	19.60
Phantom units outstanding at the end of the period (in dollars per unit)		$ 22.10	$ 23.65	$ 20.02
Unrecognized compensation cost associated with phantom unit awards		$ 3,600
Weighted-average period over which the unrecognized compensation cost is expected to be recognized		1 year 8 months 12 days
LTIP | Executive officers, employees and independent directors | Phantom units
Unit-based Compensation
Amount of compensation expense recognized		$ 3,900	$ 3,000	$ 1,300
LTIP | Employee
Number of Units
Vested (in units)				0

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Employee Benefit Plans (Details) - 401(k) Plan - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Employee Benefit Plans
Maximum annual employee contribution, as a percentage	20.00%
Maximum annual employee contribution	$ 18,000
Aggregate discretionary employer matching contributions	$ 800,000	$ 700,000	$ 600,000

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Transactions with Related Parties (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
John Chandler
Transactions with Related Parties
Receivable from related party	$ 1.3	$ 0.1
PVR and subsidiaries | Willam Shea, Jr
Transactions with Related Parties
Compression service revenue		0.6	$ 3.0
Cone | John Chandler
Transactions with Related Parties
Compression service revenue	$ 8.8	$ 1.7

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Commitments and Contingencies - Operating Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies
Rent expense for operating leases	$ 2,900	$ 2,300	$ 1,600
Commitments for future minimum lease payments on noncancellable leases
2016	1,645
2017	1,460
2018	1,160
2019	1,028
2020	27
Total	$ 5,320

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Commitments and Contingencies - Major Customers (Details) - customer	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies
Number of major customers	1	1
Percentage of revenue to total revenue	11.60%	14.30%

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Commitments and Contingencies - Purchase Commitments (Details) $ in Millions	Dec. 31, 2015 USD ($)
Commitments and Contingencies
Other Commitment	$ 20.8

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Subsequent Events (Details)	Feb. 09, 2016 shares
Subsequent Event | Phantom units
Subsequent Events
Units granted under LTIP	36,361

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Label	Element	Value
General Partner [Member]
Income (Loss) Attributable to Parent	us-gaap_IncomeLossAttributableToParent	$ 5,000
Limited Partner [Member]
Income (Loss) Attributable to Parent	us-gaap_IncomeLossAttributableToParent	530,000
Common Units [Member] | Limited Partner [Member]
Income (Loss) Attributable to Parent	us-gaap_IncomeLossAttributableToParent	5,805,000
General Partner Unit [Member] | General Partner [Member]
Income (Loss) Attributable to Parent	us-gaap_IncomeLossAttributableToParent	211,000
Subordinated Units [Member] | Limited Partner [Member]
Income (Loss) Attributable to Parent	us-gaap_IncomeLossAttributableToParent	$ 4,520,000