10-Q

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

(MARK ONE)

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

FOR THE QUARTERLY PERIOD ENDED June 30, 2015

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

FOR THE TRANSITION PERIOD FROM               TO               .

Commission File No. 001-35779

USA Compression Partners, LP

(Exact name of registrant as specified in its charter)

Delaware	75-2771546
(State or Other Jurisdiction of	(I.R.S. Employer
Incorporation or Organization)	Identification No.)
100 Congress Avenue, Suite 450
Austin, Texas	78701
(Address of principal executive offices)	(Zip Code)

(512) 473-2662

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  Yes ☒  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 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. (Check one):

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

As of August3, 2015, there were 32,768,844 common units and 14,048,588 subordinated units outstanding.

TABLE OF CONTENTS

	Page
PART I. FINANCIAL INFORMATION	1
ITEM 1.         Financial Statements	1
Unaudited Condensed Consolidated Balance Sheets	1
Unaudited Condensed Consolidated Statements of Operations	2
Unaudited Condensed Consolidated Statement of Changes in Partners’ Capital	3
Unaudited Condensed Consolidated Statements of Cash Flows	4
Notes to Unaudited Condensed Consolidated Financial Statements	5
ITEM 2.         Management’s Discussion and Analysis of Financial Condition and Results of Operations	13
ITEM 3.         Quantitative and Qualitative Disclosures About Market Risk	27
ITEM 4.         Controls and Procedures	27
PART II. OTHER INFORMATION	28
ITEM 1.         Legal Proceedings	28
ITEM 1A.      Risk Factors	28
ITEM 2.         Unregistered Sales of Equity Securities and Use of Proceeds	28
ITEM 3.         Defaults Upon Senior Securities	28
ITEM 4.         Mine Safety Disclosures	28
ITEM 5.         Other Information	29
ITEM 6.         Exhibits	29
SIGNATURES	30

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PART I.  FINANCIAL INFORMATION

ITEM 1.Financial Statements

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Balance Sheets

(Dollars in thousands, except for unit amounts)

	June 30,		December 31,
	2015		2014
Assets
Current assets:
Cash and cash equivalents	$	7	$	6
Accounts receivable, net:
Trade, net		23,056		25,159
Other		2,874		2,926
Inventory		20,705		8,923
Prepaid expenses		2,294		1,020
Total current assets		48,936		38,034
Property and equipment, net		1,264,877		1,162,637
Installment receivable		18,786		20,241
Identifiable intangible assets, net		80,565		82,357
Goodwill		208,055		208,055
Other assets		7,671		5,158
Total assets	$	1,628,890	$	1,516,482
Liabilities and Partners’ Capital
Current liabilities:
Accounts payable	$	20,144	$	44,535
Accrued liabilities		22,281		21,708
Deferred revenue		16,880		15,855
Total current liabilities		59,305		82,098
Long-term debt		753,011		594,864
Partners’ capital:
Limited partner interest:
Common units, 32,768,844 and 31,307,116 units issued and outstanding, respectively		594,212		600,401
Subordinated units, 14,048,588 issued and outstanding each period		209,236		225,221
General partner interest		13,126		13,898
Total partners’ capital		816,574		839,520
Total liabilities and partners’ capital	$	1,628,890	$	1,516,482

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Operations

(Dollars in thousands, except unit amounts)

	Three months ended June 30,				Six months ended June 30,
	2015		2014		2015		2014
Revenues:
Contract operations	$	65,552	$	52,678	$	129,587	$	102,022
Parts and service		838		588		1,803		1,446
Total revenues		66,390		53,266		131,390		103,468
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		19,079		17,997		38,290		35,714
Selling, general and administrative		10,350		10,186		20,079		18,655
Depreciation and amortization		21,507		17,044		42,238		33,264
Loss (gain) on sale of assets		(23)		(2,520)		(218)		(2,291)
Impairment of compression equipment (Note 3)		26,829		—		26,829		—
Total costs and expenses		77,742		42,707		127,218		85,342
Operating income (loss)		(11,352)		10,559		4,172		18,126
Other income (expense):
Interest expense, net		(4,415)		(3,043)		(8,409)		(6,592)
Other		5		2		10		2
Total other expense		(4,410)		(3,041)		(8,399)		(6,590)
Net income (loss) before income tax expense		(15,762)		7,518		(4,227)		11,536
Income tax expense		142		—		221		103
Net income (loss)	$	(15,904)	$	7,518	$	(4,448)	$	11,433
Net income (loss) allocated to:
General partner’s interest in net income (loss)	$	(7)	$	188	$	362	$	274
Limited partners’ interest in net income (loss):
Common units	$	(11,043)	$	5,332	$	(3,225)	$	7,769
Subordinated units	$	(4,854)	$	1,998	$	(1,585)	$	3,390
Weighted average common units outstanding:
Basic		32,449,180		27,290,699		32,072,282		25,557,737
Diluted		32,449,180		27,327,545		32,072,282		25,626,850
Weighted average subordinated units outstanding:
Basic and diluted		14,048,588		14,048,588		14,048,588		14,048,588
Net income (loss) per common unit:
Basic	$	(0.34)	$	0.20	$	(0.10)	$	0.30
Diluted	$	(0.34)	$	0.20	$	(0.10)	$	0.30
Net income (loss) per subordinated unit:
Basic and diluted	$	(0.35)	$	0.14	$	(0.11)	$	0.24
Distributions declared per limited partner unit for respective periods	$	0.525	$	0.50	$	1.04	$	0.99

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statement of Changes in Partners’ Capital

Six Months Ended June 30, 2015

(Dollars and unitsin thousands)

	Partners’ Capital								Total
	Common Units			Subordinated Units			General Partner		Partners’
	Units	Amount		Units	Amount		Amount		Capital
Partners’ capital, December 31, 2014	31,307	$	600,401	14,049	$	225,221	$	13,898	$	839,520
Vesting of phantom units	94		1,714	—		—		—		1,714
Distributions and DERs	—		(32,522)	—		(14,400)		(1,134)		(48,056)
Proceeds from issuance of common units	1,368		27,709	—		—		—		27,709
Unit-based compensation	—		135	—		—		—		135
Net income (loss)	—		(3,225)	—		(1,585)		362		(4,448)
Partners’ capital, June 30, 2015	32,769	$	594,212	14,049	$	209,236	$	13,126	$	816,574

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Unaudited Condensed Consolidated Statements of Cash Flows

(Dollars in thousands)

	Six months ended June 30,
	2015		2014
Cash flows from operating activities:
Net income (loss)	$	(4,448)	$	11,433
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization		42,238		33,264
Amortization of debt issue costs		870		874
Unit-based compensation expense		2,264		2,102
Net (gain) loss on sale of assets		(218)		(2,291)
Impairment of compression equipment		26,829		—
Changes in assets and liabilities:
Accounts receivable		3,610		(7,085)
Inventory		(12,465)		(921)
Prepaids		(1,273)		581
Other noncurrent assets		3		(79)
Accounts payable		(8,651)		(10,012)
Accrued liabilities and deferred revenue		(209)		3,803
Net cash provided by operating activities		48,550		31,669
Cash flows from investing activities:
Capital expenditures		(182,687)		(188,506)
Proceeds from sale of property and equipment		129		411
Proceeds from insurance recovery		159		—
Net cash used in investing activities		(182,399)		(188,095)
Cash flows from financing activities:
Proceeds from long-term debt		295,798		269,470
Payments on long-term debt		(137,651)		(238,444)
Net proceeds from issuance of common units		745		137,278
Cash paid for taxes related to net settlement of unit-based awards		(189)		—
Cash distributions		(21,467)		(12,087)
General partner contribution		—		294
Financing costs and registration fees		(3,386)		(85)
Net cash provided by financing activities		133,850		156,426
Increase in cash and cash equivalents		1		—
Cash and cash equivalents, beginning of period		6		7
Cash and cash equivalents, end of period	$	7	$	7
Supplemental cash flow information:
Cash paid for interest	$	8,062	$	6,161
Cash paid for taxes	$	299	$	115
Supplemental non-cash transactions:
Non-cash distributions to certain limited partners (DRIP)	$	26,964	$	25,792
Change in capital expenditures included in accounts payable and accrued liabilities	$	13,783	$	5,820

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(1)  Organization and Summary of Significant Accounting Policies

(a)  Organization

USA Compression Partners, LP (the “Partnership”) is a publicly traded Delaware limited partnership formed to own and operate the business conducted by its subsidiaries. The common units representing limited partner interests in the Partnership (“common units”) are listed on the New York Stock Exchange (“NYSE”) under the symbol “USAC.” USA Compression GP, LLC, the general partner of the Partnership (the “General Partner”), is owned by USA Compression Holdings, LLC (“USA Compression Holdings”). Unless the context requires otherwise, references to “we,” “us,” “our,” or “the Partnership” are intended to mean the business and operations of the Partnership and its wholly owned, consolidated subsidiaries (the “Operating Subsidiaries”).  References to “Argonaut” and related parties refer to Argonaut Private Equity, L.L.C. and certain related parties.

The Partnership, through its Operating Subsidiaries, primarily provides natural gas compression services under term contracts with customers in the crude oil and natural gas industry, using natural gas compression packages that it designs, engineers, owns, operates and maintains. The unaudited condensed consolidated financial statements include the accounts of the Partnership and the Operating Subsidiaries, and all intercompany balances and transactions have been eliminated in consolidation.

The Partnership’s ownership is as follows:

	June 30, 2015
	USA
	Compression		Argonaut and
	Holdings		Related Parties		Public		Total
General partner interest	1.6	%	—		—		1.6	%
Limited partner interest:
Common unitholders	12.6	%	16.6	%	39.6	%	68.8	%
Subordinated unitholders	29.6	%	—		—		29.6	%
Total	43.8	%	16.6	%	39.6	%	100.0	%

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

(b)  Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Partnership have been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s annual report on Form 10-K for the year ended December 31, 2014 (the “2014 Annual Report”). In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position as of June 30, 2015 and December 31, 2014, and the results of operations for the three months and six months ended June 30, 2015 and 2014, changes in partners’ capital for the six months ended June 30, 2015 and the statements of cash flows for the six months ended June 30, 2015and 2014 in accordance with U.S. generally accepted accounting principles (“GAAP”). Operating results for the three months and six months ended June 30, 2015 are not necessarily indicative of the results that may be expected for the year ending December 31, 2015. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Therefore, these consolidated financial statements should be read in conjunction with the Partnership’s audited consolidated financial statements for the year ended December 31, 2014 contained in our 2014 Annual Report filed on February 19, 2015.

(c)  Use of Estimates

The unaudited condensed consolidated financial statements of the Partnership have been prepared in conformity with GAAP, which includes the use of estimates and assumptions by management that affect the reported amounts of assets,

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liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the unaudited condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could differ from these estimates.

(d)  Identifiable Intangible Assets

As of June 30, 2015, identifiable intangible assets, net consisted of the following (in thousands):

	Customer				Non-compete
	Relationships		Trade Names		Agreement		Total
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Amortization Expense		(1,368)		(312)		(112)		(1,792)
Net Balance at June 30, 2015	$	67,285	$	12,792	$	488	$	80,565

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.  Accumulated amortization of intangible assets was $14.6 million and $12.8 million as of June 30, 2015 and December 31, 2014, respectively.

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 for the three and six months ended June 30, 2015 or the three and six months ended June 30, 2014.

(e)  Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compressor 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	20 - 25 years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

See more information on property and equipment in Note 3 to our unaudited condensed consolidated financial statements.

(f)   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 recoverableor 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 flowsassociated 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 configuredfleet 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 3 for more detailed information about impairment charges during the three and six months ended June 30, 2015.

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(g)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 June 30, 2015 and December 31, 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. As of June 30, 2015 and December 31, 2014, unit-based compensation liability was $1.2 million and $1.3 million, respectively.

(h)Operating Segment

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

(2)  Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $0.9 million and $0.4 million at June 30, 2015 and December 31, 2014, respectively, is the Partnership’s best estimate of the amount of probable credit losses included in the Partnership’s existing accounts receivable. The Partnership determines the allowance based upon historical write-off experience and specific customer circumstances. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

(3)  Property and Equipment

Property and equipment consisted of the following at June 30, 2015 and December 31, 2014 (in thousands):

	June 30, 2015		December 31, 2014
Compression equipment	$	1,434,941	$	1,311,943
Furniture and fixtures		646		619
Automobiles and vehicles		18,584		17,303
Computer equipment		14,656		11,913
Leasehold improvements		1,035		858
Total		1,469,862		1,342,636
Less accumulated depreciation and amortization		(204,985)		(179,999)
Total	$	1,264,877	$	1,162,637

We recognized $20.6 million and $16.1 million of depreciation expense on property and equipment for the three months ended June 30, 2015 and 2014, respectively.  We recognized $40.4 million and $31.5 million of depreciation expense on property and equipment for the six months ended June 30, 2015 and 2014, respectively.

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As of June 30, 2015 and December 31, 2014, there was $18.6 million and $32.4 million, respectively, of property and equipment purchases in accounts payable and accrued liabilities.

During the six months ended June 30, 2015, non-cash transfers of inventory to andfromproperty and equipment totaled approximately $0.7 million.  These transfers have been treated as non-cash inventory activities in theUnaudited CondensedConsolidated Statements of Cash Flows.

During the six months ended June 30, 2015, insurance recoveries of $0.2 million were received on previously impaired compression equipment and are reported within the Loss (gain) on sale of assets line in the Unaudited Condensed Consolidated Statement of Operations. 

During the quarter ended June 30, 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 of166 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.  As a result of the Partnership’s decision to retire, sell or re-utilize these compressor units, management performed an impairment review and based on that review, recorded  a$26.8 million impairment of long-lived assets in the three and six months ended June 30, 2015. The Partnership did not record impairment of long-lived assets in the three and six months ended June 30, 2014.

(4) Accrued Liabilities

Other current liabilities included accrued salaries and benefits and accrued property taxes.  The Partnership recognized $5.7 million and $5.5 million of accrued salaries and benefits as of June 30, 2015 and December 31, 2014, respectively.  The Partnership recognized $4.6 million and $4.8 million of accrued property taxes as of June 30, 2015 and December 31, 2014, respectively.

(5)  Long-Term Debt

The long-term debt of the Partnership, of which there is no current portion, consisted of the following as ofJune 30, 2015 and December 31, 2014 (in thousands):

	June 30,		December 31,
	2015		2014
Senior debt	$	753,011	$	594,864

Revolving Credit Facility

As of June 30, 2015, the Partnership was in compliance with all of its covenants under its revolving credit facility.

As of June 30, 2015, the Partnership had outstanding borrowings of $753.0 million, $156.2 million of available borrowing capacity and borrowing base availability of $347.0 million. The Partnership’s interest rate in effect for all borrowings under its revolving credit facility as of June 30, 2015 and December 31, 2014 was 2.19% and 2.16%, respectively, with an average interest rate of 2.19% and 2.28% during the three months ended June 30, 2015 and 2014, respectively, and 2.19% and 2.22% during the six months ended June 30, 2015 and 2014, respectively.  There were no letters of credit issued as of June 30, 2015 or 2014.

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 are 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 thePartnership’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 this Indenture and any Debt Securities issued hereunder, except a discharge or release by or as a result of payment under such guarantees.   Capitalized termsin this paragraphare defined in the Form of Indenture filed as exhibit 4.1 tosuchregistration statement.

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(6)Partners’ Capital

As of August 3, 2015, USA Compression Holdings held 5,997,651 common units and 14,048,588 subordinated units and controlled the General Partner which held an approximate 1.6% general partner interest (the “General Partner’s Interest”) and the incentive distribution rights (“IDRs”). See the Unaudited Condensed Consolidated Statement of Changes in Partners’ Capital.

Subordinated Units

All of the subordinated units are held by USA Compression Holdings. Our 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 IDRs 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.

Cash Distributions

The Partnership has declared quarterly distributions per unit to limited partner unitholders of record, including holders of common and subordinated 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
	Limited Partner		Common		Subordinated		General		Total
Payment Date	Unit		Unitholders		Unitholder		Partner		Distribution
May 15, 2014	$	0.49	$	11.8	$	6.9	$	0.4	$	19.1
August 14, 2014		0.50		15.1		7.0		0.5		22.6
November 14, 2014		0.505		15.5		7.1		0.5		23.1
February 13, 2015		0.51		16.0		7.2		0.5		23.7
May 15, 2015		0.515		16.6		7.2		0.6		24.4

Dividend Reinvestment Program

During the six months ended June 30, 2015 and June 30, 2014, distributions of $27.0 million and $25.8 million, respectively, were reinvested under the distribution reinvestment plan (the “DRIP”) resulting in the issuance of 1.3 million and 0.9 million common units, respectively.  Such distributions are treated as non-cash transactions in the accompanying Unaudited Condensed Consolidated Statements of Cash Flows.  After taking into account the number of common units issued under the DRIP through June 30, 2015, we have the capacity to issue an additional 3.8 million common units under the DRIP.

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Issuance of Equity in Private Placement

On May 21, 2015, we issued 34,921common 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.We used the proceeds from the private placement for general partnership purposes.  There were no other unregistered sales of securities during the three and six months ended June 30, 2015.

Announced Quarterly Distribution

On July 23, 2015, the Partnership announced a cash distribution of $0.525 per unit on its common and subordinated units. The distribution will be paid on August 14, 2015 to unitholders of record as of the close of business on August 4, 2015. USA Compression Holdings, the owner of approximately 43% of the Partnership’s outstanding limited partner interests, and Argonaut and certain of its related parties, the owners of approximately 17% of the Partnership’s outstanding limited partner interests, each have elected to reinvest all of this distribution with respect to their units pursuant to the DRIP (other than the 34,921 units recently acquired by Argonaut).

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 Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“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 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 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 not considered to be participating securities, but are included in the calculation of diluted earnings per unit.  For the three and six months ended June 30, 2015, approximately 74,000 and 106,000 incremental phantom units, respectively, were excluded from the calculation of diluted units because the impact was anti-dilutive.

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 our 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

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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
	Total Quarterly	in Distributions
	Distribution Per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.4	%	1.6	%
First Target Distribution	up to $0.4888	98.4	%	1.6	%
Second Target Distribution	above $0.4888 up to $0.5313	85.4	%	14.6	%
Third Target Distribution	above $0.5313 up to $0.6375	75.4	%	24.6	%
Thereafter	above $0.6375	50.4	%	49.6	%

(7)  Transactions with Related Parties

William Shea, Jr., who has served as a director of USA Compression GP, LLC since June 2011, served as Chief Executive Officer of the general partner of PVR Partners, L.P. (“PVR”) from March 2010 to March 2014. In March 2014, PVR merged with and into Regency Energy Partners LP, a Delaware limited partnership (“Regency”), with Regency as the surviving limited partnership (the “Merger”) and PVR ceasing existence as a separate limited partnership. For the three months ended March 31, 2014, the Partnership recognized approximately $0.6 million in revenue on compression services from subsidiaries of PVR.

John Chandler, who has served as a director of USA Compression GP, LLC since October 2013, has served as a director of CONE Midstream GP, LLC (“CONE”) since October 2014. During the three and six months ended June 30, 2015, the Partnership recognized $2.2 million and $4.0 million, respectively, in revenue on compression services and $1.0 million in accounts receivable from CONE on the Unaudited Condensed Consolidated Balance Sheet as of June 30, 2015.

(8)  Commitments and Contingencies

(a)  Major Customers

The Partnership had revenue from one customer representing 10.3% and 11.7% of total revenue for the three months ended June 30, 2015 and 2014, respectively. The Partnership had revenue from the same customer representing 10.5% and 12.0% of total revenue for the six months ended June 30, 2015 and 2014, respectively.  No other customer represented greater than 10% of revenue for the three months ended June 30, 2015 or 2014 or the six months ended June 30, 2015 or 2014.

(b)  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.

(c)  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 June 30, 2015 were $76.2 million, all of which are expected to be settled within the next twelve months.

(9)  Recent Accounting Pronouncement

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

11

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 is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

Also in April 2015, the FASB issued an ASU that simplified the presentation of debt issuance costs.  The standard states:

· Deferred debt issuance costs will, instead of being reported as an asset, be deducted from the gross carrying amount of the debt to which it relates.

· Amortization of debt issuance costs will be reported as interest expense.

The ASU is effective for annual and interim periods in fiscal years beginning after December 15, 2015. Early adoption is permitted.  At the June 18, 2015 meeting of the FASB’s Emerging Issues Task Force, the SEC staff announced that it would not object to an entity’s deferral and presentation of such costs incurred in connection with revolving-debt arrangements as an asset.  As all of the Partnership’s debt issuance costs are associated with the revolving credit facility, this ASU currently has no impact on the Partnership’s 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.  The ASU requires prospective adoptions for inventory measurements for annual and interim periods in fiscal years beginning after December 15, 2016. Early adoptions is permitted. The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

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ITEM 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations

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 in Part II, Item 1A (“Risk Factors”) and elsewhere in this report. Important factors that could cause our actual results to differ materially from the expectations reflected in these forward-looking statements include, among other things:

· changes in general economic conditions and changes 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;

· 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. 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.

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 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 production and transportation volumes in these plays are expected to increase over time 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 crude oil wells targeted by horizontal drilling techniques. The advent of horizontal drilling has allowed producers to produce incremental volumes of crude oil on economic terms that tend to remain attractive even in periods of low commodity prices.

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General Trends and Outlook

A significant amount of our assets are utilized in infrastructure applications, primarily in centralized natural gas 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 in recent years and expect to see continued stability over the medium-to-long term.  A small portion of our fleet is used in connection with crude oil production using horizontal drilling techniques.  In the past few quarters, commodity prices have declined significantly.  As a result, we have experienced a limited amount of pressure on service rates until such time as commodity prices return to higher levels. However, we believe that through prudent management of our fleet we will be able to maintain strong utilization throughout 2015.We are closely monitoring developments in our customer base, but 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. We intend to prudently grow the number of compression units in our fleet, primarily through the purchase of larger horsepower units that tend to generate higher margins and command longer contract terms, in order to be positioned to take advantage of attractive market opportunities.

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. During 2015 we have been able to increase both our fleet size and our contract rates as a result of increasing demand for our services.  Revenue generating horsepower increased by 17.5% from June 30, 2014 to June 30, 2015. Average revenue generating horsepower increased by 21.2% from the three months ended June 30, 2014 to the three months ended June 30, 2015. Average revenue per revenue generating horsepower per month increased approximately 3% in the six months ended June 30, 2015 from the six months ended June 30, 2014 and increased approximately 2% in the three months ended June 30, 2015 from the three months ended June 30, 2014. Average utilization decreased approximately 3% in the six months ended June 30, 2015 from the six months ended June 30, 2014 and decreased approximately 5% in the three months ended June 30, 2015 from the three months ended June 30, 2014.  The decrease in utilization is primarily attributable to an increase in the amount of time contracting new compression units.  We believe this is the result of a delay in planned projects of certain of our customers.  As a result, during the second quarter of 2015, we moved the delivery of approximately 30,000 large horsepower from the second half of 2015 to the first half of 2016.  Concurrently, we have seen an increase in demand for services using small horsepower and have added to our order approximately 10,000 small horsepower for delivery during the second half of 2015.  For the year ending December 31, 2015, we expect to purchase approximately 215,000 horsepower of new compression unit equipment, all of which has already been ordered.

The EIA has projected that continued natural gas production growth will be supported in the coming years by increases in drilling efficiencies as well as a backlog of drilled but uncompleted wells in major supply areas, such as the Marcellus Shale. Additionally, domestic exports, both to Mexico and through the start-up of various liquefied natural gas (“LNG”) projects in late 2015 and beyond, are expected to increase. The EIA projects that over 70% of the increased natural gas production through 2040 will come from shale plays, which typically require greater compression services in production.  

Historically, crude oil and natural gas prices in the U.S. have been volatile. Global crude oil prices have fallen recently compared to levels seen over the past 18 months. West Texas Intermediate crude oil spot prices as of June 30, 2015 were 44% lower than prices at June 30, 2014.  During periods of lower crude oil and natural gas prices, domestic crude oil and natural gas production growth could moderate or decline. A 1% decrease in average revenue generating horsepower of our active fleet during the six months ended June 30, 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 “—Non-GAAP Financial Measures” below.

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Operating Highlights

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

	Three Months Ended						Six Months Ended June 30,
	June 30, 2015			June 30, 2014			2015			2014
Fleet horsepower (at period end)(1)		1,631,959			1,345,173			1,631,959			1,345,173
Total available horsepower (at period end)(2)		1,639,064			1,426,704			1,639,064			1,426,704
Revenue generating horsepower (at period end)(3)		1,411,005			1,200,547			1,411,005			1,200,547
Average revenue generating horsepower(4)		1,405,039			1,158,804			1,395,473			1,126,741
Average revenue per revenue generating horsepower per month	$	15.83		$	15.48		$	15.84		$	15.39
Revenue generating compression units (at period end)		2,733			2,362			2,733			2,362
Average horsepower per revenue generating compression unit(5)		518			504			518			503
Horsepower utilization(6):
At period end		91.5	%		95.0	%		91.5	%		95.0	%
Average for the period(7)		90.5	%		94.8	%		91.2	%		94.4	%

(1) Fleet horsepower is horsepower for compression units that have been delivered to us (and excludes units on order). As of June 30, 2015, approximately 140,000 horsepower had been delivered during the first half of 2015. Approximately 75,000 horsepower is expected to be delivered during the remainder of 2015, totaling 215,000 horsepower expected to be delivered during 2015.

(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 and 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 June 30, 2015 and June 30, 2014 was 86.5% and 89.2%, 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 for the three months ended June 30, 2015 and June 30, 2014 was 84.9% and 87.1%, respectively.  Average horsepower utilization based on revenue generating horsepower and fleet horsepower for the six months ended June 30, 2015 and June 30, 2014 was 85.8% and 87.4%, respectively.

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The21.3%increase in fleet horsepower as of June 30, 2015 over the fleet horsepower as of June 30, 2014 is attributable to the compression units added to our fleet to meet the incremental demand by new and current customers for our compression services.  The 17.5% increase in revenue generating horsepowerwasprimarily due to organic growth in our large horsepower fleet.

The following table summarizes other financial data for the periods presented (dollars in thousands):

	Three Months Ended June 30,						Percent		Six Months Ended June 30,						Percent
Other Financial Data: (1)	2015			2014			Change		2015			2014			Change
Gross operating margin	$	47,311		$	35,269		34.1	%	$	93,100		$	67,754		37.4	%
Gross operating margin percentage(2)		71.3	%		66.2	%	7.6	%		70.9	%		65.5	%	8.2	%
Adjusted EBITDA	$	38,618		$	26,866		43.7	%	$	76,136		$	52,058		46.3	%
Adjusted EBITDA percentage(2)		58.2	%		50.4	%	15.3	%		57.9	%		50.3	%	15.2	%
Adjusted Distributable Cash Flow	$	31,001		$	19,864		56.1	%	$	60,381		$	36,698		64.5	%
Adjusted Distributable Cash Flow Coverage Ratio		1.23	x		0.94	x	31.8	%		1.22	x		0.91	x	34.5	%
Cash Coverage Ratio		3.08	x		2.42	x	27.0	%		3.03	x		2.64	x	14.8	%

(1) Grossoperatingmargin,Adjusted EBITDA,AdjustedDistributable Cash Flow (“Adjusted DCF”), Adjusted DCF Coverage Ratio and Cash Coverage Ratio areall 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.”

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

Adjusted EBITDA.  The increase in Adjusted EBITDA during the three months ended June 30, 2015 was primarily attributable to a $12.0 million increase in Gross operating margin.  The increase in Gross operating margin is primarily attributed to the 21.2% increase in average revenue generating horsepower as a result of increased demand for our compression services.

The increase in Adjusted EBITDA during the six months ended June 30, 2015 was primarily attributable to a $25.3 million increase in Gross operating margin, offset by a $1.4 million increase in selling, general and administrative expenses.  The increase in Gross operating margin is primarily attributed to the 23.9% increase in average revenue generating horsepower as a result of increased demand for our compression services.

Adjusted DCF.  The increase in Adjusted DCFduring the three months ended June 30, 2015 was primarily attributable to a $12.0 million increase in Gross operating marginalong with lower maintenance capital expenditures during the comparable period, offset by higher cash interest expense, net.  The increase in Gross operating margin is primarily attributed to the 21.2% increase in average revenue generating horsepower as a result of increased demand for our compression services.  

The increase in Adjusted DCFduring the six months ended June 30, 2015 was primarily attributable to a $25.3 million increase in Gross operating marginalong with lower maintenance capital expenditures during the comparable period, offset by higher cash interest expense, net.  The increase in Gross operating margin is primarily attributed to the 23.9% increase in average revenue generating horsepower as a result of increased demand for our compression services.  

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Financial Results of Operations

Three months ended June 30, 2015 compared to the three months ended June 30, 2014

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

	Three Months Ended June 30,				Percent
	2015		2014		Change
Revenues:
Contract operations	$	65,552	$	52,678	24.4	%
Parts and service		838		588	42.5	%
Total revenues		66,390		53,266	24.6	%
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		19,079		17,997	6.0	%
Gross Operating Margin		47,311		35,269	34.1	%
Other operating and administrative costs and expenses:
Selling, general and administrative		10,350		10,186	1.6	%
Depreciation and amortization		21,507		17,044	26.2	%
Loss (gain) on sale of assets		(23)		(2,520)	(99.1)	%
Impairment of compression equipment		26,829		—	100.0	%
Total other operating and administrative costs and expenses		58,663		24,710	137.4	%
Operating income (loss)		(11,352)		10,559	(207.5)	%
Other income (expense):
Interest expense, net		(4,415)		(3,043)	45.1	%
Other		5		2	150.0	%
Total other expense		(4,410)		(3,041)	45.0	%
Income before income tax expense		(15,762)		7,518	(309.7)	%
Income tax expense		142		—	—	%
Net income (loss)	$	(15,904)	$	7,518	(311.5)	%

Contract operations revenue.  During the three months ended June 30, 2015, wesawan increase in overall natural gas production in the U.S. and experienced anincrease in demand for our compression services.  Because the demand for our services is driven primarily by production of natural gas, we focusour activities in areas of attractive growth, which are generally found in certain shale and unconventional resource plays.  The 21.2% increase in average revenue generating horsepower was primarily due to organic growth.  Average revenue per revenue generating horsepower per month increased from $15.48 for the three months ended June 30, 2014 to $15.83 for the three months ended June 30, 2015, an increase of 2.3%, 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.  

Parts and service revenue.  Parts and service revenuewascomprised of pass-through revenue and retail service revenue.  Pass-through revenuewasearnedprimarily on freight and crane charges that are directly reimbursable by our customers, for whichwe earn no margin.  Retail service revenue consistedof maintenance work on units at our customers’ locations that are outside the scope of our core maintenance activities. 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 is primarily attributable to the increase in our fleet size due to organic growth. Certain cost increases consisted of (1) a $1.1 million increase in labor expenses, (2) a $0.3 million increase in indirect expenses, the majority of which is higher property and other taxes and (3) a $0.3 million increase in direct expenses such as parts and fluids for the fleet.  

Gross operating margin.The $12.0 million increase in gross operating marginwasdue to higher revenues partially offset by higher operating expenses during the three months ended June 30, 2015. The5.1% increase in gross operating marginpercentage from 66.2% for the three months ended June 30, 2014 to 71.3% for the three months ended June 30, 2015 was attributable to (1) certain cost savings initiatives, (2) timing of certain maintenance activities and (3) lower fuel costs.

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Selling, general and administrative expense.  Selling, general and administrative expense for the three months ended June 30, 2015 was consistent with the comparable period in prior year.

Depreciation and amortization expense.  The $4.5 million increase in depreciation expense was related to an increase in property and equipment balances during the three months ended June 30, 2015 compared to the three months ended June 30, 2014.  There is no variance in amortization expense between the same 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.

Loss (gain) on sale of assets.  The gain on sale during the three months ended June 30, 2014 was a result of the completion of a purchase option agreement with a customer which was a one-time event.  There was no such event during the three months ended June 30, 2015.

Impairment on compression equipment.The $26.8 million impairment charge during the three months ended June 30, 2015 resulted from our evaluation of the future deployment of our current idle fleet under the current market conditions, and we determined to retire and either sell or re-utilize the key components of166 compressor units, or approximately 58,000 horsepower, that were previously used to provide services in the Partnership’s business.

Interest expense, net. The increase in interest expense, net was primarily attributable to the impact of an approximate $259.0 million increase in average outstanding borrowings. Average borrowings outstanding under our revolving credit facility were $741.3million for thethree months ended June 30, 2015 compared to $482.3million for the three months ended June 30, 2014.  Our revolving credit facility had an interest rate of 2.19% and 2.40% at June 30, 2015 and 2014, respectively, and an average interest rate of 2.19% and 2.28% for the three months ended June 30, 2015 and 2014, respectively.

Income tax expense. Income tax expense is associated with the Texas franchise tax.

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Six months ended June 30, 2015 compared to the six months ended June 30, 2014

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

	Six Months Ended June 30,				Percent
	2015		2014		Change
Revenues:
Contract operations	$	129,587	$	102,022	27.0	%
Parts and service		1,803		1,446	24.7	%
Total revenues		131,390		103,468	27.0	%
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization		38,290		35,714	7.2	%
Gross Operating Margin		93,100		67,754	37.4	%
Other operating and administrative costs and expenses:
Selling, general and administrative		20,079		18,655	7.6	%
Depreciation and amortization		42,238		33,264	27.0	%
Loss (gain) on sale of assets		(218)		(2,291)	(90.5)	%
Impairment of compression equipment		26,829		—	100.0	%
Total other operating and administrative costs and expenses		88,928		49,628	79.2	%
Operating income (loss)		4,172		18,126	(77.0)	%
Other income (expense):
Interest expense, net		(8,409)		(6,592)	27.6	%
Other		10		2	400.0	%
Total other expense		(8,399)		(6,590)	27.5	%
Income before income tax expense		(4,227)		11,536	(136.6)	%
Income tax expense		221		103	114.6	%
Net income (loss)	$	(4,448)	$	11,433	(138.9)	%

Contract operations revenue.  During the six months ended June 30, 2015, wesawan increase in overall natural gas production in the U.S. and experienced anincrease in demand for our compression services.  Because the demand for our services is driven primarily by production of natural gas, we focusour activities in areas of attractive growth, which are generally found in certain shale and unconventional resource plays.  The 23.9% increase in average revenue generating horsepower was primarily due to organic growth.  Average revenue per revenue generating horsepower per month increased from $15.39 for the six months ended June 30, 2014 to $15.84 for the six months ended June 30, 2015, an increase of 2.9%, 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.  

Parts and service revenue.  Parts and service revenuewascomprised of pass-through revenue and retail service revenue.  Pass-through revenuewasearnedprimarily on freight and crane charges that are directly reimbursable by our customers, for whichwe earn no margin.  Retail service revenue consistedof maintenance work on units at our customers’ locations that are outside the scope of our core maintenance activities. 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 is primarily attributable to the increase in our fleet size due to organic growth. Certain cost increases consisted primarily of (1) a  $2.3 million increase in labor expenses and (2) a $1.1 million increase inindirect expenses, the majority of which is higher property and other taxes.  

Gross operating margin.The $25.3 million increase in gross operating marginwasdue to higher revenues partially offset by higher operating expenses during the six months ended June 30, 2015. The5.4% increase in gross operating marginpercentage from 65.5% for the six months ended June 30, 2014 to 70.9% for the six months ended June 30, 2015 was attributable to (1) certain cost savings initiatives, (2) timing of certain maintenance activities and (3) lower fuel costs.

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Selling, general and administrative expense.  The increase in selling, general and administrative expense was primarily related to a $2.6 million rise in salaries and benefits related to an increase in employee headcount. The selling, general and administrative employee headcount was 115 as of June 30, 2015, a 7.5%increase from June 30, 2014. The selling, general and administrative employee headcount increased to support the continued growth of the business.  This was offset by a $1.2 million decrease in professional fees.

Depreciation and amortization expense.  The $9.0 million increase in depreciation expense was related to an increase in gross property and equipment balances during the six months ended June 30, 2015 compared to the six months ended June 30, 2014.  There is no variance in amortization expense between the same 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.

Loss (gain) on sale of assets.  The $0.2 million gain on sale of assets during the six months ended June 30, 2015 was primarily attributable to a cash insurance recovery on previously impaired compression equipment received during the first quarter of 2015.  The majority of the gain on sale during the six months ended June 30, 2014 was a result of the completion of a purchase option agreement with a customer which was a one-time event.

Impairment on compression equipment.The $26.8 million impairment charge during the three months ended June 30, 2015 resulted from our evaluation of the future deployment of our current idle fleet under the current market conditions, and we determined to retire and either sell or re-utilize the key components of166 compressor units, or approximately 58,000 horsepower, that were previously used to provide services in the Partnership’s business.

Interest expense, net. The increase in interest expense, net was primarily attributable to the impact of an approximate $224.7 million increase in average outstanding borrowings, offset by $0.4 million additional interest income related to a capital lease which commenced during the second quarter of 2014. Average borrowings outstanding under our revolving credit facility were $700.1million for thesix months ended June 30, 2015 compared to $475.4million for the six months ended June 30, 2014.  Our revolving credit facility had an interest rate of 2.19% and 2.40% at June 30, 2015 and 2014, respectively, and an average interest rate of 2.19% and 2.22% for the six months ended June 30, 2015 and 2014, respectively.

Income tax expense. Income tax expense is associated with the Texas franchise tax.

Liquidity and Capital Resources

Cash Flows

The following table summarizes our sources and uses of cash for the six months ended June 30, 2015 and 2014 as of the end of the periods presented (in thousands):

	Six Months Ended June 30,
	2015		2014
Net cash provided by operating activities	$	48,550	$	31,669
Net cash used in investing activities		(182,399)		(188,095)
Net cash provided by financing activities		133,850		156,426

Net cash provided by operating activities. The $16.9 million increase in net cash provided by operating activities for the six months ended June 30, 2015 relates primarily to a $25.3 million increase in gross operating margin and approximately $5.0 million higher cash collections as a result of an improving Days Sales Outstanding ratio, offset by a $11.5 million increase in inventory purchases, a $2.6 million increase in property tax payments, and a $2.9 million increase in bonus payments.

Net cash used in investing activities. Net cash used in investing activities for the six months ended June 30, 2015 related primarily to purchases of new compression units and related equipment in response to increasing demand for our services.

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Net cash provided by financing activities. During the six months ended June 30, 2015, we borrowed, on a net basis, $158.9 million primarily to support our purchases of new compression units, as described above, paid various loan fees and incurred costs in respect of our revolving credit facility in the amount of $3.4 million and made cash distributions to our unitholders of $21.5 million.  During the six months ended June 30, 2014, we borrowed, on a net basis, $168.3 million, including the use of proceeds from an equity offering to pay down our revolving credit facility, primarily to support purchases of new compression units and make cash distributions to our unitholders of $12.1 million. 

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

· expansion capital expenditures, which are capital expenditures made to expand the operating capacity or revenue generating capacity of existing or new assets, including by acquisition of compression units or through modification of existing compression units to increase their capacity.

We classify capital expenditures as maintenance or expansion on an individual asset basis. We expect that our maintenance capital expenditure requirements will continue to increase as the overall size and age of our fleet increases. Our aggregate maintenance capital expenditures for the six months ended June 30, 2015 and 2014 were $7.2 million and $9.1 million, respectively. We currently plan to spend approximately $17 million in maintenance capital expenditures during 2015.

Given our growth objective and anticipated demand from our customers primarily as a result of the increasing natural gas activity described above under the heading “—General Trends and Outlook,” we anticipate that we will continue to make significant expansion capital expenditures. Without giving effect to any equipment we may acquire pursuant to any futureacquisitions, we currentlyexpecttospend between$225 million and $245 million in expansion capital expenditures during 2015.Our expansion capital expenditures for the six months ended June 30, 2015 and 2014 were $176.8 million and $179.4 million, respectively.

Revolving Credit Facility

As of June 30, 2015, we were in compliance with all of our debt covenants under our revolving credit facility.  As of June 30, 2015, we had outstanding borrowings of $753.0 million, $156.2 million of available borrowing capacity and borrowing base availability was $347.0 million. One of the financial covenants under our revolving credit facility permits a maximum leverage ratio of (a) 5.95 to 1.0 as of June 30, 2015, (b) 5.5 to 1.0 through the end of the fiscal quarter ending June 30, 2016 and (c) 5.00 to 1.0 thereafter, in each case subject to a provision for increases in 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.  As a result of our need to comply with such financial covenant, we expect borrowings under our revolving credit facility, cash generated from operations and issuance of debt securities may not be sufficient to fund all of our short-term liquidity needs and that we will potentially need to issue equity securities in the next twelve months.  We expect, however, to be able to remain in compliance with such financial covenant by one or more of the following actions: delay a discretionary portion of our capital expenditures; issue equity in conjunction with the acquisition of another business; issue equity in a public or private offering; or request an equity infusion pursuant to the terms of our revolving credit facility.

As of August 3, 2015, we had outstanding borrowings under our revolving credit facility of $774.9 million.

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Distribution Reinvestment Plan

During the six months ended June 30, 2015, distributions of $27.0 million were reinvested under the DRIP resulting in the issuance of 1.3 million common units.  Such distributions are treated as non-cash transactions in the accompanying Unaudited Condensed Statements of Cash Flows.  After taking into account the number of common units issued under the DRIP through June 30, 2015, we have the capacity to issue an additional 3.8 million common units under the DRIP.

For a more detailed description of the DRIP, please see Note 6 to our unaudited condensed consolidated financial statements.

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.

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):

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Revenues:
Contract operations	$	65,552	$	52,678	$	129,587	$	102,022
Parts and service		838		588		1,803		1,446
Total revenues		66,390		53,266		131,390		103,468
Cost of operations, exclusive of depreciation and amortization		19,079		17,997		38,290		35,714
Gross operating margin		47,311		35,269		93,100		67,754
Other operating and administrative costs and expenses:
Selling, general and administrative		10,350		10,186		20,079		18,655
Depreciation and amortization		21,507		17,044		42,238		33,264
Loss (gain) on sale of assets		(23)		(2,520)		(218)		(2,291)
Impairment of compression equipment		26,829		—		26,829		—
Total other operating and administrative costs and expenses		58,663		24,710		88,928		49,628
Operating income (loss)	$	(11,352)	$	10,559	$	4,172	$	18,126

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, interest income, unit based compensation expense, restructuring charges, management fees, (gain) loss 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

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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 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 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.

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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):

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Net income (loss)	$	(15,904)	$	7,518	$	(4,448)	$	11,433
Interest expense, net		4,415		3,043		8,409		6,592
Depreciation and amortization		21,507		17,044		42,238		33,264
Income taxes		142		—		221		103
EBITDA	$	10,160	$	27,605	$	46,420	$	51,392
Impairment of compression equipment		26,829		—		26,829		—
Interest income on capital lease		414		402		841		402
Unit-based compensation expense(1)		1,238		1,006		2,264		2,102
Transaction expenses for acquisitions(2)		—		373		—		419
Loss (gain) on sale of assets and other		(23)		(2,520)		(218)		(2,257)
Adjusted EBITDA	$	38,618	$	26,866	$	76,136	$	52,058
Interest expense, net		(4,415)		(3,043)		(8,409)		(6,592)
Income tax expense		(142)		—		(221)		(103)
Interest income on capital lease		(414)		(402)		(841)		(402)
Transaction expenses for acquisitions		—		(373)		—		(419)
Other		415		291		870		839
Changes in operating assets and liabilities		(25)		(1,739)		(18,985)		(13,712)
Net cash provided by operating activities	$	34,037	$	21,600	$	48,550	$	31,669

(1) For the three and six months ended June 30, 2015, unit-based compensation expense included $0.2 million and $0.4 million, respectively, of cash payments related to quarterly payments of distribution equivalent rights on phantom unit awards and,for the six months ended June 30, 2015,$0.2 millionrelated to the cash portion of any settlement of phantom unit awards upon vesting.  For the three and six months ended June 30, 2014, unit-based compensation expense included $0.2 million for each period of cash payments related to quarterly payments of distribution equivalent rights on phantom unit awards and $0.3 million for each period related to the cash portion of any settlement of phantom unit awards upon vesting.  The remainder of the unit-based compensation expense for both periods was related to non-cash adjustments to the unit-based compensation liability.

(2) Represents certain transaction expenses related to potential acquisitions and other items.  The Partnership believes it is useful to investors to exclude these fees.

Adjusted Distributable Cash Flow

We define distributable cash flow as net income (loss) plus non-cash interest expense, depreciation and amortization expense, unit based compensation expense and impairment of compression equipment, less maintenance capital expenditures. We define Adjusted DCF as distributable cash flow plus certain transaction fees and (gain) loss on sale of equipment. We believe distributable cash flow and Adjusted DCF are important measures of operating performance because they allow 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 distributable cash flow and Adjusted DCF, management can quickly compute the coverage ratio of estimated cash flows to planned cash distributions.

Distributable cash flow and Adjusted DCF should not be considered as 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 distributable cash flow and Adjusted DCF as presented may not be comparable to similarly titled measures of other companies.

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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 Adjusted DCF, to evaluate our financial performance and our liquidity. Our Adjusted 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 Adjusted 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.

The following table reconciles Adjusted 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):

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Net income (loss)	$	(15,904)	$	7,518	$	(4,448)	$	11,433
Plus: Non-cash interest expense		415		292		870		874
Plus: Depreciation and amortization		21,507		17,044		42,238		33,264
Plus: Unit-based compensation expense(1)		1,238		1,006		2,264		2,102
Plus: Impairment of compression equipment		26,829		—		26,829		—
Less: Maintenance capital expenditures(2)		(3,061)		(3,849)		(7,154)		(9,137)
Distributable cash flow	$	31,024	$	22,011	$	60,599	$	38,536
Transaction expenses for acquisitions(3)		—		373		—		419
Loss (gain) on sale of assets and other		(23)		(2,520)		(218)		(2,257)
Adjusted distributable cash flow	$	31,001	$	19,864	$	60,381	$	36,698
Plus: Maintenance capital expenditures		3,061		3,849		7,154		9,137
Plus: Change in working capital		(25)		(1,739)		(18,985)		(13,712)
Less: Transaction expenses for acquisitions		—		(373)		—		(419)
Less: Other		—		(1)		—		(35)
Net cash provided by operating activities	$	34,037	$	21,600	$	48,550	$	31,669

(1) For the three and six months ended June 30, 2015, unit-based compensation expense included $0.2 million and $0.4 million, respectively, of cash payments related to quarterly payments of distribution equivalent rights on phantom unit awards and,for the six months ended June 30, 2015, $0.2 millionrelated to the cash portion of any settlement of phantom unit awards upon vesting.  For the three and six months ended June 30, 2014, unit-based compensation expense included $0.2 million for each period of cash payments related to quarterly payments of distribution equivalent rights on phantom unit awards and $0.3 million for each period related to the cash portion of any settlement of phantom unit awards upon vesting.  The remainder of the unit-based compensation expense for both periods was related to non-cash adjustments to the unit-based compensation liability.

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

(3) Represents certain transaction expenses related to potential acquisitions and other items.  We believe it is useful to investors to view its results excluding these fees. 

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Coverage Ratios

We define Adjusted DCF Coverage Ratio as Adjusted DCF less cash distributions to the General Partner and IDRs divided by distributions declared to limited partner unitholders for the period. We define Cash Coverage Ratio as Adjusted DCF less cash distributions toour generalpartner andIDRs divided by cash distributions paid to limited partner unitholders, after consideration of the DRIP. We believe Adjusted 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 we generate.

Our Adjusted DCF coverage ratio and Cash coverage ratio as presented may not be comparable to similarly titled measures of other companies.

The following table summarizes certain coverage ratios for the periods presented.

	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
Adjusted distributable cash flow	$	31,001	$	19,864	$	60,381	$	36,698
GP interest in adjusted distributable cash flow		671		506		1,219		895
Adjusted distributable cash flow attributable to LP interest	$	30,330	$	19,358	$	59,162	$	35,803
Distributions for Coverage Ratio	$	24,579	$	20,670	$	48,358	$	39,361
Distributions reinvested in the DRIP(1)	$	14,731	$	12,686	$	28,842	$	25,808
Distributions for Cash Coverage Ratio(2)	$	9,848	$	7,984	$	19,516	$	13,553
Adjusted Distributable Cash Flow Coverage Ratio		1.23		0.94		1.22		0.91
Cash Coverage Ratio		3.08		2.42		3.03		2.64

(1) Representsdistributions to holders enrolled in the DRIP as of the record date for each period.  Amount for the three and six months ended June 30, 2015 is based on an estimate as of the record date.

(2) Represents cash distributions declared for common units not participating in the DRIP.

Off-Balance Sheet Arrangements

We have no off-balance sheet financing activities.

Recent Accounting Pronouncement

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 9 to our unaudited condensed consolidated financial statements.

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ITEM 3.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 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 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. We do not intend to hedge our indirect exposure to fluctuating commodity prices.

Interest Rate Risk

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

As of June 30, 2015 we had approximately $753.0 million of variable-rate outstanding indebtedness at a weighted-average interest rate of 2.2%. A 1% increase or decrease in the effective interest rate on our variable-rate outstanding debt at June 30, 2015 would have resulted in an annual increase or decrease in our interest expense of approximately $7.5 million.

For further information regarding our exposure to interest rate fluctuations on our debt obligations see Note 5 to our unaudited condensed 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 amount it owes us, it could have a material adverse effect on our business, financial condition, results of operations or cash flows.

ITEM 4.Controls and Procedures

Management’s Evaluation of Disclosure Controls and Procedures

As required by Rule 13a-15(b) of the Securities Exchange Act of 1934, as amended (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 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 June 30, 2015 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) during the last fiscal quarter that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II.  OTHER INFORMATION

ITEM 1.Legal Proceedings

From time to time, we may be involved in various legal or governmental proceedings 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 our consolidated financial position, results of operations or cash flows.

ITEM 1A.Risk Factors

Security holders and potential investors in our securities should carefully consider the risk factors below and set forth in Part I, “Item 1A. Risk Factors” of the 2014 Annual Report.  We have identified these risk factors as important factors that could cause our actual results to differ materially from those contained in any written or oral forward-looking statements made by us or on our behalf.

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

The present U.S. 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 interpretations at any time. For example, the Fiscal Year 2016 Budget proposed by the President recommends that certain publicly traded partnerships earning income from activities related to fossil fuels be taxed as corporations beginning in 2021. From time to time, members of Congress propose and consider such substantive changes to the existing U.S. 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 IRS, 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.

ITEM 2.Unregistered Sales of Equity Securities and Use of Proceeds

On May 21, 2015, we 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 as a transaction not involving a public offering.  We used the proceeds from the private placement for general partnership purposes.  There were no other unregistered sales of securities during the three months ended June 30, 2015.

ITEM 3.Defaults Upon Senior Securities

None.

ITEM 4.Mine Safety Disclosures

Not applicable.

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ITEM 5.Other Information

None.

ITEM 6.Exhibits

The documents in the accompanying Exhibit Index are filed or incorporated by reference as part of this report and such Exhibit Index is incorporated herein by reference.

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SIGNATURES

Pursuant to the requirements 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.

August5, 2015	USA Compression Partners, LP
	By:	USA Compression GP, LLC
		its General Partner
	By:	/s/ Eric D. Long
		President and Chief Executive Officer
		(Principal Executive Officer)
	By:	/s/ Matthew C. Liuzzi
		Vice President, Chief Financial Officer and Treasurer
		(Principal Financial Officer)
	By:	/s/ Michael D. Lenox
		Vice President- Finance and Chief Accounting Officer
		(Principal Accounting Officer)

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EXHIBIT INDEX

Exhibit No.		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)
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
101.1	*	Interactive data files pursuant to Rule 405 of Regulation S-T

*Filed herewith.

#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.

31

EX-31.1

Exhibit 31.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)

OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Eric D. Long, certify that:

1.I have reviewed this Quarterly Report on Form 10-Q 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.

August5, 2015
/s/ Eric D. Long
Name:	Eric D. Long
Title:	President and Chief Executive Officer

EX-31.2

Exhibit31.2

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

PURSUANT TO RULE 13A-14(A) AND RULE 15D-14(A)

OF THE SECURITIES EXCHANGE ACT OF 1934, AS AMENDED

I, Matthew C. Liuzzi, certify that:

1.I have reviewed this Quarterly Report on Form10-Q 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.

August 5, 2015
/s/ Matthew C. Liuzzi
Name:	Matthew C. Liuzzi
Title:	Vice President, Chief Financial Officer and Treasurer

EX-32.1

Exhibit 32.1

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 Quarterly Report on Form 10-Q of USA Compression Partners, LP (the “Partnership”) for the quarter ended June 30, 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 USA Compression GP, LLC, the general partner of the Partnership, hereby certifies, pursuant to 18 U.S.C. Section 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, as amended; 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

August 5, 2015

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

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 Quarterly Report on Form 10-Q of USA Compression Partners, LP (the “Partnership”) for the quarter ended June 30, 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 USA Compression GP, LLC, the general partner of the Partnership, hereby certifies, pursuant to 18 U.S.C. Section 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, as amended; 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

August 5, 2015

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.

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Commitments and Contingencies - Major Customers (Details) - customer	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Major Customers
Number of major customers	1	1	1	1
Customer one
Major Customers
Percentage of revenue to total revenue	10.30%	11.70%	10.50%	12.00%

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Property and Equipment (Details) $ in Thousands	Jun. 30, 2015 USD ($) item	Dec. 31, 2014 USD ($)
Property and Equipment
Property and Equipment, gross	$ 1,469,862	$ 1,342,636
Less accumulated depreciation and amortization	(204,985)	(179,999)
Property and Equipment, net	$ 1,264,877	1,162,637
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
Property and Equipment, gross	$ 1,434,941	1,311,943
Furniture and fixtures
Property and Equipment
Property and Equipment, gross	646	619
Automobiles and vehicles
Property and Equipment
Property and Equipment, gross	18,584	17,303
Computer equipment
Property and Equipment
Property and Equipment, gross	14,656	11,913
Leasehold improvements
Property and Equipment
Property and Equipment, gross	$ 1,035	$ 858

XML

Property and Equipment

6 Months Ended

Jun. 30, 2015

Property and Equipment

Property and Equipment

(3)  Property and Equipment

Property and equipment consisted of the following at June 30, 2015 and December 31, 2014 (in thousands):

	June 30, 2015		December 31, 2014
Compression equipment	$	1,434,941	$	1,311,943
Furniture and fixtures		646		619
Automobiles and vehicles		18,584		17,303
Computer equipment		14,656		11,913
Leasehold improvements		1,035		858
Total		1,469,862		1,342,636
Less accumulated depreciation and amortization		(204,985)		(179,999)
Total	$	1,264,877	$	1,162,637

We recognized $20.6 million and $16.1 million of depreciation expense on property and equipment for thethree months ended June 30, 2015 and 2014, respectively.  We recognized $40.4 million and $31.5 million of depreciation expense on property and equipment for the six months ended June 30, 2015 and 2014, respectively.

As of June 30, 2015 and December 31, 2014, there was $18.6 million and $32.4 million, respectively, of property and equipment purchases in accounts payable and accrued liabilities.

During the six months ended June 30, 2015, non-cash transfers of inventory to andfromproperty and equipment totaled approximately $0.7million.  These transfers have been treated as non-cash inventory activities in theUnaudited CondensedConsolidated Statements of Cash Flows.

During the six months ended June 30, 2015, insurance recoveries of $0.2million were received on previously impaired compression equipment and are reported within the Loss (gain) on sale of assets line in the Unaudited Condensed Consolidated Statement of Operations. 

During the quarter ended June 30, 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 of166 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.  As a result of the Partnership’s decision to retire, sell or re-utilize these compressor units, management performed an impairment review and based on that review, recorded  a$26.8million impairment of long-lived assets in the three and six months ended June 30, 2015. The Partnership did not record impairment of long-lived assets in the three and six months ended June 30, 2014.  

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Partners' Capital - Subordinated Units (Details)		6 Months Ended
	Aug. 03, 2015 shares	Jun. 30, 2015 item $ / shares
General partner
Partners' Capital
General Partner, interest (as a percent)		1.60%
USA Compression Holdings, LLC | Subordinated units | Minimum Quarterly Distribution
Partners' Capital
Minimum Quarterly Distribution (in dollars per unit)		$ 0.425
Minimum Quarterly Distribution annualized, level one (in dollars per unit)		$ 1.70
Number of consecutive, non-overlapping four-quarter periods | item		3
Minimum Quarterly Distribution annualized, level two (in dollars per unit)		$ 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 | Limited partner | Subordinated units
Partners' Capital
Partners' capital (in units) | shares	14,048,588
USA Compression Holdings, LLC | Limited partner | Common units
Partners' Capital
Partners' capital (in units) | shares	5,997,651
USA Compression Holdings, LLC | General partner
Partners' Capital
General Partner, interest (as a percent)		1.60%
USA Compression GP, LLC | General partner
Partners' Capital
General Partner, interest (as a percent)	1.60%

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Long-Term Debt (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Long-term debt
Long-term debt	$ 753,011,000		$ 753,011,000		$ 594,864,000
Loan fees and incurred costs paid during period			3,386,000	$ 85,000
Revolving Credit Facility
Long-term debt
Long-term debt, current portion	0		0		0
Long-term debt	753,011,000		753,011,000		$ 594,864,000
Borrowing capacity, subject to covenants	$ 156,200,000		156,200,000
Borrowing Base Availability			$ 347,000,000
Effective interest rate (as a percent)	2.19%		2.19%		2.16%
Average interest rate (as a percent)	2.19%	2.28%	2.19%	2.22%
Letter of Credit outstanding amount	$ 0	$ 0	$ 0	$ 0

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Partners' Capital - Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands								6 Months Ended
	Jul. 23, 2015	Jun. 30, 2015	May. 15, 2015	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	May. 15, 2014	Jun. 30, 2015	Jun. 30, 2014	May. 21, 2015	Dec. 31, 2014
Cash Distributions
Non-cash distributions								$ 26,964	$ 25,792
Proceeds from Issuance of Common Limited Partners Units								$ 745	$ 137,278
Private Placement
Cash Distributions
Limited partner units issued (in shares)										34,921
Cash Distributions
Cash Distributions
Total Distribution			$ 24,400	$ 23,700	$ 23,100	$ 22,600	$ 19,100
Distribution reinvestment plan ("DRIP")
Cash Distributions
Common Unit, Issued		1,300,000						1,300,000	900,000
Limited partner | Subordinated units
Cash Distributions
Ownership interest (as a percent)								29.60%
Limited partner units issued (in shares)		14,048,588						14,048,588			14,048,588
Limited partner | Subordinated units | Cash Distributions
Cash Distributions
Total Distribution			$ 7,200	$ 7,200	$ 7,100	$ 7,000	$ 6,900
Limited partner | Common and Subordinated Units | Cash Distributions
Cash Distributions
Distribution per Limited Partner Unit (in dollars per share)			$ 0.515	$ 0.51	$ 0.505	$ 0.50	$ 0.49
Cash distribution announced per unit (in dollars per share)	$ 0.525
Limited partner | Common and Subordinated Units | Distribution reinvestment plan ("DRIP")
Cash Distributions
Non-cash distributions								$ 27,000	$ 25,800
Limited partner | Common units
Cash Distributions
Ownership interest (as a percent)								68.80%
Limited partner units issued (in shares)		32,768,844						32,768,844			31,307,116
Limited partner | Common units | Cash Distributions
Cash Distributions
Total Distribution			$ 16,600	$ 16,000	$ 15,500	$ 15,100	$ 11,800
Limited partner | Common units | Distribution reinvestment plan ("DRIP")
Cash Distributions
Number of units issuable under plan								3,800,000
General partner | Cash Distributions
Cash Distributions
Total Distribution			$ 600	$ 500	$ 500	$ 500	$ 400
USA Compression Holdings, LLC | Distribution reinvestment plan ("DRIP")
Cash Distributions
Ownership interest (as a percent)		43.00%
USA Compression Holdings, LLC | Limited partner | Subordinated units
Cash Distributions
Ownership interest (as a percent)								29.60%
USA Compression Holdings, LLC | Limited partner | Common units
Cash Distributions
Ownership interest (as a percent)								12.60%
Argonaut and related parties | Limited partner | Distribution reinvestment plan ("DRIP")
Cash Distributions
Ownership interest (as a percent)			17.00%
Argonaut and related parties | Limited partner | Common units
Cash Distributions
Ownership interest (as a percent)								16.60%

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Partners' Capital - Incentive Distribution Rights (Details) - Jun. 30, 2015 - $ / shares	Total
Limited partner | Incentive Distribution Rights | Minimum Quarterly Distribution
Partners' Capital
Marginal percentage interest in distributions	98.40%
Limited partner | Incentive Distribution Rights | First Target Distribution
Partners' Capital
Marginal percentage interest in distributions	98.40%
Limited partner | Incentive Distribution Rights | Second Target Distribution
Partners' Capital
Marginal percentage interest in distributions	85.40%
Limited partner | Incentive Distribution Rights | Third Target Distribution
Partners' Capital
Marginal percentage interest in distributions	75.40%
Limited partner | Incentive Distribution Rights | Thereafter
Partners' Capital
Marginal percentage interest in distributions	50.40%
General partner
Partners' Capital
General Partner, interest (as a percent)	1.60%
General partner | Incentive Distribution Rights | Minimum Quarterly Distribution
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.425
Marginal percentage interest in distributions	1.60%
General partner | Incentive Distribution Rights | First Target Distribution
Partners' Capital
Marginal percentage interest in distributions	1.60%
General partner | Incentive Distribution Rights | First Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.4888
General partner | Incentive Distribution Rights | Second Target Distribution
Partners' Capital
Marginal percentage interest in distributions	14.60%
General partner | Incentive Distribution Rights | Second Target Distribution | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.4888
General partner | Incentive Distribution Rights | Second Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.5313
General partner | Incentive Distribution Rights | Third Target Distribution
Partners' Capital
Marginal percentage interest in distributions	24.60%
General partner | Incentive Distribution Rights | Third Target Distribution | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.5313
General partner | Incentive Distribution Rights | Third Target Distribution | Maximum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.6375
General partner | Incentive Distribution Rights | Thereafter
Partners' Capital
Marginal percentage interest in distributions	49.60%
General partner | Incentive Distribution Rights | Thereafter | Minimum
Partners' Capital
Quarterly distribution per unit (in dollars per share)	$ 0.6375

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Trade Accounts Receivable

6 Months Ended

Jun. 30, 2015

Trade Accounts Receivable

Trade Accounts Receivable

(2)  Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $0.9 million and $0.4 million at June 30, 2015 and December 31, 2014, respectively, is the Partnership’s best estimate of the amount of probable credit losses included in the Partnership’s existing accounts receivable. The Partnership determines the allowance based upon historical write-off experience and specific customer circumstances. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

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Transactions with Related Parties (Details) - Partner Type of Partners' Capital Account, Name [Domain] - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Mar. 31, 2014	Jun. 30, 2015
PVR and subsidiaries | Willam Shea, Jr
Transactions with Related Parties
Compression service revenue		$ 0.6
Cone | John Chandler
Transactions with Related Parties
Compression service revenue	$ 2.2		$ 4.0
Receivable from related party	$ 1.0		$ 1.0

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Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 7	$ 6
Accounts receivable, net:
Trade, net	23,056	25,159
Other	2,874	2,926
Inventory	20,705	8,923
Prepaid expenses	2,294	1,020
Total current assets	48,936	38,034
Property and equipment, net	1,264,877	1,162,637
Installment receivable	18,786	20,241
Identifiable intangible assets, net	80,565	82,357
Goodwill	208,055	208,055
Other assets	7,671	5,158
Total assets	1,628,890	1,516,482
Current liabilities:
Accounts payable	20,144	44,535
Accrued liabilities	22,281	21,708
Deferred revenue	16,880	15,855
Total current liabilities	59,305	82,098
Long-term debt	753,011	594,864
Partners' capital:
Total partners' capital	816,574	839,520
Total liabilities and partners' capital	1,628,890	1,516,482
Common units
Partners' capital:
Total partners' capital	594,212	600,401
Subordinated units
Partners' capital:
Total partners' capital	209,236	225,221
Limited partner | Common units
Partners' capital:
Total partners' capital	594,212	600,401
Limited partner | Subordinated units
Partners' capital:
Total partners' capital	209,236	225,221
General partner | General partner units
Partners' capital:
Total partners' capital	$ 13,126	$ 13,898

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Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities:
Net income (loss)	$ (4,448)	$ 11,433
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	42,238	33,264
Amortization of debt issue costs	870	874
Unit-based compensation expense	2,264	2,102
Net (gain) loss on sale of assets	(218)	(2,291)
Impairment of compression equipment	26,829
Changes in assets and liabilities:
Accounts receivable	3,610	(7,085)
Inventory	(12,465)	(921)
Prepaids	(1,273)	581
Other noncurrent assets	3	(79)
Accounts payable	(8,651)	(10,012)
Accrued liabilities and deferred revenue	(209)	3,803
Net cash provided by operating activities	48,550	31,669
Cash flows from investing activities:
Capital expenditures	(182,687)	(188,506)
Proceeds from sale of property and equipment	129	411
Proceeds from insurance recovery	159
Net cash used in investing activities	(182,399)	(188,095)
Cash flows from financing activities:
Proceeds from long-term debt	295,798	269,470
Payments on long-term debt	(137,651)	(238,444)
Cash paid for taxes related to net settlement of unit-based awards	(189)
Cash distributions	(21,467)	(12,087)
General partner contribution		294
Financing cost and registration fees	(3,386)	(85)
Net proceeds from issuance of common units	745	137,278
Net cash provided by financing activities	133,850	156,426
Increase (decrease) in cash and cash equivalents	1
Cash and cash equivalents, beginning of period	6	7
Cash and cash equivalents, end of period	7	7
Supplemental cash flow information:
Cash paid for interest	8,062	6,161
Cash paid for taxes	299	115
Supplemental non-cash transactions:
Non-cash distribution to certain limited partners (DRIP)	26,964	25,792
Change in capital expenditures included in accounts payable and accrued liabilities	$ 13,783	$ 5,820

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Organization and Summary of Significant Accounting Policies - Intangible Assets (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Identifiable intangible assets, net
Outstanding at beginning of period			$ 82,357,000
Amortization			(1,792,000)
Outstanding at end of period	$ 80,565,000		80,565,000
Amortization and impairment information
Accumulated amortization of intangible assets	14,600,000		14,600,000		$ 12,800,000
Impairment of intangible assets	0	$ 0	$ 0	$ 0
Minimum
Amortization and impairment information
Amortization period of identifiable intangible asset			4 years
Maximum
Amortization and impairment information
Amortization period of identifiable intangible asset			30 years
Customer Relationships
Identifiable intangible assets, net
Outstanding at beginning of period			$ 68,653,000
Amortization			(1,368,000)
Outstanding at end of period	67,285,000		67,285,000
Trade Names
Identifiable intangible assets, net
Outstanding at beginning of period			13,104,000
Amortization			(312,000)
Outstanding at end of period	12,792,000		12,792,000
Non-compete
Identifiable intangible assets, net
Outstanding at beginning of period			600,000
Amortization			(112,000)
Outstanding at end of period	$ 488,000		$ 488,000

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Trade Accounts Receivable (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Trade Accounts Receivable
Allowance for doubtful accounts	$ 0.9	$ 0.4

XML

Organization and Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies

Organization and Summary of Significant Accounting Policies

(1)  Organization and Summary of Significant Accounting Policies

(a)  Organization

USA Compression Partners, LP (the “Partnership”) is a publicly traded Delaware limited partnership formed to own and operate the business conducted by its subsidiaries. The common units representing limited partner interests in the Partnership (“common units”) are listed on the New York Stock Exchange (“NYSE”) under the symbol “USAC.” USA Compression GP, LLC, the general partner of the Partnership (the “General Partner”), is owned by USA Compression Holdings, LLC (“USA Compression Holdings”). Unless the context requires otherwise, references to “we,” “us,” “our,” or “the Partnership” are intended to mean the business and operations of the Partnership and its wholly owned, consolidated subsidiaries (the “Operating Subsidiaries”).  References to “Argonaut” and related parties refer to Argonaut Private Equity, L.L.C. and certain related parties.

The Partnership, through its Operating Subsidiaries, primarily provides natural gas compression services under term contracts with customers in the crude oil and natural gas industry, using natural gas compression packages that it designs, engineers, owns, operates and maintains. The unaudited condensed consolidated financial statements include the accounts of the Partnership and the Operating Subsidiaries, and all intercompany balances and transactions have been eliminated in consolidation.

The Partnership’s ownership is as follows:

	June 30, 2015
	USA
	Compression		Argonaut and
	Holdings		Related Parties		Public		Total
General partner interest	1.6	%	—		—		1.6	%
Limited partner interest:
Common unitholders	12.6	%	16.6	%	39.6	%	68.8	%
Subordinated unitholders	29.6	%	—		—		29.6	%
Total	43.8	%	16.6	%	39.6	%	100.0	%

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

(b)  Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Partnership have been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s annual report on Form 10-K for the year ended December 31, 2014 (the “2014 Annual Report”). In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position as of June 30, 2015 and December 31, 2014, and the results of operations for the three months and six months ended June 30, 2015 and 2014, changes in partners’ capital for the six months ended June 30, 2015 and the statements of cash flows for the six months ended June 30, 2015and 2014 in accordance with U.S. generally accepted accounting principles (“GAAP”). Operating results for the three months and six months ended June 30, 2015 are not necessarily indicative of the results that may be expected for the year ending December 31, 2015. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Therefore, these consolidated financial statements should be read in conjunction with the Partnership’s audited consolidated financial statements for the year ended December 31, 2014 contained in our 2014 Annual Report filed on February 19, 2015.

(c)  Use of Estimates

The unaudited condensed consolidated financial statements of the Partnership have been prepared in conformity with GAAP, which includes the use of estimates and assumptions by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the unaudited condensed consolidated financial statements. Although these estimates are based on management’s available knowledge of current and expected future events, actual results could differ from these estimates.

(d)  Identifiable Intangible Assets

As of June 30, 2015, identifiable intangible assets, net consisted of the following (in thousands):

	Customer				Non-compete
	Relationships		Trade Names		Agreement		Total
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Amortization Expense		(1,368)		(312)		(112)		(1,792)
Net Balance at June 30, 2015	$	67,285	$	12,792	$	488	$	80,565

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.  Accumulated amortization of intangible assets was $14.6 million and $12.8 million as of June 30, 2015 and December 31, 2014, respectively.

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 for the three and six months ended June 30, 2015 or the three and six months ended June 30, 2014.

(e)  Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compressor 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	20 - 25 years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

See more information on property and equipment in Note 3 to our unaudited condensed consolidated financial statements.

(f)   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 flowsassociated 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 configuredfleet 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 3 for more detailed information about impairment charges during the three and six months ended June 30, 2015.

(g)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 June 30, 2015 and December 31, 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.As of June 30, 2015 and December 31, 2014, unit-based compensation liability was $1.2 million and $1.3 million, respectively.

(h)Operating Segment

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

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Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - Limited partner - shares	Jun. 30, 2015	Dec. 31, 2014
Common units
Limited partner units issued (in shares)	32,768,844	31,307,116
Limited partner units outstanding (in shares)	32,768,844	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

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Organization and Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies

Schedule of ownership

	June 30, 2015
	USA
	Compression		Argonaut and
	Holdings		Related Parties		Public		Total
General partner interest	1.6	%	—		—		1.6	%
Limited partner interest:
Common unitholders	12.6	%	16.6	%	39.6	%	68.8	%
Subordinated unitholders	29.6	%	—		—		29.6	%
Total	43.8	%	16.6	%	39.6	%	100.0	%

Schedule of identifiable intangible assets (in thousands)

	Customer				Non-compete
	Relationships		Trade Names		Agreement		Total
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Amortization Expense		(1,368)		(312)		(112)		(1,792)
Net Balance at June 30, 2015	$	67,285	$	12,792	$	488	$	80,565

Schedule of Estimated Useful Lives of Property, Plant and Equipment

Compression equipment	20 - 25 years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

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Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Aug. 03, 2015
Entity Registrant Name	USA Compression Partners, LP
Entity Central Index Key	0001522727
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q2
Common units
Entity Common Stock, Shares Outstanding		32,768,844
Subordinated units
Entity Common Stock, Shares Outstanding		14,048,588

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Property and Equipment (Tables)

6 Months Ended

Jun. 30, 2015

Property and Equipment

Schedule of property and equipment (in thousands)

	June 30, 2015		December 31, 2014
Compression equipment	$	1,434,941	$	1,311,943
Furniture and fixtures		646		619
Automobiles and vehicles		18,584		17,303
Computer equipment		14,656		11,913
Leasehold improvements		1,035		858
Total		1,469,862		1,342,636
Less accumulated depreciation and amortization		(204,985)		(179,999)
Total	$	1,264,877	$	1,162,637

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Condensed Consolidated Statements of Operations (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
Contract operations	$ 65,552	$ 52,678	$ 129,587	$ 102,022
Parts and service	838	588	1,803	1,446
Total revenues	66,390	53,266	131,390	103,468
Costs and expenses:
Cost of operations, exclusive of depreciation and amortization	19,079	17,997	38,290	35,714
Selling, general, and administrative	10,350	10,186	20,079	18,655
Depreciation and amortization	21,507	17,044	42,238	33,264
Loss (gain) on sale of assets	(23)	(2,520)	(218)	(2,291)
Impairment of compression equipment	26,829		26,829
Total costs and expenses	77,742	42,707	127,218	85,342
Operating income (loss)	(11,352)	10,559	4,172	18,126
Other income (expense):
Interest expense, net	(4,415)	(3,043)	(8,409)	(6,592)
Other	5	2	10	2
Total other expense	(4,410)	(3,041)	(8,399)	(6,590)
Net income (loss) before income tax expense	(15,762)	7,518	(4,227)	11,536
Income tax expense	142		221	103
Net income (loss)	(15,904)	7,518	(4,448)	11,433
Net income (loss) allocated to:
General partner’s interest in net income (loss)	$ (7)	$ 188	$ 362	$ 274
Net income per unit:
Distributions declared per limited partner unit for respective periods (in dollars per unit)	$ 0.525	$ 0.50	$ 1.04	$ 0.99
Common units
Net income (loss) allocated to:
Limited partners' interest in net income (loss)	$ (11,043)	$ 5,332	$ (3,225)	$ 7,769
Weighted average units outstanding:
Basic (in units)	32,449,180	27,290,699	32,072,282	25,557,737
Diluted (in units)	32,449,180	27,327,545	32,072,282	25,626,850
Net income per unit:
Basic (in dollars per unit)	$ (0.34)	$ 0.20	$ (0.10)	$ 0.30
Diluted (in dollars per unit)	$ (0.34)	$ 0.20	$ (0.10)	$ 0.30
Subordinated units
Net income (loss) allocated to:
Limited partners' interest in net income (loss)	$ (4,854)	$ 1,998	$ (1,585)	$ 3,390
Weighted average units outstanding:
Basic and diluted (in units)	14,048,588	14,048,588	14,048,588	14,048,588
Net income per unit:
Basic and diluted (in dollars per unit)	$ (0.35)	$ 0.14	$ (0.11)	$ 0.24

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Partners' Capital

6 Months Ended

Jun. 30, 2015

Partners' Capital.

Partners' Capital

(6)Partners’ Capital

As of August 3, 2015, USA Compression Holdings held 5,997,651 common units and 14,048,588 subordinated units and controlled the General Partner which held an approximate 1.6% general partner interest (the “General Partner’s Interest”) and the incentive distribution rights (“IDRs”). See the Unaudited Condensed Consolidated Statement of Changes in Partners’ Capital.

Subordinated Units

All of the subordinated units are held by USA Compression Holdings. Our 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 IDRs 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.

Cash Distributions

The Partnership has declared quarterly distributions per unit to limited partner unitholders of record, including holders of common and subordinated 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
	Limited Partner		Common		Subordinated		General		Total
Payment Date	Unit		Unitholders		Unitholder		Partner		Distribution
May 15, 2014	$	0.49	$	11.8	$	6.9	$	0.4	$	19.1
August 14, 2014		0.50		15.1		7.0		0.5		22.6
November 14, 2014		0.505		15.5		7.1		0.5		23.1
February 13, 2015		0.51		16.0		7.2		0.5		23.7
May 15, 2015		0.515		16.6		7.2		0.6		24.4

Dividend Reinvestment Program

During the six months ended June 30, 2015 and June 30, 2014, distributions of $27.0 million and $25.8 million, respectively, were reinvested under the distribution reinvestment plan (the “DRIP”) resulting in the issuance of 1.3 million and 0.9 million common units, respectively.  Such distributions are treated as non-cash transactions in the accompanying Unaudited Condensed Consolidated Statements of Cash Flows.  After taking into account the number of common units issued under the DRIP through June 30, 2015, we have the capacity to issue an additional 3.8 million common units under the DRIP.

Issuance of Equity in Private Placement

On May 21, 2015, we issued 34,921common 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.We used the proceeds from the private placement for general partnership purposes.  There were no other unregistered sales of securities during the three and six months ended June 30, 2015.

Announced Quarterly Distribution

On July 23, 2015, the Partnership announced a cash distribution of $0.525per unit on its common and subordinated units. The distribution will be paid on August 14, 2015 to unitholders of record as of the close of business on August 4, 2015. USA Compression Holdings, the owner of approximately 43% of the Partnership’s outstanding limited partner interests, and Argonaut and certain of its related parties, the owners of approximately 17% of the Partnership’s outstanding limited partner interests, each have elected to reinvest all of this distribution with respect to their units pursuant to the DRIP (other than the 34,921 units recently acquired by Argonaut).

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 Financial Accounting Standards Board’s (“FASB”) Accounting Standards Codification (“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 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 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 not considered to be participating securities, but are included in the calculation of diluted earnings per unit.  For the three and six months ended June 30, 2015, approximately 74,000 and 106,000 incremental phantom units, respectively, were excluded from the calculation of diluted units because the impact was anti-dilutive.

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 our 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
	Total Quarterly	in Distributions
	Distribution Per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.4	%	1.6	%
First Target Distribution	up to $0.4888	98.4	%	1.6	%
Second Target Distribution	above $0.4888 up to $0.5313	85.4	%	14.6	%
Third Target Distribution	above $0.5313 up to $0.6375	75.4	%	24.6	%
Thereafter	above $0.6375	50.4	%	49.6	%

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Long-Term Debt

6 Months Ended

Jun. 30, 2015

Long-Term Debt

Long-Term Debt

(5)  Long-Term Debt

The long-term debt of the Partnership, of which there is no current portion, consisted of the following as ofJune 30, 2015 and December 31, 2014 (in thousands):

	June 30,		December 31,
	2015		2014
Senior debt	$	753,011	$	594,864

Revolving Credit Facility

As of June 30, 2015, the Partnership was in compliance with all of its covenants under its revolving credit facility.

As of June 30, 2015, the Partnership had outstanding borrowings of $753.0 million, $156.2 million of available borrowing capacity and borrowing base availability of $347.0 million. The Partnership’s interest rate in effect for all borrowings under its revolving credit facility as of June 30, 2015 and December 31, 2014 was 2.19% and 2.16%, respectively, with an average interest rate of 2.19% and 2.28% during the three months ended June 30, 2015 and 2014, respectively, and 2.19% and 2.22% during the six months ended June 30, 2015 and 2014, respectively.  There were no letters of credit issued as of June 30, 2015 or 2014.

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 are 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 thePartnership’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 this Indenture and any Debt Securities issued hereunder, except a discharge or release by or as a result of payment under such guarantees.   Capitalized termsin this paragraphare defined in the Form of Indenture filed as exhibit 4.1 tosuchregistration statement.

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Organization and Summary of Significant Accounting Policies - Property and Equipment (Details)	6 Months Ended
	Jun. 30, 2015
Compression equipment overhauls | Minimum
Property and Equipment
Estimated useful lives	3 years
Compression equipment overhauls | Maximum
Property and Equipment
Estimated useful lives	5 years
Compression equipment | Minimum
Property and Equipment
Estimated useful lives	20 years
Compression equipment | Maximum
Property and Equipment
Estimated useful lives	25 years
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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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2015

Long-Term Debt

Schedule of long-term debt of the Partnership (in thousands)

	June 30,		December 31,
	2015		2014
Senior debt	$	753,011	$	594,864

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Recent Accounting Pronouncement

6 Months Ended

Jun. 30, 2015

Recent Accounting Pronouncement

Recent Accounting Pronouncement

(9)  Recent Accounting Pronouncement

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 is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

Also in April 2015, the FASB issued an ASU that simplified the presentation of debt issuance costs.  The standard states:

· Deferred debt issuance costs will, instead of being reported as an asset, be deducted from the gross carrying amount of the debt to which it relates.

· Amortization of debt issuance costs will be reported as interest expense.

The ASU is effective for annual and interim periods in fiscal years beginning after December 15, 2015. Early adoption is permitted.  At the June 18, 2015 meeting of the FASB’s Emerging Issues Task Force, the SEC staff announced that it would not object to an entity’s deferral and presentation of such costs incurred in connection with revolving-debt arrangements as an asset.  As all of the Partnership’s debt issuance costs are associated with the revolving credit facility, this ASU currently has no impact on the Partnership’s 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.  The ASU requires prospective adoptions for inventory measurements for annual and interim periods in fiscal years beginning after December 15, 2016. Early adoptions is permitted. The Partnership is currently evaluating the impact, if any, of this ASU on its consolidated financial statements.

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Transactions with Related Parties

6 Months Ended

Jun. 30, 2015

Transactions with Related Parties

Transactions with Related Parties

(7)  Transactions with Related Parties

William Shea, Jr., who has served as a director of USA Compression GP, LLC since June 2011, served as Chief Executive Officer of the general partner of PVR Partners, L.P. (“PVR”) from March 2010 to March 2014. In March 2014, PVR merged with and into Regency Energy Partners LP, a Delaware limited partnership (“Regency”), with Regency as the surviving limited partnership (the “Merger”) and PVR ceasing existence as a separate limited partnership. For the three months ended March 31, 2014, the Partnership recognized approximately $0.6 million in revenue on compression services from subsidiaries of PVR.

John Chandler, who has served as a director of USA Compression GP, LLC since October 2013, has served as a director of CONE Midstream GP, LLC (“CONE”) since October 2014. During the three and six months ended June 30, 2015, the Partnership recognized $2.2 million and $4.0 million, respectively, in revenue on compression services and $1.0 million in accounts receivable from CONE on the Unaudited Condensed Consolidated Balance Sheet as of June 30, 2015.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2015

Commitments and Contingencies

Commitments and Contingencies

(8)  Commitments and Contingencies

(a)  Major Customers

The Partnership had revenue from one customer representing 10.3% and 11.7% of total revenue for the three months ended June 30, 2015 and 2014, respectively. The Partnership had revenue from the same customer representing 10.5% and 12.0% of total revenue for the six months ended June 30, 2015 and 2014, respectively.  No other customer represented greater than 10% of revenue for the three months ended June 30, 2015 or 2014 or the six months ended June 30, 2015 or 2014.

(b)  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.

(c)  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 June 30, 2015 were $76.2 million, all of which are expected to be settled within the next twelve months.

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Organization and Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2015

Organization and Summary of Significant Accounting Policies

Organization

(a)  Organization

USA Compression Partners, LP (the “Partnership”) is a publicly traded Delaware limited partnership formed to own and operate the business conducted by its subsidiaries. The common units representing limited partner interests in the Partnership (“common units”) are listed on the New York Stock Exchange (“NYSE”) under the symbol “USAC.” USA Compression GP, LLC, the general partner of the Partnership (the “General Partner”), is owned by USA Compression Holdings, LLC (“USA Compression Holdings”). Unless the context requires otherwise, references to “we,” “us,” “our,” or “the Partnership” are intended to mean the business and operations of the Partnership and its wholly owned, consolidated subsidiaries (the “Operating Subsidiaries”).  References to “Argonaut” and related parties refer to Argonaut Private Equity, L.L.C. and certain related parties.

The Partnership, through its Operating Subsidiaries, primarily provides natural gas compression services under term contracts with customers in the crude oil and natural gas industry, using natural gas compression packages that it designs, engineers, owns, operates and maintains. The unaudited condensed consolidated financial statements include the accounts of the Partnership and the Operating Subsidiaries, and all intercompany balances and transactions have been eliminated in consolidation.

The Partnership’s ownership is as follows:

	June 30, 2015
	USA
	Compression		Argonaut and
	Holdings		Related Parties		Public		Total
General partner interest	1.6	%	—		—		1.6	%
Limited partner interest:
Common unitholders	12.6	%	16.6	%	39.6	%	68.8	%
Subordinated unitholders	29.6	%	—		—		29.6	%
Total	43.8	%	16.6	%	39.6	%	100.0	%

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

Basis of Presentation

(b)  Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Partnership have been prepared on the same basis as the audited consolidated financial statements included in the Partnership’s annual report on Form 10-K for the year ended December 31, 2014 (the “2014 Annual Report”). In the opinion of the Partnership’s management, such financial information reflects all adjustments necessary for a fair presentation of the financial position as of June 30, 2015 and December 31, 2014, and the results of operations for the three months and six months ended June 30, 2015 and 2014, changes in partners’ capital for the six months ended June 30, 2015 and the statements of cash flows for the six months ended June 30, 2015and 2014 in accordance with U.S. generally accepted accounting principles (“GAAP”). Operating results for the three months and six months ended June 30, 2015 are not necessarily indicative of the results that may be expected for the year ending December 31, 2015. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”). Therefore, these consolidated financial statements should be read in conjunction with the Partnership’s audited consolidated financial statements for the year ended December 31, 2014 contained in our 2014 Annual Report filed on February 19, 2015.

Use of Estimates

(c)  Use of Estimates

The unaudited condensed consolidated financial statements of the Partnership have been prepared in conformity with GAAP, which includes the use of estimates and assumptions by management that affect the reported amounts of assets, liabilities, revenues, expenses and disclosure of contingent assets and liabilities that exist at the date of the unaudited condensed consolidated financial statements. 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

(d)  Identifiable Intangible Assets

As of June 30, 2015, identifiable intangible assets, net consisted of the following (in thousands):

	Customer				Non-compete
	Relationships		Trade Names		Agreement		Total
Net Balance at December 31, 2014	$	68,653	$	13,104	$	600	$	82,357
Amortization Expense		(1,368)		(312)		(112)		(1,792)
Net Balance at June 30, 2015	$	67,285	$	12,792	$	488	$	80,565

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.  Accumulated amortization of intangible assets was $14.6 million and $12.8 million as of June 30, 2015 and December 31, 2014, respectively.

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 for the three and six months ended June 30, 2015 or the three and six months ended June 30, 2014.

Property and Equipment

(e)  Property and Equipment

Property and equipment are carried at cost. Overhauls and major improvements that increase the value or extend the life of compressor 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	20 - 25 years
Furniture and fixtures	7 years
Vehicles and computer equipment	3 - 7 years
Leasehold improvements	5 years

Impairments of Long-Lived Assets

(f)   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 flowsassociated 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 configuredfleet 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 3 for more detailed information about impairment charges during the three and six months ended June 30, 2015.

Fair Value Measurements

(g)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 June 30, 2015 and December 31, 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.

Operating Segment

(h)Operating Segment

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

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Commitments and Contingencies - Purchase Commitments (Details) $ in Millions	Jun. 30, 2015 USD ($)
Compression units
Equipment purchase commitments
Purchase commitments	$ 76.2

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Organization and Summary of Significant Accounting Policies - Organization (Details)	6 Months Ended
	Jun. 30, 2015
Organization
Total (as a percent)	100.00%
Public
Organization
Total (as a percent)	39.60%
General partner
Organization
General partner interest (as a percent)	1.60%
USA Compression Holdings, LLC
Organization
Total (as a percent)	43.80%
USA Compression Holdings, LLC | General partner
Organization
General partner interest (as a percent)	1.60%
Argonaut and related parties
Organization
Total (as a percent)	16.60%
Common units | Limited partner
Organization
Limited partner interest (as a percent)	68.80%
Common units | Limited partner | Public
Organization
Limited partner interest (as a percent)	39.60%
Common units | USA Compression Holdings, LLC | Limited partner
Organization
Limited partner interest (as a percent)	12.60%
Common units | Argonaut and related parties | Limited partner
Organization
Limited partner interest (as a percent)	16.60%
Subordinated units | Limited partner
Organization
Limited partner interest (as a percent)	29.60%
Subordinated units | USA Compression Holdings, LLC | Limited partner
Organization
Limited partner interest (as a percent)	29.60%

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Property and Equipment - Additional Disclosures (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Property and Equipment
Depreciation expense	$ 20,600	$ 16,100	$ 40,400	$ 31,500
Transfers to inventory from property and equipment			700
Impairment of long-lived assets	$ 26,800	$ 0	26,800	$ 0
Loss (gain) on sale of assets
Property and Equipment
Insurance Recoveries			200
Accounts payable and accrued liabilities
Property and Equipment
Purchases of property and equipment			$ 18,600		$ 32,400

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Condensed Consolidated Statements of Changes in Partners' Capital (Unaudited) - USD ($) $ in Thousands	Common units Limited partner	Common units	Subordinated units Limited partner	Subordinated units	General partner units General partner	Total
Increase (Decrease) in Partners' Capital
Limited Partners' Capital Account, Units Outstanding	31,307,116		14,048,588
Partners' capital at Dec. 31, 2014	$ 600,401	$ 600,401	$ 225,221	$ 225,221	$ 13,898	$ 839,520
Increase (Decrease) in Partners' Capital
Vesting of phantom units	$ 1,714					1,714
Vesting of phantom units (in units)	94,000
Distributions and DERs	$ (32,522)		(14,400)		(1,134)	(48,056)
Proceeds from issuance of common units	$ 27,709					27,709
Proceeds from issuance of common units (in units)	1,368,000
Unit-based compensation	$ 135					135
Net income (loss)	(3,225)		(1,585)		362	(4,448)
Partners' capital at Jun. 30, 2015	$ 594,212	$ 594,212	$ 209,236	$ 209,236	$ 13,126	$ 816,574
Increase (Decrease) in Partners' Capital
Limited Partners' Capital Account, Units Outstanding	32,768,844		14,048,588

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Accrued Liabilities

6 Months Ended

Jun. 30, 2015

Accrued Liabilities

Accrued Liabilities

(4) Accrued Liabilities

Other current liabilities included accrued salaries and benefits and accrued property taxes.  The Partnership recognized $5.7 million and $5.5 million of accrued salaries and benefits as of June 30, 2015 and December 31, 2014, respectively.  The Partnership recognized $4.6 million and $4.8 million of accrued property taxes as of June 30, 2015 and December 31, 2014, respectively.

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Accrued Liabilities (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Accrued Liabilities
Accrued payroll & benefits expenses	$ 5.7	$ 5.5
Accrued property taxes	$ 4.6	$ 4.8

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Partners' Capital (Tables)

6 Months Ended

Jun. 30, 2015

Partners' Capital.

Schedule of cash distributions (in millions, except distribution per unit)

	Distribution per		Amount Paid to		Amount Paid to		Amount Paid to
	Limited Partner		Common		Subordinated		General		Total
Payment Date	Unit		Unitholders		Unitholder		Partner		Distribution
May 15, 2014	$	0.49	$	11.8	$	6.9	$	0.4	$	19.1
August 14, 2014		0.50		15.1		7.0		0.5		22.6
November 14, 2014		0.505		15.5		7.1		0.5		23.1
February 13, 2015		0.51		16.0		7.2		0.5		23.7
May 15, 2015		0.515		16.6		7.2		0.6		24.4

Schedule of percentage allocations of available cash from operating surplus between the unitholders and general partner

		Marginal Percentage Interest
	Total Quarterly	in Distributions
	Distribution Per Unit	Unitholders		General Partner
Minimum Quarterly Distribution	$0.425	98.4	%	1.6	%
First Target Distribution	up to $0.4888	98.4	%	1.6	%
Second Target Distribution	above $0.4888 up to $0.5313	85.4	%	14.6	%
Third Target Distribution	above $0.5313 up to $0.6375	75.4	%	24.6	%
Thereafter	above $0.6375	50.4	%	49.6	%