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UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 10-Q

(MARK ONE)

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

FOR THE QUARTERLY PERIOD ENDED June 30, 2014

o                   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)

(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 x  No o

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 x  No o

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):

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

As of August 8, 2014, there were 30,192,332 common units and 14,048,588 subordinated units outstanding.

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PART I.  FINANCIAL INFORMATION

ITEM 1.                                                Financial Statements

USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Condensed Consolidated Balance Sheets

(in thousands, except for unit amounts)

(unaudited)

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Condensed Consolidated Statements of Operations

(in thousands, except unit amounts)

(unaudited)

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Condensed Consolidated Statements of Changes in Partners’ Capital

Six Months Ended June 30, 2014

(in thousands)

(unaudited)

See accompanying notes to unaudited condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Condensed Consolidated Statements of Cash Flows

(in thousands)

(unaudited)

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 consolidated subsidiaries and references to the “General Partner” refer to the General Partner. References to “Riverstone” refer to Riverstone/Carlyle Global Energy and Power Fund IV, L.P., and affiliated entities, including Riverstone Holdings LLC.

The Partnership, through its wholly-owned subsidiaries (the “Operating Subsidiaries”), primarily provides natural gas compression services under term contracts with customers in the oil and gas industry, using natural gas compressor packages that it designs, engineers, owns, operates and maintains. The 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.

Our ownership is as follows:

Partnership net income (loss) is allocated to the partners 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, 2013, (“2013 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, 2014 and December 31, 2013, and the results of operations, changes in partners’ capital and changes in cash flows for the three months and six months ended June 30, 2014 and 2013, respectively, in accordance with accounting principles generally accepted in the United States (“GAAP”). Operating results for the three months and six months ended June 30, 2014 are not necessarily indicative of the results that may be expected for the year ending December 31, 2014. All intercompany balances and transactions have been eliminated in consolidation. 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 (“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, 2013 contained in our 2013 Annual Report filed on February 20, 2014. As the closing of the Partnership’s initial public offering (“IPO”) occurred on January 18, 2013, the earnings and earnings per unit for the six months ended June 30, 2013 have been pro-rated to reflect earnings on a pre-IPO and post-IPO basis.

(c)  Use of Estimates

The unaudited condensed consolidated financial statements 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 be different from those estimates.

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(d)  Intangible Assets

As of June 30, 2014, identifiable intangible assets, net consisted of the following (in thousands):

Intangible assets are amortized on a straight line basis 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. As of June 30, 2014, the amortization periods of identifiable customer relationships and identifiable trade names vary between 20 and 30 years and the amortization period of identifiable non-compete is 4 years.

The Partnership assesses long-lived assets, including intangible assets, for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability is assessed by comparing the carrying amount of an asset to undiscounted future net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured as the amount by which the carrying amounts exceed the fair value of the assets. The Partnership did not record any impairment of long-lived assets or intangible assets for the three and six months ended June 30, 2014 or for the three and six months ended June 30, 2013.

(e)  Fair Value of Financial Instruments

Accounting standards on fair value measurement 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.

The Partnership’s financial instruments consist primarily of cash and cash equivalents, trade accounts receivable, trade accounts payable and senior 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 amounts of senior debt approximate fair value due to the variable interest rates charged on the outstanding senior debt.

(2)  Acquisitions

On August 30, 2013, the Partnership completed the acquisition of assets and certain liabilities related to the business of providing compression services to third parties engaged in the exploration, production, gathering, processing, transportation or distribution of oil and gas (the “S&R Acquisition”) in exchange for 7,425,261 common units, which were valued at $181.9 million at the time of issuance. The S&R Acquisition was consummated pursuant to the Contribution Agreement dated August 12, 2013 (the “Contribution Agreement”) with S&R Compression, LLC, (“S&R”) and Argonaut Private Equity, L.L.C. (“Argonaut”). The S&R Acquisition had an effective date (from a standpoint of revenues and selected costs) of June 30, 2013. In connection with the S&R Acquisition, Argonaut and certain related parties agreed to participate in the Partnership’s Distribution Reinvestment Plan (the “DRIP”) through the distribution relating to the quarter ended June 30, 2014 (subsequently extended through the first quarter of 2015), provided that USA Compression Holdings continues to participate in the DRIP through that same period. The effective purchase price of $178.5 million reflects customary effective-date adjustments such as a $3.4 million purchase price adjustment due to working capital changes from the effective date to the closing date.

There were no adjustments during the six months ended June 30, 2014 to the S&R Acquisition purchase accounting disclosed in the Partnership’s 2013 Annual Report. Expenses associated with acquisition activities and transaction activities related to the S&R Acquisition for the six months ended June 30, 2014 and the year ended December 31, 2013 were $0.05 million and $2.1 million, respectively, and are included in selling, general and administrative expenses (“SG&A”).

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Revenue, Net Income and Pro Forma Financial Information — Unaudited

The assets acquired in the S&R Acquisition were not included in the Partnership’s consolidated results until the closing date of August 30, 2013. The unaudited pro forma financial information was prepared assuming the S&R Acquisition occurred on January 1, 2013. The financial information was derived from the Partnership’s unaudited historical condensed consolidated financial statements for the three and six months ended June 30, 2013 and S&R’s unaudited interim financial statements for the three and six months ended June 30, 2013.

The pro forma adjustments were based on currently available information and certain estimates and assumptions by management. If the S&R Acquisition had been in effect on the dates or for the periods indicated, the results may have been substantially different. For example, we may have operated the assets differently than S&R, realized revenue may have been different and costs of operation of the acquired assets may have been different. This pro forma financial information is provided for illustrative purposes only and may not provide an indication of results in the future.  The following table presents a summary of our pro forma financial information (in thousands, except unit amounts):

(1)         The Partnership did not complete its initial public offering until January 18, 2013.

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

(a)         Revenues and direct operating expenses for S&R were derived from the historical financial records of S&R. Incremental revenue related to the S&R Acquisition was $8.8 million and $16.7 million for the three and six months ended June 30, 2013, respectively. Incremental operating costs related to the S&R Acquisition were $3.7 million and $7.4 million for the three and six months ended June 30, 2013, respectively.

(b)         Depreciation and amortization was estimated using the straight-line method and reflects the incremental depreciation and amortization expense incurred due to adding the compression assets and intangible assets at fair value. Incremental depreciation and amortization was estimated at $2.4 million and $4.8 million for the three and six months ended June 30, 2013, respectively.

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

(d)         The capital contribution made by the General Partner to maintain its 2% general partner interest in the Partnership in connection with the issuance of common units in the S&R Acquisition was used to pay down the Partnership’s revolving credit facility resulting in a reduction of interest expense. Incremental interest expense reduction was estimated at $0.05 million and $0.1 million for the three and six months ended June 30, 2013.

(3)  Trade Accounts Receivable

Trade accounts receivable are recorded at the invoiced amount and do not bear interest. The allowance for doubtful accounts of $0.3 million and $0.2 million at June 30, 2014 and December 31, 2013, respectively, is the Partnership’s best estimate of the amount

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of probable credit losses in the Partnership’s existing accounts receivable. The Partnership determines the allowance based upon historical write-off experience and the specific circumstances. The Partnership does not have any off-balance-sheet credit exposure related to its customers.

(4)  Property and Equipment

Property and equipment consisted of the following at June 30, 2014 and December 31, 2013 (in thousands):

We recognized $16.1 million and $11.4 million of depreciation expense on property, plant and equipment for the three months ended June 30, 2014 and 2013, respectively. We recognized $31.5 million and $22.3 million of depreciation expense on property, plant and equipment for the six months ended June 30, 2014 and 2013, respectively.

As of June 30, 2014 and December 31, 2013, there were $21.7 million and $15.8 million, respectively, of property and equipment purchases in accounts payable and accrued liabilities.

(5)  Installment Receivable

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

The Superior Transaction was accounted for as a sales type lease and  resulted in a current installment receivable of $2.6 million included in other accounts receivable and a long-term installment receivable of $20.1 million, as of June 30, 2014. Additionally, the Partnership recorded a $2.7 million gain on sale of assets related to the Superior Transaction for the three months ended June 30, 2014.

(6)  Long-Term Debt

The long-term debt of the Partnership, of which there is no current portion, consisted of the following at June 30, 2014 and December 31, 2013 (in thousands):

On June 1, 2012, the Partnership entered into the third amendment to the credit agreement whereby the aggregate commitment under the revolving credit facility increased from $500 million to $600 million. In addition, on June 1, 2012, the Partnership entered into the Fourth Amended and Restated Credit Agreement in order to provide a more appropriate covenant structure for a public company than was the prior credit agreement, including a reduction of the applicable margin for LIBOR loans to a range of 175 to 250 basis points above LIBOR, depending on the Partnership’s leverage ratio. This amended and restated credit agreement went effective on January 18, 2013, the closing date of the Partnership’s initial public offering, was secured by a first priority lien against our assets and had a scheduled maturity of October 5, 2015. On December 10, 2012, the Partnership amended the Fourth Amended and Restated Credit Agreement to extend the periods during which the maximum funded debt to EBITDA ratio thresholds would apply.

On December 13, 2013, the Partnership entered into the Fifth Amended and Restated Credit Agreement whereby the aggregate commitment under the revolving credit facility increased from $600 million to $850 million (subject to availability under our borrowing base and a further potential increase of $100 million) and reduced the applicable margin for LIBOR loans to a range of 150 to 225 basis points above LIBOR, depending on the Partnership’s leverage ratio. The revolving credit facility is secured by a first priority lien against the Partnership’s assets and matures on December 13, 2018, at which point all amounts outstanding will become due.

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

·                  grant liens;

·                  make certain loans or investments;

·                  incur additional indebtedness or guarantee other indebtedness;

·                  enter into transactions with affiliates;

·                  merge or consolidate;

·                  sell the Partnership’s assets; or

·                  make certain acquisitions.

The Fifth Amended and Restated Credit Agreement also contains various financial covenants, including covenants requiring the Partnership to maintain:

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

·                  a maximum funded debt to EBITDA ratio, determined as of the last day of each fiscal quarter, for the annualized trailing three months of (a) 5.50 to 1.0, with respect to any fiscal quarter ending on or after December 13, 2013, the closing date of the amended credit facility, through June 30, 2015 or (b) 5.00 to 1.0, with respect to the fiscal quarter ending September 30, 2015 and each fiscal quarter thereafter, in each case subject to a provision for increases to such thresholds by 0.5 in connection with certain future acquisitions for the six consecutive month period following the period in which any such acquisition occurs.

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

On June 30, 2014, the Partnership entered into the Superior Transaction with the Superior Parties, pursuant to which the Partnership granted an irrevocable purchase option to the Superior Parties with respect to the Subject Compressor Packages.

In connection with the execution of the Superior Transaction, on June 30, 2014, the Partnership, entered into a letter agreement regarding a limited consent, amendment and subordination with respect to the Fifth Amended and Restated Credit Agreement to (a) permit the Superior Transaction, (b) permit the lien of the Superior Parties with respect to the Subject Compressor Packages, (c) subordinate the lien of the JPMorgan Chase Bank, N.A., as the administrative agent, for the benefit of itself and the other lenders, to the lien and purchase option of the Superior Parties with respect to the Subject Compressor Packages, (d) authorize the release of the lien of the administrative agent, for the benefit of itself and the other lenders, upon the exercise by any Superior Parties of its purchase option with respect to a specific Subject Compressor Package and (e) amend certain other provisions as more specifically set forth therein.

As of June 30, 2014 and December 31, 2013, the Partnership was in compliance with all of its covenants under the Fifth Amended and Restated Credit Agreement.

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At June 30, 2014, subject to financial covenants, borrowing availability was $305.6 million. The borrowing base consists of eligible accounts receivable, inventory and compression units. The largest component, representing 96% of the borrowing base at each of June 30, 2014 and December 31, 2013, was eligible compression units. Eligible compression units consist of compressor packages that are leased, rented or under service contracts to customers and carried in the financial statements as fixed assets.

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 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 (as such capitalized terms are defined in the Form of Indenture filed as exhibit 4.1 to the registration statement on Form S-3 (Reg. No. 333-193724)).

(7)  Partners’ Capital

As of August 8, 2014, USA Compression Holdings held 4,228,495 common units and 14,048,588 subordinated units and controlled USA Compression GP, LLC, which held an approximate 1.7% general partner 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. The First Amended and Restated Agreement of Limited Partnership of the Partnership (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 approximate 1.7% 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 approximate 1.7% interest and the related distribution on the incentive distribution rights for the four-quarter period immediately preceding that date. When the subordination period ends, all subordinated units will convert into common units on a one-for-one basis, and all common units thereafter will no longer be entitled to arrearages.

Cash Distributions

The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common and subordinated units and the approximate 1.7% general partner interest and IDRs held by the General Partner as follows (in millions, except distribution per unit):

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

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The Partnership Agreement requires that, within 45 days after the end of each quarter, the Partnership distribute all of its Available Cash to the partners of record on the applicable record date. Certain limited partners, including USA Compression Holdings, and Argonaut and certain of its related parties, have elected to receive distributions in the form of additional common units in accordance with the DRIP. Distributions to these holders relating to the fourth quarter of 2013 and first quarter of 2014, which were paid during the six months ended June 30, 2014, were reinvested pursuant to the DRIP. Such distributions totaled $25.8 million and are treated as non-cash transactions in the accompanying Statements of Cash Flows for the six months ended June 30, 2014.

On July 24, 2014, the Partnership announced a cash distribution of $0.50 per unit on its common and subordinated units. The distribution will be paid on August 14, 2014 to unitholders of record as of the close of business on August 4, 2014. USA Compression Holdings, the owner of 41.3% of the Partnership’s outstanding limited partner interests, and Argonaut and certain of its related parties, the owners of 16.0% of the Partnership’s outstanding limited partner interests, have elected to reinvest all of this distribution with respect to their units pursuant to the DRIP.

Equity Offering

On May 19, 2014, the Partnership closed a public offering of 6,600,000 common units, of which 5,600,000 common units were sold by the Partnership and 1,000,000 common units were sold by certain selling unitholders, including USA Compression Holdings and Argonaut (the “Selling Unitholders”), at a price to the public of $25.59. The Partnership used the net proceeds of $138.0 million (net of underwriting discounts and commission and offering expenses) to reduce the indebtedness outstanding under its revolving credit facility. USA Compression Holdings and Argonaut granted the underwriters an option to purchase up to an additional 990,000 units to cover over-allotments, which was exercised by the underwriters and closed on May 27, 2014. These sales resulted in USA Compression Holdings’ ownership percentage being reduced from 50.1% to 40.6% and Argonaut’s ownership percentage being reduced from 17.9% to 14.7%. The Partnership did not receive any proceeds from the common units sold by the Selling Unitholders.

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 Partnership’s subordinated units and general partner 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 unit and subordinated unit are determined by dividing net income allocated to the common units 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 units and subordinated units, respectively, during the period. Net income 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 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 Partnership’s 2013 Long-Term Incentive Plan.

Incentive Distribution Rights

The General Partner holds 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 approximate 1.7% general partner interest, and assume (i) the General Partner has contributed any additional capital necessary to maintain its approximate 1.7% general partner interest and has not transferred its IDRs  and (ii) there are no arrearages.

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(8)  Transactions with Related Parties

For the six months ended June 30, 2013, the Partnership incurred $0.05 million of expenses related to a management fee under an agreement between USA Compression Holdings, LLC and certain of its affiliates. No management fees were incurred during the six months ended June 30, 2014.

William Shea, who has served as a director of USA Compression GP, LLC since June 2011, also served as a director and the chief executive officer of the general partner of PVR Partners, L.P. (“PVR”) starting in March 2010. On March 21, 2014, PVR merged with and into Regency Energy Partners LP, a Delaware limited partnership (“Regency”), with Regency as the surviving limited partnership (the “Merger”). As a result of the Merger, the separate limited partnership existence of PVR ceased, and Regency continued its existence as the surviving limited partnership. For the three months ended June 30, 2013, subsidiaries of PVR made compression service payments to us of approximately $0.8 million. For the six months ended June 30, 2014 and 2013, subsidiaries of PVR made compression service payments to us of approximately $0.6 million and $1.5 million, respectively.

The Partnership provides compression services to entities controlled by Riverstone, who owned a majority of the membership interest in USA Compression Holdings, which owns and controls the General Partner and owned 41.3% of our limited partner interests, as of August 8, 2014. For each of the three months ended June 30, 2014 and 2013, such controlled entities made compression service payments to the Partnership of approximately $0.1 million. For the six months ended June 30, 2014 and 2013, such controlled entities made compression service payments to the Partnership of approximately $0.2 million and $0.3 million, respectively. The Partnership may provide compression services to additional entities controlled by Riverstone in the future; any significant transactions will be disclosed.

(9)  Recent Accounting Pronouncement

In May 2014, the FASB issued an update to the authoritative guidance related to clarifying the principles for recognizing revenue and to develop a common revenue standard for GAAP and International Financial Reporting Standards. The standard is updated in order to:

a.              remove inconsistencies and weaknesses in revenue requirements;

b.              provide a more robust framework for addressing revenue issues;

c.               improve comparability of revenue recognition practices across entities, industries, jurisdictions, and capital markets;

d.              provide more useful information to users of financial statements through improved disclosure requirements; and

e.               simplify the preparation of financial statements by reducing the number of requirements to which an entity must refer.

The amendments in this update are effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early adoption is not permitted. The Partnership is currently evaluating the impact, if any, of this standard on the condensed consolidated financial statements.

(10)  Commitments and Contingencies

(a)  Major Customers

The Partnership had revenue from one customer representing 11.7% and 16.0% of total revenue for the three months ended June 30, 2014 and 2013, respectively. The Partnership had revenue from one customer representing 12.0% and 15.2% of total revenue for the six months ended June 30, 2014 and 2013, respectively.

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(b)  Litigation

The Partnership and its subsidiaries 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 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, 2014 were $397.9 million, of which $334.7 million are expected to be settled within the next twelve months.

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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 of this report. Important factors that could cause our actual results to differ materially from the expectations reflected in these forward-looking statements include, among other things:

·                  changes in general economic conditions;

·                  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 are a growth-oriented Delaware limited partnership, and, based on management’s significant experience in the industry, we believe that we are one of the largest independent providers of compression services in the U.S. in terms of total compression unit horsepower. We partner with a broad customer base composed of producers, processors, gatherers and transporters of natural gas and oil producers. Our focus is to provide compression services to infrastructure applications primarily in high volume gathering systems, processing facilities and transportation applications.

General Trends and Outlook

Our midstream compression units have generally experienced stable rates since 2011 through the second quarter of 2014.  In our gas lift fleet, we have continued to experience strong market demand and, as a result, attractive pricing. We intend to grow the number of midstream and gas lift horsepower units in our fleet. While midstream horsepower units in general allow us to generate higher gross operating margins than gas lift units, they also generate lower average monthly revenue per revenue generating horsepower.

Our ability to increase our revenues is dependent in large part on our ability to add new revenue generating compression units to our fleet and increase the utilization of idle compression units. For the year ending December 31, 2014, we have ordered and expect to be delivered approximately 352,000 horsepower of new compression unit equipment, up from the 200,000 horsepower at year end December 31, 2013. Revenue generating horsepower increased by 43.5% from June 30, 2013 to June 30, 2014. We continue to have utilization rates of our fleet in excess of 90%. The average revenue generating horsepower increased by 39.7% from the three months ended June 30, 2013 to the three months ended June 30, 2014. We believe the activity levels in the U.S. will continue to increase, particularly in shale plays. According to the Annual Energy Outlook 2014 prepared by the Energy Information Agency (“EIA”),

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natural gas production from shale formations is expected to increase from 40% of total U.S. natural gas production in 2012 to 53% in 2040. Over the same period, total natural gas production is expected to increase 56% from 24 trillion cubic feet (“Tcf”) to 38 Tcf. In addition, the EIA forecasts that total domestic crude oil production will increase by 48% from 2012 to 2019 to 9.6 MMBbls/d, and more importantly, forecasts tight oil production to account for 50% of the total U.S. production in 2019 — an increase from 35% in 2012. We anticipate this activity will result in higher demand for our compression services, which we believe will result in increasing revenues. However, the expected increase in natural gas and crude oil activity and demand for our compression services may not occur for a variety of reasons. Please read “Disclosure Regarding Forward-Looking Statements”.

Operating Highlights

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

(1)         Fleet horsepower is horsepower for compression units that have been delivered to us (and excludes units on order). As of June 30, 2014, approximately 150,000 horsepower had been delivered. Approximately 90,000 horsepower is expected to be delivered between July 2014 and September 2014 and approximately 112,000 horsepower is expected to be delivered between October 2014 and December 2014, totaling 352,000 horsepower delivered during 2014 or on order currently.

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

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

(4)         Horsepower utilization is calculated as (i)(a) revenue generating horsepower plus (b) horsepower in our fleet that is under contract, but is not yet generating revenue plus (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, 2014 and 2013 was 89.2% and 86.4%, respectively.

(5)         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 six months ended June 30, 2014 and 2013 was 87.4% and 86.2%, respectively.

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

(1)   Gross operating margin is a non-GAAP financial measure. We calculate 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 should not be considered an alternative to, or more meaningful than, operating income 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 determined under GAAP, as well as gross operating margin, to evaluate our operating profitability.

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

(2)   For a reconciliation of Adjusted EBITDA, a non-GAAP financial measure, to net income and cash flows from operating activities, its most directly comparable GAAP financial measures, see “Non-GAAP Financial Measures.”

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

Gross operating margin, as a percentage of total revenues, decreased to 66.2% for the three months ended June 30, 2014 from 69.6% for the three months ended June 30, 2013. The decrease in gross operating margin, as a percentage of total revenues, was partially attributable to the lower gross operating margins on our gas lift compression units as compared to our large horsepower midstream assets.

The increase in cost of operations is attributable to (1) a $2.9 million increase due to labor and training, (2) a $1.4 million increase in lubrication oil expenses, attributable to a 85.8% increase in gallons consumed, (3) a $1.1 million increase of parts for maintenance expense, (4) a $0.7 million increase related to vehicle maintenance and fuel, (5) a $0.5 million increase due to higher property and other taxes and (6) a $0.3 million increase due to higher retail service expenses. These increases are primarily attributable to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition.

The increase in total revenues is attributable to an increase in average revenue generating horsepower from 829,684 for the three months ended June 30, 2013 to 1,158,804 for the three months ended June 30, 2014, an increase of 39.7%, primarily due to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition. Average revenue per revenue generating horsepower per month increased from $13.55 for the three months ended June 30, 2013 to $15.48 for the three months ended June 30, 2014, an increase of 14.2%, primarily due to higher revenue per horsepower per month from the gas lift compression units that were acquired in the S&R Acquisition. Revenue generating horsepower was 1,200,547 at June 30, 2014 compared to 836,427 at June 30, 2013, a 43.5% increase, primarily due to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition.

Gross operating margin, as a percentage of total revenues, decreased to 65.5% for the six months ended June 30, 2014 from 68.8% for the six months ended June 30, 2013. The decrease in gross operating margin, as a percentage of total revenues, was partially attributable to the lower gross operating margins on our gas lift compression units as compared to our large horsepower midstream assets.

The increase in cost of operations is attributable to (1) a $5.7 million increase in labor and training, (2) a $3.0 million increase in lubrication oil expenses due to a 94.1% increase in gallons consumed, (3) a $2.4 million increase in parts maintenance expense, (4) a $1.1 million increase in vehicle maintenance and fuel, (5) a $0.9 million increase in property and other taxes and (6) a $0.6 million increase in rent and supplies. These increases are primarily attributable to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition.

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The increase in total revenues is attributable to an increase in average revenue generating horsepower from 815,629 for the six months ended June 30, 2013 to 1,126,741 for the six months ended June 30, 2014, an increase of 38.1%, primarily due to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition. Average revenue per revenue generating horsepower per month increased from $13.57 for the six months ended June 30, 2013 to $15.39 for the six months ended June 30, 2014, an increase of 13.4%, primarily due to higher revenue per horsepower per month from the gas lift compression units that were acquired in the S&R Acquisition. Revenue generating horsepower was 1,200,547 at June 30, 2014 compared to 836,427 at June 30, 2013, a 43.5% increase, primarily due to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition.

Financial Results of Operations

Three months ended June 30, 2014 compared to the three months ended June 30, 2013

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

Contract operations revenue. Contract operations revenue was $52.7 million for the three months ended June 30, 2014 compared to $33.1 million for the three months ended June 30, 2013, an increase of 58.9%, primarily due to an increase in average revenue generating horsepower and an increase in average revenue per revenue generating horsepower.  Average revenue generating horsepower increased from 829,684 for the three months ended June 30, 2013 to 1,158,804 for the three months ended June 30, 2014, an increase of 39.7%, primarily due to growth in our midstream compression units along with the addition of assets in connection with the S&R Acquisition. Average revenue per revenue generating horsepower per month increased from $13.55 for the three months ended June 30, 2013 to $15.48 for the three months ended June 30, 2014, an increase of 14.2%, primarily due to higher revenue per horsepower per month from the gas lift compression units that were acquired in the S&R Acquisition. Revenue generating horsepower was 1,200,547 at June 30, 2014 compared to 836,427 at June 30, 2013, a 43.5% increase, primarily due to the increase in our fleet size due to organic growth and of operations related to the assets acquired in the S&R Acquisition.

Parts and service revenue. Parts and service revenue was $0.6 million for the three months ended June 30, 2014 compared to $0.2 million during the three months ended June 30, 2013.

Cost of operations, exclusive of depreciation and amortization. Cost of operations was $18.0 million for the three months ended June 30, 2014 compared to $10.1 million for the three months ended June 30, 2013, an increase of 77.6%. The increase is primarily attributable to the increase in our fleet size. The individual expenses increasing as a result of our fleet size include (1) a $2.9 million increase due to labor and training, (2) a $1.4 million increase in lubrication oil expenses, attributable to a 85.8% increase in gallons consumed,

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