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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 March 31, 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 May 5, 2014, there were 24,095,795 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 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 condensed consolidated financial statements.

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USA COMPRESSION PARTNERS, LP AND SUBSIDIARIES

Condensed Consolidated Statements of Changes in Partners’ Capital

Three Months Ended March 31, 2014

(In thousands)

(unaudited)

See accompanying notes to 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 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 USA Compression Partners, LP 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, together with its wholly-owned subsidiaries USA Compression Partners, LLC (“Operating Subsidiary”) and Operating Subsidiary’s wholly-owned subsidiary USAC Leasing, LLC (“Leasing Subsidiary”) and USAC OpCo 2, LLC (“OPCO 2”) and OPCO 2’s wholly-owned subsidiary USAC Leasing 2, LLC (“Leasing 2” and together with Operating Subsidiary, Leasing Subsidiary and OPCO 2, 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. 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 March 31, 2014 and December 31, 2013, and the results of operations, changes in partners’ capital and changes in cash flows for the three months ended March 31, 2014 and 2013, respectively, in accordance with accounting principles generally accepted in the United States (“GAAP”). All intercompany items 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 Annual Report on Form 10-K 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 three months ended March 31, 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 March 31, 2014, 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 March 31, 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 in the three months ended March 31, 2014 and recorded a $0.2 million impairment of long-lived assets for the year ended December 31, 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 notes payable. 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 notes payable approximate fair value due to the variable interest rates charged on the outstanding notes payable.

(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, 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 three months ended March 31, 2014 to the S&R Acquisition purchase accounting disclosed in the Partnership’s year ended December 31, 2013 Form 10-K. Expenses associated with acquisition activities and transaction activities related to the S&R Acquisition for the three months ended March 31, 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 S&R Acquisition was not included in the Partnership’s consolidated results until the closing date of August 30, 2013. For the three months ended March 31, 2014, the S&R Acquisition accounted for $12.6 million of revenue, $4.5 million of direct operating expenses and $2.9 million of depreciation and amortization, resulting in $5.2 million of net income. The net income attributable to these assets does not reflect certain expenses, such as SG&A and interest expense; therefore, this information is not intended to report results as if these operations were managed on a stand-alone basis.

The unaudited pro forma financial information was prepared assuming the S&R Acquisition occurred on January 1, 2013. The financial information was derived from the Partnership’s unaudited historical condensed consolidated financial statements for the three months ended March 31, 2013 and S&R’s unaudited interim financial statements for the three months ended March 31, 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 compression assets may have been different. This pro forma financial information is provided for illustrative purposes only and may not provide an indication of results in the future.  The following table presents a summary of our pro forma financial information (in thousands, except earnings per share):

(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 $7.9 million for the three months ended March 31, 2013. Incremental operating costs related to the S&R Acquisition were $3.7 million for the three months ended March 31, 2013.

(b)         Depreciation and amortization was estimated using the straight-line method and reflects the incremental depreciation and amortization expense incurred due to adding the compression assets and intangible fair value assets acquired from S&R. Incremental depreciation and amortization was estimated at $2.4 million for the three months ended March 31, 2013.

(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 for the three months ended March 31, 2013.

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(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 March 31, 2014 and December 31, 2013, respectively, is the Partnership’s best estimate of the amount 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 March 31, 2014 and December 31, 2013 (in thousands):

We recognized $15.3 million and $10.9 million of depreciation expense on property, plant and equipment for the three months ended March 31, 2014 and 2013, respectively.

As of March 31, 2014 and December 31, 2013, there were $4.7 million and $15.8 million, respectively, of property and equipment purchases in accounts payable and accrued liabilities.

(5)  Long-Term Debt

The long-term debt of the Partnership, of which there is no current portion, consisted of the following at March 31, 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 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, continued to be 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 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.

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;

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·                  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.

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

At March 31, 2014, subject to financial covenants, borrowing availability was $226.7 million. The borrowing base consists of eligible accounts receivable, inventory and compression units. The largest component, representing 95% and 96% of the borrowing base at March 31, 2014 and December 31, 2013, respectively, was eligible compression units; 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 Operating Subsidiary, Leasing Subsidiary, Leasing 2 or OPCO 2, each of which is a wholly-owned subsidiary of the Partnership, 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)).

(6)  Partner’s Capital

As of May 5, 2014, USA Compression Holdings held 5,337,977 common units and 14,048,588 subordinated units and controlled USA Compression GP, LLC, which held a 2% general partner interest and the incentive distribution rights (“IDRs”). See the Condensed Consolidated Statement of Changes in Partners’ Capital.

Subordinated Units

All of the subordinated units are held by USA Compression Holdings. 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 2.0% 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 2.0% 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.

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Cash Distributions

The Partnership has declared quarterly distributions per unit to unitholders of record, including holders of common and subordinated units and the 2% general partner interest 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.

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, which were paid during the first quarter of 2014, were reinvested pursuant to the DRIP. Such distributions totaled $12.6 million and are treated as non-cash transactions in the accompanying Statements of Cash Flows for the three months ended March 31, 2014.

On April 24, 2014, the Partnership announced a cash distribution of $0.49 per unit on its common and subordinated units. The distribution will be paid on May 15, 2014 to unitholders of record as of the close of business on May 5, 2014. USA Compression Holdings, the owner of 50.8% of the Partnership’s outstanding limited partner interests, and Argonaut and certain of its related parties, the owners of 19.4% of the Partnership’s outstanding limited partner interests, have elected to reinvest all of this distribution with respect to their units pursuant to the Partnership’s DRIP.

Earnings Per Common and Subordinated Unit

The computations of earnings per common unit and subordinated unit are based on the weighted average number of common units and subordinated units, respectively, outstanding during the applicable period. The Partnership’s subordinated units meet the definition of a participating security as defined by the Financial Accounting Standards Board’s 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. Diluted earnings per unit are computed using the treasury stock method, which considers the potential issuance of limited partner units associated with the LTIP.

Pursuant to the Partnership Agreement, to the extent that the quarterly distributions exceed certain targets, the General Partner, as the owner of the IDRs, is entitled to receive certain incentive distributions that will result in more earnings proportionately being allocated to the General Partner than to the holders of common units and subordinated units. The Partnership’s earnings per unit calculations allocate 2% of earnings to the General Partner plus the increasing distributions allocated to the General Partner relating to the IDRs.

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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 2.0% general partner interest, and assume (i) the General Partner has contributed any additional capital necessary to maintain its 2.0% general partner interest and has not transferred its IDRs  and (ii) there are no arrearages.

(7)  Unit-based Compensation

Long-Term Incentive Plan

In connection with the Partnership’s IPO, the Board adopted the USA Compression Partners, LP 2013 Long-Term Incentive Plan (the “LTIP”) for employees, consultants and directors of the General Partner and any of its affiliates who perform services for the Partnership. The LTIP consists of unit options, unit appreciation rights, restricted units, phantom units, distribution equivalent rights, unit awards, profits interest units and other unit-based awards. The LTIP initially limits the number of common units that may be delivered pursuant to awards under the plan to 1,410,000 common units. Awards that are forfeited, cancelled, paid or otherwise terminate or expire without the actual delivery of units will be available for delivery pursuant to other awards. The LTIP is administered by the Board or a committee thereof.

During the three months ended March 31, 2014, the Board approved a modification to the phantom unit awards that were granted pursuant to the LTIP during the 2013 fiscal year. The modification provided employees with an option of settling a portion of their award in cash and a portion in units.  The amount that can be settled in cash is in excess of the employee’s minimum statutory tax-withholding rate.  ASC Topic 718, Compensation-Stock Compensation, requires the entire amount of an award with such features to be accounted for as a liability.  Liability accounting requires the Partnership to re-measure the fair value of the award at each financial statement date until the award is vested or cancelled.  During the requisite service period, compensation cost is recognized using the proportionate amount of the award’s fair value that has been earned through service to date.

During the quarter ending March 31, 2014, the Partnership recorded an additional $0.5 million in unit-based compensation expense and re-classed $1.2 million from limited partner interest to accrued liabilities as a result of the above-described modification.

(8)  Transactions with Related Parties

For the three months ended March 31, 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 three months ended March 31, 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”) from 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 March 31, 2014 and 2013, subsidiaries of PVR made compression services payments to us of approximately $0.6 million and $0.7 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 owned and controlled the General Partner and owned 50.8% of our limited partner interests, as of May 5, 2014. For the three months ended March 31, 2014 and 2013, such controlled entities made compression service payments to the Partnership of approximately $0.1 million and $0.2 million, respectively. The Partnership may provide compression services to additional entities controlled by Riverstone in the future; and any significant transactions will be disclosed.

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(9)  Commitments and Contingencies

(a)  Operating Leases

Rent expense for office space, warehouse facilities and certain corporate equipment for the three months ended March 31, 2014 and 2013 was $0.5 million and $0.4 million, respectively. Commitments for future minimum lease payments on noncancelable leases as of March 31, 2014 are as follows (in thousands):

(b)  Major Customers

The Partnership had revenue from one customer representing 12.4% and 14.4% of total revenue for the three months ended March 31, 2014 and 2013, respectively.

(c)  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.

(d)  Equipment Purchase Commitments

The Partnership’s future capital commitments are comprised of binding commitments under purchase orders for new compression units ordered but not received. The commitments as of March 31, 2014 were approximately $169.2 million, all of which 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”) 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

We have generally experienced stable rates since 2011 through the three months ending March 31, 2014.  We have experienced some pricing pressure on certain of our midstream compression units, and expect that to continue through the remainder 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 expect to purchase approximately 300,000 horsepower of new compression unit equipment, 280,000 horsepower of which has already been ordered. Revenue generating horsepower increased by 37.0% from March 31, 2013 to March 31, 2014. We continue to have utilization rates of our fleet in excess of 90%. The average revenue generating horsepower increased by 36.6% from the three months ended March 31, 2013 to the three months ended March 31, 2014. We believe the activity levels in the U.S. will continue to increase, particularly in shale plays. According to the Annual Energy Outlook 2013 prepared by the Energy Information Agency (“EIA”), natural gas production from shale formations is expected to increase from 34% of total U.S. natural gas production in 2011 to 50% of total U.S. natural gas production in 2040. In addition, the EIA forecasts in its 2013 Outlook that total domestic crude oil production will increase by 33% from 2011 to 2019, and more importantly, forecasts tight oil production to increase by 128% over the same time period. We anticipate this activity will result in higher demand for our compression services, which we believe should result in increasing revenues. However, the expected increase in overall natural gas activity and demand for our compression services may not occur for a variety of reasons. Please read “Disclosure Regarding Forward-Looking Statements”.

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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 March 31, 2014, approximately 73,000 horsepower had been delivered and approximately 66,000 horsepower is expected to be delivered between April 2014 and June 2014, approximately 84,000 horsepower is expected to be delivered between July 2014 and September 2014, and approximately 57,000 horsepower is expected to be delivered between October 2014 and December 2014, totaling 280,000 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 each applicable period end was 87.0%, 89.0% and 85.7% for the quarters ended March 31, 2014, December 31, 2013 and March 31, 2013, 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 each applicable period was 87.8%, 89.0% and 86.1% for the quarters ended March 31, 2014, December 31, 2013 and March 31, 2013, respectively.

The following table summarizes other financial data for the periods presented.

(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 64.7% for the three months ended March 31, 2014 from 68.0% for the three months ended March 31, 2013. The decrease in gross operating margin, as a percentage of total revenues, was partially attributable to our gas lift compression units that have lower gross operating margins than our large horsepower midstream assets. Also contributing to the decrease was the timing of certain operating expenses in our midstream compression units in the first quarter of 2014.

The increase in cost of operations is attributable to (1) $1.6 million of higher lubrication oil expenses due to a 106.4% increase in gallons consumed, (2) a $2.6 million increase due to labor and salaries, (3) a $1.3 million increase in parts for maintenance expense, (4) a $0.4 million increase related to vehicle tools and gasoline, (5) a $0.4 million increase due to higher property and other taxes and (6) a $0.1 million increase due to higher retail service expenses. These factors 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 801,574 for the three months ended March 31, 2013 to 1,094,677 for the three months ended March 31, 2014, an increase of 36.6%, primarily due to growth in our midstream compression units along with the addition of assets in connection with the S&R Acquisition, as well as the higher rate charged on our gas lift assets. Average revenue per revenue generating horsepower per month increased from $13.59 for the three months ended March 31, 2013 to $15.30 for the three months ended March 31, 2014, an increase of 12.6%, 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 1,107,218 at March 31, 2014 compared to 807,988 at March 31, 2013, a 37.0% increase, primarily due to growth in our midstream compression units along with the S&R Acquisition.

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Financial Results of Operations

Three months ended March 31, 2014 compared to the three months ended March 31, 2013

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

Contract operations revenue. Contract operations revenue was $49.3 million for the three months ended March 31, 2014 compared to $31.9 million for the three months ended March 31, 2013, an increase of 54.7%, 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 801,574 for the three months ended March 31, 2013 to 1,094,677 for the three months ended March 31, 2014, an increase of 36.6%, 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 $13.59 for the three months ended March 31, 2013 to $15.30 for the three months ended March 31, 2014, an increase of 12.6%, 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 1,107,218 at March 31, 2014 compared to 807,988 at March 31, 2013, a 37.0% increase, primarily due to growth in our midstream compression units along with the S&R Acquisition.

Parts and service revenue. Parts and service revenue was $0.9 million for the three months ended March 31, 2014 compared to $0.7 million during the three months ended March 31, 2013, a 21.2% increase.

Cost of operations, exclusive of depreciation and amortization. Cost of operations was $17.7 million for the three months ended March 31, 2014 compared to $10.4 million for the three months ended March 31, 2013, an increase of 70.0%. The increase is primarily attributable to the increase in our fleet size, as well as certain other factors described below. The individual expenses increasing as a result of our fleet size include (1) a $1.6 million increase in lubrication oil expenses, attributable to a 106.4% increase in gallons consumed, primarily due to the timing of certain deliveries, (2) $2.6 million due to labor and salaries, (3) $1.3 million of parts for maintenance expense, (4) $0.4 million related to vehicle tools and gasoline, (5) a $0.4 million increase due to higher property and other taxes and (6) $0.1 million 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 cost of operations was 35.3% of revenue for the three months ended March 31, 2014 as compared to 32.0% for the three months ended March 31, 2013.

Selling, general and administrative expense. Selling, general and administrative expense was $8.5 million for the three months ended March 31, 2014 compared to $4.9 million for the three months ended March 31, 2013, an increase of 73.0%. Approximately $1.7 million of the increase in selling, general and administrative expense is related to a rise in salaries and benefits due to an increase in headcount to support the continued growth of the business, including the growth resulting from the S&R Acquisition as well as to support our operations as a public company.   Other significant increases include (1) a $1.0 million increase due to unit-based compensation expense, (2) a $0.3 million increase due to increased third-party professional fees and (3) a $0.3 million increase of outside services expense, all of which are attributable to increased employee headcount and support services. Selling, general and administrative expense represented 16.9% and 14.8% of revenue for the three months ended March 31, 2014 and 2013, respectively.

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Depreciation and amortization expense. Depreciation and amortization expense was $16.2 million for the three months ended March 31, 2014 compared to $11.7 million for the three months ended March 31, 2013, an increase of 38.9%. The increase is related to an increase in property, plant and equipment, including the S&R Acquisition, of 48.1% over these periods.

Interest expense. Interest expense was $3.5 million for the three months ended March 31, 2014 compared to $3.1 million for the three months ended March 31, 2013, an increase of 15.8%. Included in interest expense is amortization of deferred loan costs of $0.6 million and $0.5 million for the three months ended March 31, 2014 and 2013, respectively. Average borrowings outstanding under our revolving credit facility were $468.5 million for the three months ended March 31, 2014 compared to $363.0 million for the three months ended March 31, 2013. Interest expense for both periods was related to borrowings under our revolving credit facility. Our revolving credit facility had an interest rate of 2.15% and 2.45% at March 31, 2014 and 2013, respectively, and an average interest rate of 2.16% and 2.46% at March 31, 2014 and 2013, respectively.

Income tax expense. We incurred approximately $103,000 and $55,000 in franchise tax for the three months ended March 31, 2014 and 2013, respectively, as a result of the Texas franchise tax.

Liquidity and Capital Resources

Our primary sources of liquidity are cash generated from operations and amounts available under our revolving credit facility.  Our primary uses of cash have been for our operating expenses, capital expenditures and cash distributions to unitholders.   Our primary uses of cash have been for our operating expenses, capital expenditures and cash distributions to unitholders.  Depending on market conditions, in the future we may access the public or private capital markets to finance various partnership activities including reducing outstanding borrowings on our revolving credit facility and acquiring businesses or assets.

The following table summarizes our sources and uses of cash for the three months ended March 31, 2014 and 2013 as of the end of the periods presented (in thousands):

Net cash provided by operating activities. Net cash provided by operating activities increased to $10.1 million for the three months ended March 31, 2014, from $9.4 million for the three months ended March 31, 2013. The increase relates primarily to a higher operating margin offset by higher selling, general and administrative expenses and higher inventory purchases.

Net cash used in investing activities. Net cash used in investing activities increased to $86.7 million for the three months ended March 31, 2014, from $23.3 million for the three months ended March 31, 2013. The increase relates primarily to higher purchases of new compression units and related equipment in response to increasing demand.

Net cash provided by financing activities. Net cash provided by financing activities was $76.7 million for the three months ended March 31, 2014, compared to net cash provided by financing activities of $14.0 million for the three months ended March 31, 2013. The increase is primarily due to higher net borrowings to support our purchases of new compression unit equipment. Offsetting the increase is the $6.2 million distribution payment during the three months ended 2014 with respect to the fourth quarter of 2013; there was no such payment in the comparable period in 2013.

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.

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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 three months ended March 31, 2014 and 2013 were $5.3 million and $3.1 million, respectively.

Given our growth objective, we anticipate that we will continue to make significant expansion capital expenditures. Our expansion capital expenditures for the three months ended March 31, 2014 and 2013 were $81.5 million and $20.3 million, respectively.

In addition to organic growth, we may also consider a variety of assets or businesses for potential acquisition. We expect to fund any future acquisitions primarily with capital from external financing sources, such as issuance of debt and equity securities, including our issuance of additional partnership units and future debt offerings.

Description of Revolving Credit Facility

On June 1, 2012, we entered into the Fourth Amended and Restated Credit Agreement in order to provide a covenant structure that was more appropriate 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 our leverage ratio. This amended and restated credit agreement became effective on January 18, 2013, the closing date of our initial public offering, was secured by a first priority lien against our assets and had a schedule maturity of October 5, 2015. On December 10, 2012, we amended the Fourth Amended and Restated Credit Agreement to extend the periods during which the maximum funded debt to EBITDA ratio thresholds will apply.

On December 13, 2013, we entered into the Fifth Amended and Restated Credit Agreement whereby the aggregate commitment under the facility increased from $600 million to $850 million (subject to availability under a 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 our leverage ratio. The revolving credit facility is secured by a first priority lien against our assets and matures on December 13, 2018, at which point all amounts outstanding will become due.

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, we are in compliance with the facility’s financial covenants and (c) immediately after giving effect to such distribution, we have availability under the revolving credit facility of at least $20 million. In addition, the amended and restated credit agreement contains various covenants that may limit, among other things, our ability to (subject to certain exceptions):

·                  grant liens;

·                  make certain loans or investments;

·                  incur additional indebtedness or guarantee other indebtedness;

·                  enter into transactions with affiliates;

·                  merge or consolidate;

·                  sell our assets; or

·                  make certain acquisitions.

The Fifth Amended and Restated Credit Agreement also contains various financial covenants, including covenants requiring us 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.

As of March 31, 2014, we were in compliance with all of the covenants under the Fifth Amended and Restated Credit Agreement.

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Distribution Reinvestment Plan

On April 28, 2014, we filed a registration statement on Form S-3 (Reg. No. 333-195526) with the SEC to register the issuance of up to 6,100,000 of our common units in connection with a distribution reinvestment plan (“DRIP”), which became effective immediately upon filing. This registration statement replaces the registration statement on Form S-1 (Reg. No. 333-180551), which initially became effective on January 30, 2013, and pursuant to which we issued 1,552,749 common units in the DRIP.  The DRIP provides our common unitholders a means by which they can increase the number of common units they own by reinvesting the quarterly distributions they would otherwise receive in cash, into the purchase of additional common units.  As of May 5, 2014, 1,552,749 common units had been issued under this registration statement.

Total Contractual Cash Obligations

The following table summarizes our total contractual cash obligations as of March 31, 2014 (in thousands):

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

(2)         Represents future interest payments under our revolving credit facility based on the interest rate at March 31, 2014 of 2.15%.

(3)         Represents commitments for new compression units that are being fabricated.

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

Non-GAAP Financial Measures

We define Adjusted EBITDA as our net income before interest expense, income taxes, depreciation and amortization expense, unit-based compensation expense, gain (loss) on sale of assets, management fees and transaction expenses related to the S&R Acquisition. We view Adjusted EBITDA as one of our primary assessment measures, 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 and prior year and to budget. Adjusted EBITDA is used as a supplemental financial measure by our management and external users of our financial statements, such as investors and commercial banks, to assess:

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

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

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

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

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

Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income, operating income, 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.

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Adjusted EBITDA does not include interest expense, income taxes, depreciation and amortization expense, unit-based compensation expense, gain (loss) on sale of assets, management fees and transaction expenses related to the S&R Acquisition. Because we borrow money under our revolving credit facility and have historically utilized operating leases to finance our operations, interest expense and operating lease expense are necessary elements of our costs. Because we use capital assets, depreciation and impairment of compression equipment is also a necessary element of our costs. Unit-based compensation expense related to equity awards to employees is also necessary to operate 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 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 and net cash provided by operating activities, and these measures may vary among companies. Management compensates for the limitations of Adjusted EBITDA as an analytical tool by reviewing the comparable GAAP measures, understanding the differences between the measures and incorporating this knowledge into management’s decision making processes.

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