Form 10-Q Antero Midstream Partner For: Jun 30

T’s

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

(Mark One)

 

 

For the quarterly period ended June 30, 2015

 

OR

 

 

For the transition period from                    to                   

 

Commission file number: 001-36719

 

ANTERO MIDSTREAM PARTNERS LP

(Exact name of registrant as specified in its charter)

 

 

(303) 357-7310

(Registrant’s telephone number, including area code)

 

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  ☒ Yes  ☐ No

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).  ☒ Yes  ☐ No

 

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

 

 

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

 

As of July 24, 2015, there were 75,965,011  common units and 75,940,957 subordinated units outstanding.

 

 

 

 

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TABLE OF CONTENTS 

 

 

 

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Some of the information in this report may contain forward-looking statements. Forward-looking statements give our current expectations, contain projections of results of operations or of financial condition, or forecasts of future events. Words such as “may,” “assume,” “forecast,” “position,” “predict,” “strategy,” “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe,” “project,” “budget,” “potential,” or “continue,” and similar expressions are used to identify forward-looking statements. They can be affected by assumptions used or by known or unknown risks or uncertainties. Consequently, no forward-looking statements can be guaranteed. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this report. Actual results may vary materially. You are cautioned not to place undue reliance on any forward-looking statements. You should also understand that it is not possible to predict or identify all such factors and should not consider the following list to be a complete statement of all potential risks and uncertainties. Factors that could cause our actual results to differ materially from the results contemplated by such forward-looking statements include:

We caution you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the gathering and compression business. These risks include, but are not limited to, commodity price volatility, inflation, environmental risks, drilling and completion and other operating risks, regulatory changes, the uncertainty inherent in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described under “Risk Factors” in this report and in our Annual Report on Form 10-K for the year ended December 31, 2014, filed with the Securities and Exchange Commission on February 25, 2015.

Should one or more of the risks or uncertainties described in this report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements.

All forward-looking statements, expressed or implied, included in this report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue.

Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this report.

 

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PART I—FINANCIAL INFORMATION

Item 1.Financial Statements

 

ANTERO MIDSTREAM PARTNERS LP

Condensed Consolidated Balance Sheets

December 31, 2014, and June 30, 2015

(Unaudited)

(In thousands, except unit counts)

 

 

 

 

See accompanying notes to condensed consolidated financial statements. 

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ANTERO MIDSTREAM PARTNERS LP

Condensed Consolidated Statements of Operations and Comprehensive Income (Loss)

Three Months Ended June  30, 2014, and 2015

(Unaudited)

(In thousands, except unit counts and per unit amounts)

 

 

See accompanying notes to condensed consolidated financial statements.

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ANTERO MIDSTREAM PARTNERS LP

Condensed Consolidated Statements of Operations and Comprehensive Income

Six Months Ended June 30, 2014,  and 2015

(Unaudited)

(In thousands, except unit counts and per unit amounts)

 

 

See accompanying notes to condensed consolidated financial statements.

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ANTERO MIDSTREAM PARTNERS LP

Condensed Consolidated Statements of Partners’ Capital

Six  Months Ended June 30, 2015

(Unaudited)

(In thousands)

 

See accompanying notes to condensed consolidated financial statements.

 

 

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ANTERO MIDSTREAM PARTNERS LP

Condensed Consolidated Statements of Cash Flows

Six  Months Ended June 30, 2014,  and 2015

(Unaudited)

(In thousands)

 

 

See accompanying notes to condensed consolidated financial statements. 

 

 

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(1)Business and Organization

 

Antero Midstream Partners LP (the “Partnership”) is a growth-oriented limited partnership formed by Antero Resources Corporation (“Antero”) to own, operate and develop midstream assets to service Antero’s natural gas and oil and condensate production.  On November 10, 2014, the Partnership completed its initial public offering (the “IPO”) of 46,000,000 common units representing limited partnership interests at a price of $25.00 per common unit.  The Partnership was originally formed as Antero Resources Midstream LLC and converted to a limited partnership in connection with the completion of the IPO.  At the closing of the IPO, Antero contributed substantially all of its high and low pressure gathering and compression assets to Antero Midstream LLC (“Midstream Operating”), and the equity interests of Midstream Operating were contributed to the Partnership.

Our condensed consolidated financial statements as of December 31, 2014 and June 30, 2015 include the accounts of the Partnership and Midstream Operating.

Our assets consist of 8‑, 12‑, 16‑, and 20‑inch high and low pressure gathering pipelines and compressor stations that collect natural gas and oil and condensate from Antero’s wells in the Marcellus Shale in West Virginia and the Utica Shale in Ohio.

We have agreements with Antero pursuant to which we will provide gathering and compression services for a 20-year period and a services agreement whereby Antero provides operational and management services to us.

In connection with the IPO, we obtained an option for two years to purchase Antero’s integrated water business at fair market value, with a right of first offer thereafter. Further, we have a right to participate for up to a 15% non‑operating equity interest in an unnamed 50‑mile regional gathering pipeline extension (the “Regional Gathering System”) that will expire six months following the date on which the Regional Gathering System is placed into service. In addition, we have entered into a right‑of‑first‑offer agreement with Antero to allow for us to provide Antero with gas processing or NGLs fractionation, transportation or marketing services in the future. 

 

(2)Summary of Significant Accounting Policies

(a) Basis of Presentation

 

These condensed consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”) applicable to interim financial information, and should be read in the context of the December 31, 2014 consolidated financial statements and notes thereto for a more complete understanding of the Partnership’s operations, financial position, and accounting policies.  The December 31, 2014 consolidated financial statements have been filed with the SEC in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 (the “2014 Form 10-K”).

 

The accompanying unaudited condensed consolidated financial statements of the Partnership have been prepared in accordance with United States generally accepted accounting principles (“U.S. GAAP”) for interim financial information, and, accordingly, do not include all of the information and footnotes required by U.S. GAAP for complete consolidated financial statements. In the opinion of management, these statements include all adjustments (consisting of normal and recurring accruals) considered necessary for a fair presentation of the Partnership’s financial position as of December 31, 2014 and June 30, 2015, the results of its operations for the three and six months ended June 30, 2014 and 2015 and its cash flows for the six months ended June 30, 2014 and 2015. The Partnership has no items of other comprehensive income or loss; therefore, its net income (loss) is identical to its comprehensive income (loss).  Operating results for the period ended June 30, 2015 are not necessarily indicative of the results that may be expected for the full year.

The accompanying condensed consolidated financial statements present the assets, liabilities, and results of operations of Antero’s gathering and compression assets as the accounting predecessor (the “Predecessor”) to the Partnership, presented on a carve-out basis of Antero’s historical ownership of the Predecessor. The Predecessor financial statements have been prepared from the separate records maintained by Antero and may not necessarily be indicative of the actual results of operations that might have occurred if the Predecessor had been operated separately during the periods reported. References in these financial statements to “Predecessor,” “we,” “our,” “us” or like terms, when referring to periods prior to November 10, 2014, refer to the

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Predecessor as defined above.  References to “the Partnership,” “we,” “our,” “us” or like terms, when referring to periods since November 10, 2014 or when used in the present tense or prospectively, refer to the Partnership.

Certain costs of doing business which are incurred by Antero on our behalf have been reflected in the accompanying condensed consolidated financial statements. These costs include general and administrative expenses allocated to us by Antero in exchange for:

Transactions between us and Antero have been identified in the condensed consolidated financial statements as transactions between affiliates (see Note 3).

As of the date these condensed consolidated financial statements were filed with the SEC, the Partnership completed its evaluation of potential subsequent events for disclosure and no items requiring disclosure were identified, except the declaration of a cash distribution to unitholders, as described in Note 6—Partnership Equity and Distributions.

(b)Revenue Recognition

We provide gathering and compression services under fee‑based contracts based on throughput. Under these arrangements, we receive fees for gathering oil and gas products and compression services. The revenue we earn from these arrangements is directly related to (1) in the case of natural gas gathering and compression, the volumes of metered natural gas that we gather, compress and deliver to natural gas compression sites or other transmission delivery points or (2) in the case of oil and condensate gathering, the volumes of metered oil and condensate that we gather and deliver to other transmission delivery points. We recognize revenue when all of the following criteria are met: (1) persuasive evidence of an agreement exists, (2) services have been rendered, (3) prices are fixed or determinable and (4) collectability is reasonable assured.

(c)Use of Estimates

The preparation of the condensed consolidated financial statements and notes in conformity with U.S. GAAP requires that management formulate estimates and assumptions that affect revenues, expenses, assets, liabilities and the disclosure of contingent assets and liabilities. Items subject to estimates and assumptions include the useful lives of property and equipment and valuation of accrued liabilities, among others. Although management believes these estimates are reasonable, actual results could differ from these estimates.

(d)Cash and Cash Equivalents

Prior to the IPO, the Predecessor’s operations were funded by Antero. Net amounts funded by Antero are reflected as net contributions from or distributions to parent on the accompanying Statements of Cash Flows.

We consider all liquid investments purchased with an initial maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short‑term nature of these instruments.

(e)Property and Equipment

Property and equipment primarily consists of gathering pipelines and compressor stations stated at historical cost less accumulated depreciation. We capitalize construction‑related direct labor and material costs. Maintenance and repair costs are expensed as incurred.

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Depreciation is computed using the straight‑line method over the estimated useful lives and salvage values of assets. Uncertainties that may impact these estimates of useful lives include, among others, changes in laws and regulations relating to environmental matters, including air and water quality, restoration and abandonment requirements, economic conditions, and supply and demand for our services in the areas in which we operate. When assets are placed into service, management makes estimates with respect to useful lives and salvage values that management believes are reasonable. However, subsequent events could cause a change in estimates, thereby impacting future depreciation amounts.

Our investment in property and equipment for the periods presented is as follows:

 

 

(f)Impairment of Long‑Lived Assets

We evaluate our long‑lived assets for impairment when events or changes in circumstances indicate that the related carrying values of the assets may not be recoverable.  Generally, the basis for making such assessments is undiscounted future cash flow projections for the unit being assessed.  If the carrying values of the assets are deemed not recoverable, the carrying values are reduced to the estimated fair value, which is based on discounted future cash flows or other techniques, as appropriate.  No impairments for such assets have been recorded through June 30, 2015.

(g)Asset Retirement Obligations

Our gathering pipelines and compressor stations have an indeterminate life, if properly maintained. A liability for these asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life can be estimated. Because we are not able to make a reasonable estimate of when future dismantlement and removal dates of such assets will occur, we have not recorded asset retirement obligations at December 31, 2014 or June 30, 2015.

(h)Litigation and Other Contingencies

An accrual is recorded for a loss contingency when its occurrence is probable and damages can be reasonably estimated based on the anticipated most likely outcome or the minimum amount within a range of possible outcomes. We regularly review contingencies to determine the adequacy of our accruals and related disclosures. The ultimate amount of losses (if any) may differ from these estimates.

We accrue losses associated with environmental obligations when such losses are probable and can be reasonably estimated. Accruals for estimated environmental losses are recognized no later than at the time a remediation feasibility study, or an evaluation of response options, is complete. These accruals are adjusted as additional information becomes available or as circumstances change. Future environmental expenditures are not discounted to their present value. Recoveries of environmental costs from other parties are recorded separately as assets at their undiscounted value when receipt of such recoveries is probable.

No events have occurred that require accruals for loss contingencies or environmental obligations at December 31, 2014 or June 30, 2015.

(i)Equity‑Based Compensation

Our condensed consolidated financial statements reflect various equity‑based compensation awards granted by Antero, as well as compensation expense associated with our own plan. These awards include profits interests awards, restricted stock, stock options, restricted units, and phantom units. For purposes of these condensed consolidated financial statements, we

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recognized as expense in each period an amount allocated from Antero, with the offset included in partners’ capital. See Note 3—Transactions with Affiliates for additional information regarding Antero’s allocation of expenses to us.

In connection with the IPO, our general partner adopted the Antero Midstream Partners LP Long-Term Incentive Plan (“Midstream LTIP”), pursuant to which certain non‑employee directors of our general partner and certain officers, employees and consultants of our general partner and its affiliates are eligible to receive awards representing equity interests in the Partnership. An aggregate of 10,000,000 common units may be delivered pursuant to awards under the Midstream LTIP, subject to customary adjustments. For accounting purposes, these units are treated as if they are distributed from us to Antero. Antero recognizes compensation expense for the units awarded to its employees and a portion of that expense is allocated to us. See Note 5—Equity-Based Compensation.

 

(j)Income Taxes

Our condensed consolidated financial statements do not include a provision for income taxes as we are treated as a partnership for federal and state income tax purposes, with each partner being separately taxed on its share of taxable income.

 (k)Fair Value Measures

The Financial Accounting Standards Board (the “FASB”) Accounting Standards Codification Topic 820, Fair Value Measurements and Disclosures, clarifies the definition of fair value, establishes a framework for measuring fair value, and expands disclosures about fair value measurements. This guidance also relates to all nonfinancial assets and liabilities that are not recognized or disclosed on a recurring basis (e.g., the initial recognition of asset retirement obligations and impairments of long‑lived assets). The fair value is the price that we estimate would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy is used to prioritize inputs to valuation techniques used to estimate fair value. An asset or liability subject to the fair value requirements is categorized within the hierarchy based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. The highest priority (Level 1) is given to unadjusted quoted market prices in active markets for identical assets or liabilities, and the lowest priority (Level 3) is given to unobservable inputs. Level 2 inputs are data, other than quoted prices included within Level 1, that are observable for the asset or liability, either directly or indirectly.

The carrying values on our balance sheet of our cash and cash equivalents, accounts receivable—affiliate, prepaid expenses, other assets, accounts payable, accounts payable—affiliate, accrued liabilities, accrued capital expenditures, accrued ad valorem tax, and the revolving credit facility approximate fair values due to their short maturities. 

(l) Reclassifications   

Certain reclassifications have been made to prior periods’ financial information related to direct operating expenses to conform that information to our current period presentation. These reclassifications did not have an impact on net income for the periods previously reported.

(3)Transactions with Affiliates

(a)Revenues

All revenues during the three and six months ended June 30, 2014 and 2015 were earned from services performed for Antero.

(b)Accounts receivable—affiliate, and Accounts payable—affiliate

Accounts receivable—affiliate represents amounts due from Antero, primarily related to gathering and compression services and other costs. Accounts payable—affiliate represents amounts due to Antero for general and administrative and other costs.

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(c)Allocation of Costs

The employees supporting our operations are employees of Antero. Direct operating expense includes allocated costs of $0.3 million and $0.8 million during the three months ended June 30, 2014 and 2015, respectively, and $0.5 million and $1.4 million during the six months ended June 30, 2014 and 2015, respectively, related to direct labor charges for Antero employees associated with the operation of our gathering lines and compressor stations. General and administrative expense includes allocated costs of $5.8 million and $9.2 million during the three months ended June 30, 2014 and 2015, respectively, and $9.6 million and $17.7 million during the six months ended June 30, 2014 and 2015, respectively. These costs relate to: (i) various business services, including payroll processing, accounts payable processing and facilities management, (ii) various corporate services, including legal, accounting, treasury, information technology and human resources and (iii) compensation, including equity‑based compensation (see Note 5—Equity-Based Compensation for more information). These expenses are charged or allocated to us based on the nature of the expenses and are allocated based on a combination of our proportionate share of Antero’s gross property and equipment, capital expenditures and direct labor costs, as applicable.

(4)Long‑Term Debt

 

(a)Predecessor Credit Facility

 

Prior to the IPO on November 10, 2014, long-term debt represented amounts outstanding under a credit facility agreement between Midstream Operating, then a wholly owned subsidiary of Antero and now a wholly owned subsidiary of the Partnership, and the lenders under Antero’s credit facility, that were incurred for the acquisition and construction of the Predecessor’s gathering and compression assets (the “predecessor credit facility”).  Interest expense during the three and six months ended June 30, 2014 includes interest and commitment fees incurred under the predecessor credit facility. On November 10, 2014, in connection with the completion of the IPO, the outstanding balance of the predecessor credit facility was repaid out of the proceeds of the IPO, and this facility was assumed by Antero. 

 

(b)Revolving Credit Facility

 

On November 10, 2014, in connection with the closing of the IPO, the Partnership entered into a revolving credit facility with a syndicate of bank lenders (the “revolving credit facility”). The revolving credit facility provides for lender commitments of $1.0 billion and a letter of credit sublimit of $150 million. The revolving credit facility will mature on November 10, 2019.

 

The revolving credit facility is ratably secured by mortgages on substantially all of our properties, including the properties of our restricted subsidiaries, and guarantees from our restricted subsidiaries. The revolving credit facility contains certain covenants including restrictions on indebtedness and distributions, and requirements with respect to leverage and interest coverage ratios. The Partnership was in compliance with all of the financial covenants under the revolving credit facility as of December 31, 2014 and June 30, 2015.

 

Principal amounts borrowed are payable on the maturity date with such borrowings bearing interest that is payable quarterly or, in the case of Eurodollar Rate Loans, at the end of the applicable interest period if shorter than three months. Interest is payable at a variable rate based on LIBOR or the base rate, determined by election at the time of borrowing. Commitment fees on the unused portion of the revolving credit facility are due quarterly at rates ranging from 0.25% to 0.375% of the unused facility based on utilization.

 

At December 31, 2014 and June 30, 2015, we had no borrowings or letters of credit outstanding under the revolving credit facility.

(5)Equity-Based Compensation

 

Our general and administrative expenses include equity-based compensation costs allocated to us by Antero for grants made pursuant to: (i) the Antero Resources Corporation Long‑Term Incentive Plan (the “Antero LTIP”); (ii) profits interests awards valued in connection with the Antero reorganization pursuant to its initial public offering of common stock, which closed on October 16, 2013; and (iii) the Midstream LTIP.  Equity‑based compensation expense allocated to us was $2.5 million and $5.4 million for the three months ended June 30, 2014 and 2015, respectively, and $3.8 million and $10.0 million for the six

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months ended June 30, 2014 and 2015, respectively. These expenses were allocated to us based on our proportionate share of Antero’s direct labor costs. Antero has unamortized expense totaling approximately $197 million as of June 30, 2015 related to its various equity-based compensation plans and the Midstream LTIP. A portion of this will be allocated to us as it is amortized over the remaining service period of the related awards.

Midstream LTIP

 

Our general partner manages our operations and activities and Antero employs the personnel who provide support to our operations. In connection with the IPO, our general partner adopted the Midstream LTIP, pursuant to which non‑employee directors of our general partner and certain officers, employees and consultants of our general partner and its affiliates are eligible to receive awards representing ownership interests in the Partnership. An aggregate of 10,000,000 common units may be delivered pursuant to awards under the Midstream LTIP, subject to customary adjustments.  A total of 7,654,863 common units are available for future grant under the Midstream LTIP as of June 30, 2015. Restricted units and phantom units granted under the Midstream LTIP vest subject to the satisfaction of service requirements, upon the completion of which common units in the Partnership are delivered to the holder of the restricted units or phantom units. Compensation related to each restricted unit and phantom unit award is recognized on a straight-line basis over the requisite service period of the entire award.  The grant date fair values of these awards are determined based on the closing price of the Partnership’s common units on the date of grant. These units are accounted for as if they are distributed by the Partnership to Antero. Antero recognizes compensation expense for the units awarded and a portion of that expense is allocated to the Partnership. Antero allocates equity-based compensation expense to the Partnership based on our proportionate share of Antero’s direct labor costs. The Partnership’s portion of the equity-based compensation expense is included in general and administrative expenses.

 

A summary of restricted unit and phantom unit awards activity during the three months ended June 30, 2015 is as follows:

 

Intrinsic values are based on the closing price of the Partnership’s common units on the referenced dates.  Unamortized expense of $57 million at June 30, 2015 is expected to be recognized by Antero over a weighted average period of approximately 3.3 years. A proportionate share of the expense will be allocated to us as it is recognized by Antero.

 

(6)Partnership Equity and Distributions

 

Our Minimum Quarterly Distribution

 

Our partnership agreement provides for a minimum quarterly distribution of $0.17 per unit for each quarter, or $0.68 per unit on an annualized basis.

Our partnership agreement generally provides that we distribute cash each quarter during the subordination period in the following manner:

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If cash distributions to our unitholders exceed $0.1955 per common unit and subordinated unit in any quarter, our unitholders and our general partner, as the holder of our incentive distribution rights (“IDRs”), will receive distributions according to the following percentage allocations:

 

 

General Partner Interest

 

Our general partner owns a non‑economic general partner interest in us, which does not entitle it to receive cash distributions. However, our general partner owns the incentive distribution rights and may in the future own common units or other equity interests in us and will be entitled to receive distributions on any such interests.

 

Subordinated Units

 

Antero owns all of our subordinated units. The principal difference between our common units and subordinated units is that, for any quarter during the subordination period, holders of the subordinated units are not entitled to receive any distribution from operating surplus until the common units have received the minimum quarterly distribution from operating surplus for such quarter plus any arrearages in the payment of the minimum quarterly distribution from prior quarters. Subordinated units will not accrue arrearages. When the subordination period ends, all of the subordinated units will convert into an equal number of common units. The subordination period will end on the first business day after we have earned and paid at least $0.68 (the minimum quarterly distribution on an annualized basis) on each outstanding common unit and subordinated unit for each of three consecutive, non-overlapping four-quarter periods ending on or after September 30, 2017 and there are no outstanding arrearages on our common units.

 

To the extent we do not pay the minimum quarterly distribution on our common units, our common unitholders will not be entitled to receive such arrearage payments in the future except during the subordination period. To the extent we have cash available for distribution from operating surplus in any future quarter during the subordination period in excess of the amount necessary to pay the minimum quarterly distribution to holders of our common units, we will use this excess cash to pay any distribution arrearages on common units related to prior quarters before any cash distribution is made to holders of subordinated units.

Cash Distributions

 

On July 15, 2015, we announced that the board of directors of our general partner declared a cash distribution of $0.19 per unit for the quarter ended June 30, 2015. The distribution will be payable on August 27, 2015 to unitholders of record as of August 13, 2015.

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The allocation of total quarterly cash distributions to our partners is as follows for the three and six months ended June 30, 2015. Our distributions are declared subsequent to quarter end; therefore the following table represents total cash distributions applicable to the period in which distributions were earned.

 

 

 

 

(7)Net Income Per Limited Partner Unit

 

Net Income Per Limited Partner Unit

The Partnership’s net income is allocated to the general partner and limited partners, including subordinated unitholders, in accordance with their respective ownership percentages, and when applicable, giving effect to incentive distributions paid to the general partner. Basic and diluted net income per limited partner unit is calculated by dividing limited partners’ interest in net income, less general partner incentive distributions, by the weighted average number of outstanding limited partner units during the period.

 

We compute earnings per unit using the two-class method for master limited partnerships. Under the two-class method, earnings per unit is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.

 

We calculate net income available to limited partners based on the distributions pertaining to the current period’s net income. After adjusting for the appropriate period’s distributions, the remaining undistributed earnings or excess distributions over earnings, if any, are allocated to the general partner and limited partners in accordance with the contractual terms of the partnership agreement under the two-class method.

 

Basic earnings per unit is computed by dividing net earnings attributable to unitholders by the weighted average number of units outstanding during each period. Diluted net income per limited partner unit reflects the potential dilution that could occur if agreements to issue common units, such as awards under long-term incentive plans, were exercised, settled or converted into common units. When it is determined that potential common units resulting from an award should be included in the diluted net income per limited partner unit calculation, the impact is reflected by applying the treasury stock method. Earnings per common unit assuming dilution for the three months ended June 30, 2015 was calculated based on the diluted weighted average number of units outstanding of 75,957,984, including 17,027 dilutive units attributable to non-vested restricted unit and phantom unit awards. Earnings per common unit assuming dilution for the six months ended June 30, 2015 was calculated based on the diluted weighted average number of units outstanding of 75,956,354, including 15,397 dilutive units attributable to non-vested restricted unit and phantom unit awards. For the three and six months ended June 30, 2015, 2,319,412 and 2,316,264 non-vested phantom unit and restricted unit awards, respectively, were anti-dilutive and therefore excluded from the calculation of diluted earnings per unit.

 

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The Partnership’s calculation of net income per common and subordinated unit for the periods indicated is as follows:

 

 

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(8)  Contingencies

 

Environmental Obligations

We are subject to federal, state and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. We believe there are currently no such matters that will have a material adverse effect on our results of operations, cash flows or financial position.

 

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

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our condensed consolidated financial statements and related notes included elsewhere in this report. The information provided below supplements, but does not form part of, our condensed consolidated financial statements. This discussion contains forward‑looking statements that are based on the views and beliefs of our management, as well as assumptions and estimates made by our management. Actual results could differ materially from such forward‑looking statements as a result of various risk factors, including those that may not be in the control of management. For further information on items that could impact our future operating performance or financial condition, please read see “Item 1A. Risk Factors.” and the section entitled “Cautionary Statement Regarding Forward‑Looking Statements.” We do not undertake any obligation to publicly update any forward-looking statements except as otherwise required by applicable law. For more information please refer to the Annual Report on Form 10-K for the year ended December 31, 2014, filed with the SEC on February 25, 2015.

References in this report to “Predecessor,” “we,” “our,” “us” or like terms, when referring to periods prior to November 10, 2014, refer to Antero’s gathering and compression assets, our predecessor for accounting purposes.  References to “the Partnership,” “we,” “our,” “us” or like terms, when referring to periods since November 10, 2014 or when used in the present tense or prospectively, refer to Antero Midstream Partners LP.

Overview

We are a growth‑oriented limited partnership formed by Antero to own, operate and develop midstream energy assets to service Antero’s rapidly increasing production. Our assets consist of gathering pipelines and compressor stations, through which we provide midstream services to Antero under a long‑term, fixed‑fee contract. Our assets are located in the rapidly developing liquids‑rich southwestern core of the Marcellus Shale in northwest West Virginia and the liquids‑rich core of the Utica Shale in southern Ohio, two of the premier North American shale plays. We believe that our strategically located assets and our relationship with Antero position us to become a leading midstream energy company serving the Marcellus and Utica Shales.

Address, Internet Website and Availability of Public Filings

Our principal executive offices are at 1615 Wynkoop Street, Denver, Colorado 80202.  Our telephone number is (303) 357-7310. Our website is located at www.anteromidstream.com.

We make available our Annual Reports on Form 10-K, our Quarterly Reports on Form 10-Q, and our Current Reports on Form 8-K.  These documents are located www.anteromidstream.com under the “Investors Relations” link.

Information on our website is not incorporated into this Quarterly Report on Form 10-Q or our other filings with the SEC and is not a part of them.

2015 Developments and Highlights

 

Energy Industry Environment 

 

We have a gathering and compression agreement with Antero which provides for a fixed fee structure, and we intend to continue to pursue additional fixed fee opportunities with Antero and third parties in order to avoid direct commodity price exposure. However, to the extent that our future contractual arrangements with Antero or third parties do not provide for fixed fee structures, we may become subject to commodity price risk. We are subject to commodity price risks to the extent that they impact Antero’s development plan and therefore our gathering volumes. In late 2014, global energy commodity prices declined precipitously as a result of several factors, including an increase in worldwide commodity supplies, a stronger U.S. dollar, relatively mild weather in large portions of the U.S. during winter months, and strong competition among oil producing countries for market share. Commodity prices have continued to remain low through the second quarter of 2015; prices for West Texas Intermediate have remained at or below $60 per Bbl, and Henry Hub natural gas prices have remained below $3.00 per MMBtu. In response to these market conditions and concerns about access to capital markets, many U.S. exploration and development companies significantly reduced their capital spending plans for 2015. Antero’s capital budget for 2015 is $1.8 billion, a 49% reduction from 2014 capital expenditures.  Antero

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plans to operate an average of 14 drilling rigs in 2015 as compared to an average of 21 rigs in 2014, and plans to complete 130 horizontal wells in the Marcellus and Utica Shales in 2015 as compared to 177 in 2014.    

 

Operating and Financial Results

 

For the three months ended June 30, 2015, we generated cash flow from operations of $44.5 million, net income of $19.5 million, and Adjusted EBITDA of $40.8 million. This compares to cash flow from operations of $10.4 million, net loss of $0.7 million, and Adjusted EBITDA of $11.4 million for the three months ended June 30, 2014.  See “—Non-GAAP Financial Measure” for a definition of Adjusted EBITDA (a non-GAAP measure) and a reconciliation of Adjusted EBITDA to net income.

 

For the six months ended June 30, 2015, we generated cash flow from operations of $84.3 million, net income of $35.1 million, and Adjusted EBITDA of $76.4 million. This compares to cash flow from operations of $17.0 million, net income of less than $0.1 million, and Adjusted EBITDA of $19.8 million for the six months ended June 30, 2014.  See “—Non-GAAP Financial Measure” for a definition of Adjusted EBITDA (a non-GAAP measure) and a reconciliation of Adjusted EBITDA to net income.

 

Our low pressure, high pressure, compression and condensate daily volumes totaled 965 MMcf/d, 1,197 MMcf/d, 454 MMcf/d, and 3 MBbl/d respectively, for the three months ended June 30, 2015. This compares to low pressure, high pressure,  compression and condensate daily volumes totaling 386 MMcf/d, 266 MMcf/d, 41 MMcf/d, and 3 MBbl/d respectively, for the three months ended June 30, 2014.

 

Our low pressure, high pressure, compression and condensate daily volumes totaled 950 MMcf/d, 1,166 MMcf/d, 406 MMcf/d, and 3 MBbl/d respectively, for the six months ended June 30, 2015. This compares to low pressure, high pressure,  compression and condensate daily volumes totaling 359 MMcf/d, 196 MMcf/d, 39 MMcf/d, and 1 MBbl/d respectively, for the six months ended June 30, 2014.

 

Distribution for the Second Quarter for 2015

 

On July 15, 2015, we announced that the board of directors of our general partner declared a  cash distribution of $0.19 per unit for the quarter ended June 30, 2015, totaling approximately $28.9 million. The distribution will be payable on August 27, 2015 to unitholders of record as of August 13, 2015.

 

2015 Capital Budget

 

During the three and six months ended June 30, 2015, our total capital expenditures were approximately $74.1 million and $200.1 million, respectively. During 2015, we plan to continue to expand our existing Marcellus and Utica Shale gathering and compression systems to accommodate Antero’s development plans. Our capital budget for 2015 is $425 to $450 million, which includes $415 to $435 million and $10 to $15 million in expansion and maintenance capital, respectively.  This capital budget includes $250 to $260 million of gathering infrastructure, which will result in 44 miles and 20 miles of additional low pressure and high pressure gathering pipelines, respectively, in both the Marcellus and Utica Shale plays combined. Additionally, the budget includes the construction or expansion of five compressor stations, which will add 545 MMcf/d of incremental compression capacity in 2015. At December 31, 2015, we expect to have 180 miles of low pressure gathering lines, 117 miles of high pressure gathering lines, and 920 MMcf/d of compression capacity in service.

 

Credit Facility

 

Current lender commitments under our revolving credit facility are $1.0 billion, with a letter of credit sublimit of $150 million. At June 30, 2015, we had no borrowings or letters of credit outstanding under the revolving credit facility. Our revolving credit facility matures in November 2019.  See “—Debt Agreements and Contractual Obligations—Revolving Credit Facility” for a description of our revolving credit facility.

 

Private Letter Ruling

 

On May 26, 2015, we received a favorable private letter ruling from the U.S. Internal Revenue Service providing that gross income earned by the Partnership from (i) the delivery of water for use in the exploration and production of oil and gas and (ii) the

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collection, treatment and transport of flowback, produced water, other fluids and residual salt that are byproducts of the exploration and production of oil and gas will constitute “qualifying income” under section 7704(d)(1)(E) of the Internal Revenue Code of 1986, as amended. In order for the Partnership to maintain its classification as a partnership for U.S. federal income tax purposes, at least 90% of its gross income must be “qualifying income.”

 

In connection with the IPO, we obtained an option for two years to purchase Antero’s integrated water business at fair market value, with a right of first offer thereafter. Further, we have a right to participate for up to a 15% non‑operating equity interest in an unnamed 50‑mile regional gathering pipeline extension (the “Regional Gathering System”) that will expire six months following the date on which the Regional Gathering System is placed into service. In addition, we have entered into a right‑of‑first‑offer agreement with Antero to allow for us to provide Antero with gas processing or NGLs fractionation, transportation or marketing services in the future.

 

Items Affecting Comparability of Our Financial Results

The historical financial results discussed below may not be comparable to our future financial results primarily as a result of the significant increase in the scope of our operations over the last several years. Our gathering and compression systems are relatively new, having been substantially built within the last three years. Accordingly, our revenues and expenses over that time reflect the significant ramp up in our operations. Similarly, Antero has experienced significant growth in its production and drilling and completion schedule over that same period. Accordingly, it may be difficult to accurately project future trends in our operations based on our historical financial data.

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Results of Operations

Three Months Ended June 30, 2014 Compared to Three Months Ended June 30, 2015

The following table sets forth selected operating data for the three months ended June 30, 2014 compared to the three months ended June 30, 2015:

 

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*Not meaningful or applicable.

Gathering and compression revenue—affiliate.  Revenues from gathering of natural gas and condensate and compression of natural gas increased from $16.9 million for the three months ended June 30, 2014 to $56.6 million for the three months ended June 30, 2015, an increase of $39.7 million. Specifically:

Direct operating expenses.  Total direct operating expenses increased from $2.2 million for the three months ended June 30, 2014 to $11.3 million for the three months ended June 30, 2015, an increase of $9.1 million. The increase was primarily due to an increase in the number of gathering pipelines and compressor stations, as well as an increase in ad valorem tax expense as a result of more gathering and compression assets in West Virginia.

General and administrative expenses.  General and administrative expenses (before equity-based compensation) increased from $3.3 million for the three months ended June 30, 2014 to $4.5 million for the three months ended June 30, 2015, an increase of $1.2 million. The increase was primarily a result of increased staffing levels and related salary and benefits expenses and increased legal and other general corporate expenses to support our growth, as well as additional expenditures attributable to our operation as a publicly traded partnership.

Equity-based compensation expense. Equity-based compensation expense increased from $2.5 million for the three months ended June 30, 2014 to $5.4 million for the three months ended June 30, 2015, an increase of $2.9 million. The increase was primarily a result of equity-based compensation expense allocated to us by Antero related to (i) awards made under the Antero Resources Corporation Long‑Term Incentive Plan after June 30, 2014 and (ii) awards made to Antero employees and officers, and to non-employee directors of our general partner under the Antero Midstream Partners LP Long-Term Incentive Plan after June 30, 2014. Equity-based compensation expense allocated to us from Antero has no effect on our cash flows.

Depreciation expense.  Total depreciation expense increased from $8.7 million for the three months ended June 30, 2014 to $15.1 million for the three months ended June 30, 2015, an increase of $6.4 million. The increase was primarily due to gathering and compression assets placed in service after June 30, 2014.

Interest expense.  Interest expense decreased from $1.0 million for the three months ended June 30, 2014 to $0.8 million for the three months ended June 30, 2015, a decrease of $0.2 million. The decrease is primarily due to interest and commitment fees incurred during the three months ended June 30, 2014 under the predecessor credit facility that was repaid in connection with the completion of the IPO, partially offset by commitment fees and amortization of deferred financing fees incurred during the three months ended June 30, 2015 in relation to our revolving credit facility.

 

Adjusted EBITDA.  Adjusted EBITDA increased from $11.4 million for the three months ended June 30, 2014 to $40.8 million for the three months ended June 30, 2015, an increase of $29.4 million. The increase was primarily due to an increase in gathering and compression throughput volumes during the three months ended June 30, 2015, net of the related increases in operating and general and administrative expenses. For a discussion of the non-GAAP financial measure Adjusted EBITDA, including a reconciliation of Adjusted EBITDA to its most directly comparable financial measures calculated and presented in accordance with GAAP, please see “—Non-GAAP Financial Measure” below.

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Six Months Ended June 30, 2014 Compared to Six Months Ended June 30, 2015

The following table sets forth selected operating data for the six months ended June 30, 2014 compared to the six months ended June 30, 2015:

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*Not meaningful or applicable.

(1)   For a discussion of the non‑GAAP financial measure Adjusted EBITDA, including a reconciliation of Adjusted EBITDA to its most directly comparable financial measure calculated and presented in accordance with GAAP, please see “—Non‑GAAP Financial Measure” below.

Gathering and compression revenue—affiliate.  Revenues from gathering of natural gas and condensate and compression of natural gas increased from $28.7 million for the six months ended June 30, 2014 to $108.8 million for the six months ended June 30, 2015, an increase of $80.1 million. Specifically:

Direct operating expenses.  Total direct operating expenses increased from $3.1 million for the six months ended June 30, 2014 to $23.0 million for the six months ended June 30, 2015, an increase of $19.9 million. The increase was primarily due to an increase in the number of gathering pipelines and compressor stations, as well as an increase in ad valorem tax expense as a result of more gathering and compression assets in West Virginia.

General and administrative expenses.  General and administrative expenses (before equity-based compensation) increased from $5.8 million for the six months ended June 30, 2014 to $9.4 million for the six months ended June 30, 2015, an increase of $3.6 million. The increase was primarily a result of increased staffing levels and related salary and benefits expenses and increased legal and other general corporate expenses to support our growth, as well as additional expenditures attributable to our operation as a publicly traded partnership.

Equity-based compensation expense. Equity-based compensation expense increased from $3.8 million for the six months ended June 30, 2014 to $10.0 million for the six months ended June 30, 2015, an increase of $6.2 million. The increase was primarily a result of equity-based compensation expense allocated to us by Antero related to (i) awards made under the Antero Resources Corporation Long‑Term Incentive Plan after June 30, 2014 and (ii) awards made to Antero employees and officers, and to non-employee directors of our general partner under the Antero Midstream Partners LP Long-Term Incentive Plan after June 30, 2014. Equity-based compensation expense allocated to us from Antero has no effect on our cash flows.

Depreciation expense.  Total depreciation expense increased from $14.8 million for the six months ended June 30, 2014 to $29.7 million for the six months ended June 30, 2015, an increase of $14.9 million. The increase was primarily due to gathering and compression assets placed in service after June 30, 2014.

Interest expense.  Interest expense increased from $1.2 million for the six months ended June 30, 2014 to $1.7 million for the six months ended June 30, 2015, an increase of $0.5 million. The increase is primarily due to commitment fees and amortization of deferred financing fees incurred during the six months ended June 30, 2015 in relation to our revolving credit facility, offset by interest and commitment fees incurred during the six months ended June 30, 2014 under the predecessor credit facility that was repaid in connection with the completion of the IPO.

 

Adjusted EBITDA.  Adjusted EBITDA increased from $19.8 million for the six months ended June 30, 2014 to $76.4 million for the six months ended June 30, 2015, an increase of $56.6 million. The increase was primarily due to an increase in gathering and compression throughput volumes during the six months ended June 30, 2015, net of the related increases in operating and general and administrative expenses. For a discussion of the non-GAAP financial measure Adjusted EBITDA, including a reconciliation of

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Adjusted EBITDA to its most directly comparable financial measures calculated and presented in accordance with GAAP, please see “—Non-GAAP Financial Measure” below.

Capital Resources and Liquidity

Sources and Uses of Cash

Our primary use of cash has been for the development and construction of our gathering and compression infrastructure. Prior to the IPO, our sources of liquidity included cash generated from operations and funding from Antero.

Capital and liquidity is provided by operating cash flow, cash on our balance sheet, and borrowings under our revolving credit facility, discussed below. We expect cash flow from operations to continue to contribute to our liquidity in the future. Sources of liquidity include borrowing capacity under our $1.0 billion revolving credit facility and potential issuances of debt and equity securities. We expect the combination of these capital resources will be adequate to meet our working capital requirements, capital expenditure program and expected quarterly cash distributions for at least the next 12 months.

The board of directors of our general partner has adopted a cash distribution policy pursuant to which we intend to distribute at least the minimum quarterly distribution of $0.17 per unit ($0.68 per unit on an annualized basis) on all of our units to the extent we have sufficient cash after the establishment of cash reserves and the payment of our expenses, including payments to our general partner and its affiliates. On July 15, 2015, we announced that the board of directors of our general partner declared a cash distribution of $0.19 per unit for the quarter ended June 30, 2015. The distribution is payable on August 27, 2015 to unit holders of record on August 13, 2015.

We expect our future cash requirements relating to working capital, maintenance capital expenditures and quarterly cash distributions to our partners will be funded from cash flows internally generated from our operations. Our expansion capital expenditures will be funded by borrowings under our revolving credit facility or from potential capital market transactions.

The following table and discussion presents a summary of our combined net cash provided by or used in operating activities, investing activities and financing activities for the periods indicated.

 

 

Cash Flow Provided by Operating Activities

Net cash provided by operating activities was $84.3 million for the six months ended June 30, 2015 and net cash provided by operating activities was $17.0 million for the six months ended June 30, 2014. The increase in cash flow from operations for the six 

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months ended June 30, 2015 compared to the six months ended June 30, 2014 was primarily the result of increased throughput volumes and revenues, which includes the addition of new gathering and compression systems placed in service after June 30, 2014.

Cash Flow Used in Investing Activities

Our Predecessor’s historical capital expenditures were funded by Antero.

During the six months ended June 30, 2015, we used cash flows in investing activities totaling $159.9 million for expenditures and deposits for gathering systems and compressor stations. During the six months ended June 30, 2014, we used cash flows in investing activities totaling $303.2 million for expenditures and deposits for gathering systems and compressor stations.

The board of directors of our general partner has approved a capital budget ranging from $425 million to $450 million for 2015 to expand our existing gathering and compression systems to accommodate Antero Resources’ development plans. Our capital budget may be adjusted as business conditions warrant.  If natural gas, NGLs, and oil prices decline to levels below acceptable levels or costs increase to levels above acceptable levels, Antero could choose to defer a significant portion of its budgeted capital expenditures until later periods. As a result, we may also defer a significant portion of our budgeted capital expenditures to achieve the desired balance between sources and uses of liquidity and prioritize capital projects that we believe have the highest expected returns and potential to generate near‑term cash flow.  We routinely monitor and adjust our capital expenditures in response to changes in Antero’s development plans, changes in commodity prices, availability of financing, acquisition costs, industry conditions, the timing of regulatory approvals, success or lack of success in Antero’s drilling activities, contractual obligations, internally generated cash flow and other factors both within and outside our control.

 

Cash Flow Provided by (Used in) Financing Activities

Net cash used in financing activities for the six months ended June 30, 2015 of $41.7 million is the result of $41.7 million in cash distributions to our unitholders.

Net cash provided by financing activities for the six months ended June 30, 2014 of $286.2 million was the result of $59.7 million in net parent contributions from Antero and $228.9 million in borrowings under the predecessor credit facility, offset by $0.5 million for payments on capital leases and $1.9 million for payments of IPO-related costs.

Debt Agreements and Contractual Obligations

Revolving Credit Facility

On November 10, 2014, we entered into a revolving credit facility with a syndicate of bank lenders. The revolving credit facility provides for lender commitments of $1.0 billion and a letter of credit sublimit of $150 million.  At June 30, 2015, we had no borrowings and no letters of credit outstanding under the revolving credit facility. The revolving credit facility will mature on November 10, 2019.

 

We have a choice of borrowing in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the LIBOR Rate administered by the ICE Benchmark Administration for one, two, three, six or twelve months plus an applicable margin ranging from 150 to 225 basis points, depending on the leverage ratio then in effect. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the

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rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 50 to 125 basis points, depending on the leverage ratio then in effect.

 

The revolving credit facility is secured by mortgages on substantially all of our properties, including the properties of our restricted subsidiaries. The revolving credit facility contains restrictive covenants that may limit our ability to, among other things:

 

Borrowings under the revolving credit facility also require us to maintain the following financial ratios:

 

 

 

 

Contractual Obligations

There have been no material changes to contractual obligations during the three months ended June 30, 2015. At June 30, 2015, we had no borrowings and no letters of credit outstanding under the revolving credit facility. Under the terms of our revolving

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credit facility, we are required to pay a commitment fee at rates ranging from 0.250% to 0.375% on any unused portion of the credit facility.

Non-GAAP Financial Measures

 

We use Adjusted EBITDA and Distributable Cash Flow as performance measures to assess the ability of our assets to generate cash sufficient to pay interest costs, support indebtedness and make cash distributions. Adjusted EBITDA is a financial measure reported to our lenders and used as a gauge for compliance with some of the financial covenants included in our revolving credit facility. We define Adjusted EBITDA as net income (loss) before equity-based compensation expense, interest expense, interest income, income taxes and depreciation and amortization expense. We define Distributable Cash Flow as Adjusted EBITDA less cash interest paid and ongoing maintenance capital expenditures paid. Distributable Cash Flow should not be viewed as indicative of the actual amount of cash that the Partnership has available for distributions from operating surplus or that the Partnership plans to distribute.

We use Adjusted EBITDA and Distributable Cash Flow to assess:

Adjusted EBITDA and Distributable Cash Flow are non‑GAAP financial measures. The GAAP measures most directly comparable to Adjusted EBITDA and Distributable Cash Flow are net income and net cash provided by operating activities. The non‑GAAP financial measures of Adjusted EBITDA and Distributable Cash Flow should not be considered as an alternative to the GAAP measure of net income. Adjusted EBITDA and Distributable Cash Flow are not presentations made in accordance with GAAP and have important limitations as an analytical tool because they includes some, but not all, items that affect net income. You should not consider Adjusted EBITDA and Distributable Cash Flow in isolation or as a substitute for analyses of results as reported under GAAP. Our definition of Adjusted EBITDA and Distributable Cash Flow may not be comparable to similarly titled measures of other partnerships.

The following table represents a reconciliation of our Adjusted EBITDA and Distributable Cash Flow to the most directly comparable GAAP financial measures for the periods presented:

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Critical Accounting Policies and Estimates    

The following discussion relates to the critical accounting policies and estimates for both the Partnership and our Predecessor. The discussion and analysis of our financial condition and results of operations are based upon our financial statements, which have been prepared in accordance with U.S. GAAP. The preparation of our condensed consolidated financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our financial statements. We provide expanded discussion of our more significant accounting policies, estimates and judgments in 2014 Form 10-K. We believe these accounting policies reflect our more significant estimates and assumptions used in preparation of our financial statements. Also, see note 2 of the notes to our audited consolidated financial statements, included in our 2014 Form 10-K, for a discussion of additional accounting policies and estimates made by management.

New Accounting Pronouncements

On May 28, 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014‑09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The ASU will replace most existing revenue recognition guidance in U.S. GAAP when it becomes effective. The new standard is effective for the Partnership on January 1, 2018. Early application is not permitted. The standard

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permits the use of either the retrospective or cumulative effect transition method. We are evaluating the effect that ASU 2014‑09 will have on our financial statements and related disclosures. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.

On April 7, 2015, the FASB issued ASU No. 2015-03, Interest–Imputation of Interest, which requires debt issuance costs to be presented in the balance sheet as a direct deduction from the associated debt liability.  The new standard becomes effective for the Partnership on January 1, 2016. The Partnership does not believe that this standard will have a material impact on its ongoing financial reporting upon adoption.

 

In April 2015, the FASB issued ASU 2015-06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions, which requires a master limited partnership (MLP) to allocate earnings (losses) of a transferred business entirely to the general partner when computing earnings per unit (EPU) for periods before the dropdown transaction occurred. The EPU for limited partners that was previously reported would not change as a result of the dropdown transaction. The ASU also requires an MLP to disclose the effects of the dropdown transaction on EPU for the periods before and after the dropdown transaction occurred. The new standard is effective for the Partnership on January 1, 2016.  The ASU requires retrospective application and early adoption is permitted. The Partnership is evaluating the effect that ASU 2015-06 will have on its consolidated financial statements and related disclosures.

 

Off-Balance Sheet Arrangements

As of June 30, 2015, we did not have any material off‑balance sheet arrangements.

Item 3.Quantitative and Qualitative Disclosures About Market Risk.

The primary objective of the following information is to provide forward‑looking quantitative and qualitative information about our potential exposure to market risk. The term “market risk” refers to the risk of loss arising from adverse changes in commodity prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. This forward‑looking information provides indicators of how we view and manage our ongoing market risk exposures.

Commodity Price Risk

Our gathering and compression agreement with Antero provides for fixed‑fee structures, and we intend to continue to pursue additional fixed‑fee opportunities with Antero and third parties in order to avoid direct commodity price exposure. However, to the extent that our future contractual arrangements with Antero or third parties do not provide for fixed‑fee structures, we may become subject to commodity price risk. We are subject to commodity price risks to the extent that they impact Antero’s development program and production and therefore our gathering volumes.

Interest Rate Risk

Our primary exposure to interest rate risk results from outstanding borrowings under our revolving credit facility, which has a floating interest rate. We do not currently, but may in the future, hedge the interest on portions of our borrowings under our revolving credit facility from time‑to‑time in order to manage risks associated with floating interest rates. At June 30, 2015, we had no borrowings and no letters of credit outstanding under the revolving credit facility.

Credit Risk

We are dependent on Antero as our only customer, and we expect to derive a substantial majority of our revenues from Antero for the foreseeable future. As a result, any event, whether in our area of operations or otherwise, that adversely affects Antero’s production, drilling schedule, financial condition, leverage, market reputation, liquidity, results of operations or cash flows may adversely affect our revenues and cash available for distribution.

Further, we are subject to the risk of non‑payment or non‑performance by Antero, including with respect to our gathering and compression agreement. We cannot predict the extent to which Antero’s business would be impacted if conditions in the energy

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industry were to deteriorate further, nor can we estimate the impact such conditions would have on Antero’s ability to execute its drilling and development program or to perform under our agreement. Any material non‑payment or non‑performance by Antero could reduce our ability to make distributions to our unitholders.

Item 4. Controls and Procedures. 

Evaluation of Disclosure Controls and Procedures

As required by Rule 13a-15(b) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this quarterly report on Form 10-Q.  Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC.  Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of June 30, 2015 at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the six months ended June 30, 2015 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

Our operations are subject to a variety of risks and disputes normally incident to our business. As a result, we may, at any given time, be a defendant in various legal proceedings and litigation arising in the ordinary course of business. However, we are not currently subject to any material litigation.

We maintain insurance policies with insurers in amounts and with coverage and deductibles that we, with the advice of our insurance advisors and brokers, believe are reasonable and prudent. We cannot, however, provide any assurance that this insurance will be adequate to protect us from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at economical prices.

Item 1A. Risk Factors.

We are subject to certain risks and hazards due to the nature of the business activities we conduct. For a discussion of these risks, see “Item 1A. Risk Factors” in our 2014 Form 10-K. The risks described in our 2014 Form 10-K could materially and adversely affect our business, financial condition, cash flows, and results of operations. The following risk factor updates the risks described in our 2014 Form 10-K.  Except as set forth below, there have been no material changes to the risks described in our 2014 Form 10-K. We may experience additional risks and uncertainties not currently known to us; or, as a result of developments occurring in the future, conditions that we currently deem to be immaterial may also materially and adversely affect our business, financial condition, cash flows and results of operations.

 

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

 

The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial changes or differing interpretations at any time. For example, the Fiscal Year 2016 Budget proposed by the President recommends that certain publicly traded partnerships earning income from activities related to fossil fuels be taxed as corporations beginning in 2021. From time to time, members of Congress propose and consider such substantive changes to the existing U.S. federal income tax laws that affect publicly traded partnerships. If successful, the Obama administration’s proposal or other similar proposals could eliminate the qualifying income exception to the treatment of all publicly-traded partnerships as corporations upon which we rely for our treatment as a partnership for U.S. federal income tax purposes.

 

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

 

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

 

Item 5. Other Information. 

Disclosure pursuant to Section 13(r) of the Securities Exchange Act of 1934

Pursuant to Section 13(r) of the Securities Exchange Act of 1934, we, Antero Midstream Partners LP, may be required to disclose in our annual and quarterly reports to the Securities and Exchange Commission (the “SEC”), whether we or any of our “affiliates” knowingly engaged in certain activities, transactions or dealings relating to Iran or with certain individuals or entities targeted by US economic sanctions.  Disclosure is generally required even where the activities, transactions or dealings were

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conducted in compliance with applicable law.  Because the SEC defines the term “affiliate” broadly, it includes any entity under common “control” with us (and the term “control” is also construed broadly by the SEC).

 

The description of the activities below has been provided to us by Warburg Pincus LLC (“WP”), affiliates of which: (i) beneficially own more than 10% of our outstanding common units and/or are members of our general partner’s board of directors and (ii) beneficially own more than 10% of the equity interests of, and have the right to designate members of the board of directors of Santander Asset Management Investment Holdings Limited (“SAMIH”).  SAMIH may therefore be deemed to be under common “control” with us; however, this statement is not meant to be an admission that common control exists.

 

The disclosure below relates solely to activities conducted by SAMIH and its non-U.S. affiliates that may be deemed to be under common “control” with us.  The disclosure does not relate to any activities conducted by us or by WP and does not involve our or WP’s management.  Neither we nor WP has had any involvement in or control over the disclosed activities of SAMIH, and neither we nor WP has independently verified or participated in the preparation of the disclosure.  Neither we nor WP is representing as to the accuracy or completeness of the disclosure nor do we or WP undertake any obligation to correct or update it.

 

We understand that SAMIH’s affiliates intend to disclose in their next annual or quarterly SEC report that “Santander UK holds frozen savings and current accounts for two customers resident in the U.K. who are currently designated by the U.S. for terrorism.  The accounts held by each customer were blocked after the customer’s designation and have remained blocked and dormant throughout the first half of 2015.  No revenue has been generated by Santander UK on these accounts.”

 

“An Iranian national, resident in the U.K., who is currently designated by the U.S. under the Iranian Financial Sanctions Regulations and the Weapons of Mass Destruction Proliferators Sanctions Regulations (“NPWMD sanctions program”), holds a mortgage with Santander UK that was issued prior to any such designation. No further drawdown has been made (or would be allowed) under this mortgage although Santander UK continues to receive repayment installments.  In the first half of 2015, total revenue in connection with the mortgage was approximately £1,780 while net profits were negligible relative to the overall profits of Santander UK. Santander UK does not intend to enter into any new relationships with this customer, and any disbursements will only be made in accordance with applicable sanctions. The same Iranian national also holds two investment accounts with Santander Asset Management UK Limited. The accounts have remained frozen during the first half of 2015.  The investment returns are being automatically reinvested, and no disbursements have been made to the customer. Total revenue for the Group in connection with the investment accounts was approximately £120 while net profits in the first quarter of 2015 were negligible relative to the overall profits of Banco Santander, S.A”

Item 6. Exhibits.

The exhibits required to be filed pursuant to the requirements of Item 601 of Regulation S-K are set forth in the Exhibit Index accompanying this Form 10-Q and are incorporated herein by reference.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

 

 

 

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EXHIBIT INDEX

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The exhibits marked with the asterisk symbol (*) are filed or furnished with this Quarterly Report on Form 10-Q.

 

 

 

 

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