10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 __________________________________________________

FORM 10-Q

 __________________________________________________ 

(Mark One)

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

For the quarterly period ended June 30, 2017

OR

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 number: 001-36635

__________________________________________________

CONE MIDSTREAM PARTNERS LP

(Exact name of registrant as specified in its charter)

Delaware	47-1054194
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

1000 CONSOL Energy Drive

Canonsburg, PA 15317-6506

(724) 485-4000

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)__________________________________________________

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 (§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  x    No   o

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

Large accelerated filer  o    Accelerated filer  x    Non-accelerated filer  o (Do not check if a smaller reporting company)    Smaller Reporting Company  o Emerging Growth Company  x

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. x

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

As of August 7, 2017, CONE Midstream Partners LP had 34,422,212 common units and 29,163,121 subordinated units outstanding.

TABLE OF CONTENTS
		Page
PART I FINANCIAL INFORMATION
ITEM 1.	Consolidated Financial Statements
	Consolidated Statements of Operations for the Three and Six Months Ended June 30, 2017 and 2016	3
	Consolidated Balance Sheets at June 30, 2017 and December 31, 2016	4
	Consolidated Statements of Partners' Capital and Noncontrolling Interest for the Six Months Ended June 30, 2017	5
	Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2017 and 2016	6
	Notes to Consolidated Unaudited Financial Statements	7
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	23
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	37
ITEM 4.	Controls and Procedures	37
PART II OTHER INFORMATION
ITEM 1.	Legal Proceedings	38
ITEM 1A.	Risk Factors	38
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	38
ITEM 3.	Defaults upon Senior Securities	38
ITEM 4.	Mine Safety Disclosures	38
ITEM 5.	Other Information	38
ITEM 6.	Exhibits	39

PART I: FINANCIAL INFORMATION

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

CONE MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit data)

(unaudited)

	Three Months Ended   June 30,				Six Months Ended   June 30,
	2017		2016		2017		2016
Revenue
Gathering revenue — related party	$	55,667	$	58,407	$	114,625	$	120,655
Gathering revenue — third party	867		—		867		—
Total Revenue	56,534		58,407		115,492		120,655
Expenses
Operating expense — related party	7,089		7,078		14,717		15,422
Operating expense — third party	5,957		7,879		12,590		16,553
General and administrative expense — related party	2,715		2,213		5,651		3,897
General and administrative expense — third party	981		1,153		2,120		2,147
Loss on asset sales	3,241		10,083		3,914		10,083
Depreciation expense	5,675		5,152		11,346		9,992
Interest expense	1,124		381		2,162		800
Total Expense	26,782		33,939		52,500		58,894
Net Income	29,752		24,468		62,992		61,761
Less: Net income attributable to noncontrolling interest	761		1,251		3,934		13,755
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$	28,991	$	23,217	$	59,058	$	48,006
Calculation of Limited Partner Interest in Net Income:
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$	28,991	$	23,217	$	59,058	$	48,006
Less: General partner interest in net income, including incentive distribution rights	1,305		464		2,434		960
Limited partner interest in net income	$	27,686	$	22,753	$	56,624	$	47,046
Net income per limited partner unit - Basic	$	0.44	$	0.39	$	0.89	$	0.81
Net income per limited partner unit - Diluted	$	0.44	$	0.39	$	0.89	$	0.81
Limited partner units outstanding - Basic	63,585		58,343		63,575		58,343
Limited partner unit outstanding - Diluted	63,644		58,415		63,630		58,397
Cash distributions declared per unit (*)	$	0.2922	$	0.2540	$	0.5743	$	0.4990

(*) Represents the cash distributions declared during the month following the end of each respective quarterly period. See Note 15.

The accompanying notes are an integral part of these unaudited financial statements.

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CONE MIDSTREAM PARTNERS LP

CONSOLIDATED BALANCE SHEETS

(in thousands, except number of units)

(unaudited)

	June 30, 2017			December 31, 2016
ASSETS
Current Assets:
Cash	$	4,866		$	6,421
Receivables — related party (Note 6)	18,425			22,434
Receivables — third party (Note 6)	5,243			—
Other current assets	1,914			2,181
Total Current Assets	30,448			31,036
Property and Equipment:
Property and equipment (Note 7)	940,208			930,732
Less — accumulated depreciation	62,394			52,172
Property and Equipment — Net	877,814			878,560
Other assets (Note 8)	675			8,961
TOTAL ASSETS	$	908,937		$	918,557
LIABILITIES AND EQUITY
Current Liabilities:
Accounts payable	$	18,880		$	18,007
Accounts payable — related party (Note 9)	2,728			8,289
Total Current Liabilities	21,608			26,296
Other Liabilities:
Revolving credit facility (Note 10)	161,000			167,000
Total Liabilities	182,608			193,296
Partners' Capital:
Common units (34,422,212 units issued and outstanding at June 30, 2017 and 34,363,371 units issued and outstanding at December 31, 2016)	430,171			418,352
Subordinated units (29,163,121 units issued and outstanding at June 30, 2017 and December 31, 2016)	(56,185		)	(65,986		)
General partner interest	(1,451		)	(2,311		)
Partners' capital attributable to CONE Midstream Partners LP	372,535			350,055
Noncontrolling interest	353,794			375,206
Total Partners' Capital	726,329			725,261
TOTAL LIABILITIES AND PARTNERS' CAPITAL	$	908,937		$	918,557

The accompanying notes are an integral part of these unaudited financial statements.

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CONE MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL AND NONCONTROLLING INTEREST

(in thousands)

(unaudited)

	Partners' Capital									Total
										Capital
	Limited Partners						General			Attributable			Noncontrolling
	Common			Subordinated			Partner			to Partners			Interest			Total
Balance at December 31, 2016	$	418,352		$	(65,986	)	$	(2,311	)	$	350,055		$	375,206		$	725,261
Net income	30,652			25,972			2,434			59,058			3,934			62,992
Contributions to (distributions from) general partner and noncontrolling interest holders, net	—			—			29			29			(25,346		)	(25,317		)
Quarterly distributions to unitholders	(19,072		)	(16,171		)	(1,603		)	(36,846		)	—			(36,846		)
Unit-based compensation	650			—			—			650			—			650
Vested units withheld for unitholder taxes	(411		)	—			—			(411		)	—			(411		)
Balance at June 30, 2017	$	430,171		$	(56,185	)	$	(1,451	)	$	372,535		$	353,794		$	726,329

The accompanying notes are an integral part of these unaudited financial statements.

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CONE MIDSTREAM PARTNERS LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Six Months Ended   June 30,
	2017			2016
Cash Flows from Operating Activities:
Net income	$	62,992		$	61,761
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation expense and amortization of debt issuance costs	11,430			10,073
Unit-based compensation	650			355
Loss on asset sales	3,914			10,083
Other	167			151
Changes in assets and liabilities:
Receivables — related party	4,009			12,285
Receivables — third party	(867		)	—
Other current and non-current assets	3,574			822
Accounts payable	(3,645		)	(12,533		)
Accounts payable — related party	(5,790		)	(40		)
Net Cash Provided by Operating Activities	76,434			82,957
Cash Flows from Investing Activities:
Capital expenditures	(23,415		)	(33,724		)
Proceeds from sale of assets	14,000			—
Net Cash Used in Investing Activities	(9,415		)	(33,724		)
Cash Flows from Financing Activities:
Contributions to (distributions from) general partner and noncontrolling interest holders, net	(25,317		)	10,823
Quarterly distributions to unitholders	(36,846		)	(28,654		)
Net payments on revolving credit facility	(6,000		)	(26,500		)
Vested units withheld for unitholders taxes	(411		)	(23		)
Net Cash Used In Financing Activities	(68,574		)	(44,354		)
Net (Decrease) Increase in Cash	(1,555		)	4,879
Cash at Beginning of Period	6,421			217
Cash at End of Period	$	4,866		$	5,096
Cash paid during the period for:
Interest	$	2,171		$	893

The accompanying notes are an integral part of these unaudited financial statements.

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CONE MIDSTREAM PARTNERS LP

NOTES TO THE CONSOLIDATED UNAUDITED FINANCIAL STATEMENTS

NOTE 1 — DESCRIPTION OF BUSINESS

CONE Midstream Partners LP (the “Partnership") is a master limited partnership formed in May 2014 by CONSOL Energy Inc. (NYSE: CNX) (“CONSOL”) and Noble Energy, Inc. (NYSE: NBL) (“Noble Energy”) primarily to own, operate, develop and acquire natural gas gathering and other midstream energy assets to service each of CONSOL's and Noble Energy's production in the Marcellus Shale in Pennsylvania and West Virginia. Our assets include natural gas gathering pipelines and compression and dehydration facilities, as well as condensate gathering, collection, separation and stabilization facilities. The Partnership's general partner is CONE Midstream GP LLC (our “general partner”), a wholly owned subsidiary of CONE Gathering LLC (“CONE Gathering”). CONE Gathering, a Delaware limited liability company, is a joint venture formed by CONSOL and Noble Energy in September 2011.

Noble Energy Sale of Upstream Assets

On June 28, 2017, Noble Energy closed the previously announced sale of its upstream assets in northern West Virginia and southern Pennsylvania to HG Energy II Appalachia, LLC (“HG Energy”), a portfolio company of Quantum Energy Partners, LP (“Quantum”), effectively making HG Energy the new shipper on the dedicated acreage that was previously owned by Noble Energy (the “Noble Energy Asset Sale”). In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems, from amounts dedicated to us as per the terms of our gathering agreement, which is more fully discussed in Note 4. The Partnership is in the process of confirming the amount of acreage that was released from dedication to us.

Effective June 28, 2017, the Partnership gathers the natural gas and condensate volumes produced by HG Energy on our dedicated acreage under the terms of our gathering agreement with Noble Energy, which was assigned to HG Energy upon consummation of the Noble Energy Asset Sale.

Noble Energy Proposed Sale of Interests in CONE Gathering and the Partnership

On May 18, 2017, Noble Energy announced that it had reached an agreement to divest the holding company which owns its 50% membership interest in CONE Gathering, as well as 7,110,638 common units and 14,581,560 subordinated units in the Partnership (collectively, the “Interests”), to Wheeling Creek Midstream, LLC (“Wheeling Creek”), a portfolio company of Quantum (the “Wheeling Creek Acquisition”). The proposed transaction, which Noble Energy has announced it expects to close in the second half of 2017, is subject to customary closing conditions. CONSOL has advised Noble Energy that CONSOL disagrees with Noble Energy’s ability to sell its interest in CONE Gathering, which wholly owns our general partner, without first offering a preferential right of purchase to CONSOL. Accordingly, CONSOL has filed a lawsuit against Noble Energy seeking to enforce this right. Noble Energy disputes that CONSOL has such a right.

As of August 7, 2017, Noble Energy continues to own the Interests. Accordingly, in this Quarterly Report on Form 10-Q, we may refer to CONSOL and Noble Energy together as our Sponsors.

Description of Business

In order to effectively manage our business we have divided our current midstream assets among three operating segments that we refer to as our “Anchor Systems,” “Growth Systems” and “Additional Systems” based on their relative current cash flows, growth profiles, capital expenditure requirements and the timing of their development.

• Our Anchor Systems include our most developed midstream systems that generate the largest portion of our current cash flows, which includes our three primary midstream systems (the McQuay System, the Majorsville System and the Mamont System) and related assets.

• Our Growth Systems are primarily located in the dry gas regions of our dedicated acreage that are generally in earlier phases of development and require substantial future expansion capital expenditures to materially increase production, which would primarily be funded by CONSOL and Noble Energy in proportion to CONE Gathering's 95% retained ownership interest.

• Our Additional Systems include several gathering systems primarily located in the wet gas regions of our dedicated acreage that we expect will require lower levels of expansion capital investment relative to our Growth Systems. The substantial majority of capital investment on these systems would primarily be funded by CONSOL and Noble Energy in proportion to CONE Gathering's 95% retained ownership interest.

On September 30, 2014, in connection with the closing of the Partnership's initial public offering (“IPO”), CONE Gathering contributed to the Partnership a 75% controlling interest in the Anchor Systems, a 5% controlling interest in the

7

Growth Systems and a 5% controlling interest in the Additional Systems. On November 16, 2016, the Partnership acquired the remaining 25% noncontrolling interest in the Anchor Systems from CONE Gathering (the “Anchor Systems Acquisition”), which was accounted for as a transaction between unitholders under Accounting Standards Codification (“ASC”) 810 - Consolidations. Accordingly, at December 31, 2016 and June 30, 2017, the Partnership owned a 100% controlling limited partner interest in the Anchor Systems and a 5% controlling limited partner interest in each of the Growth and Additional Systems.

In order to maintain operational flexibility, our operations are conducted through, and our operating assets are owned by, our operating subsidiaries. However, neither we nor our operating subsidiaries have any employees. Our general partner has the sole responsibility for providing the personnel necessary to conduct our operations, whether through directly hiring employees or by obtaining the services of others, which may include personnel of our Sponsors as provided through contractual relationships with the Partnership. All of the personnel that conduct our business are employed or contracted by our general partner and its affiliates, including our Sponsors, but we sometimes refer to these individuals as our employees because they provide services directly to us. See Note 4 for details.

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation and Use of Estimates

The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and various disclosures. Actual results could differ from those estimates, which are evaluated on an ongoing basis, utilizing historical experience and other methods considered reasonable under the particular circumstances. Although these estimates are based on management’s best available knowledge at the time, changes in facts and circumstances or discovery of new facts or circumstances may result in revised estimates and actual results may differ from these estimates. Effects on the Partnership’s business, financial position and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revision become known. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation of the accompanying consolidated financial statements have been included.

The balance sheet at December 31, 2016 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements.

Principles of Consolidation

The consolidated financial statements include the accounts of the Partnership and all of its controlled subsidiaries, including 100% of each of the Anchor Systems, Growth Systems and Additional Systems. Although the Partnership has less than a 100% economic interest in the Growth and Additional Systems, each are consolidated fully with the results of the Partnership for all periods following the IPO. However, after adjusting for noncontrolling interests, net income attributable to general and limited partner ownership interests in the Partnership reflect only that portion of net income that is attributable to the Partnership's unitholders. As a result of the Anchor Systems Acquisition, net income attributable to general and limited partner ownership interests in the Partnership includes 100% of the results of the Anchor Systems for periods subsequent to November 16, 2016.

Transactions between the Partnership and its Sponsors have been identified in the consolidated financial statements as transactions between related parties and are discussed in Note 4.

Jumpstart Our Business Startups Act (“JOBS Act”)

Under the JOBS Act, for as long as the Partnership remains an “emerging growth company” as defined in the JOBS Act, we may take advantage of certain exemptions from the Securities and Exchange Commission's (“SEC”) reporting requirements that are applicable to other public companies that are not emerging growth companies, including not being required to provide an auditor’s attestation report on management’s assessment of the effectiveness of its system of internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act, reduced disclosure obligations regarding executive compensation in our periodic reports, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and seeking unitholder approval of any golden parachute payments not previously approved. We may take advantage of these reporting exemptions until we are no longer an emerging growth company. We continue to be an emerging growth company at June 30, 2017.

The Partnership will remain an emerging growth company for up to five years from the date of our IPO (through December 31, 2019), although we will lose that status sooner if:

• we have more than $1.0 billion of revenues in a fiscal year;

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• the limited partner interests held by non-affiliates have a market value of more than $700 million as of the last business day of our most recently completed second fiscal quarter, which determination shall be made as of the last day of such fiscal year; or

• we issue more than $1.0 billion of non-convertible debt over a three-year period.

The JOBS Act also provides that an emerging growth company can delay adopting new or revised accounting standards until such time as those standards apply to private companies. The Partnership has irrevocably elected to “opt out” of this exemption and, therefore, is and will be subject to the same new or revised accounting standards as other public companies that are not emerging growth companies.

Revenue Recognition

During the quarter ended June 30, 2017, our revenues primarily consisted of fees, which we charge on a per unit basis, for gathering natural gas that was produced by CONSOL and Noble Energy. We recognize revenue when services have been rendered, the prices are fixed or determinable, and collectibility is reasonably assured.

The fees we charged CONSOL and Noble Energy, prior to consummation of the Noble Asset Sale on June 28, 2017, were recorded in gathering revenue — related party in our consolidated statements of operations. Following consummation of the Noble Asset Sale, fees from midstream services we performed for HG Energy, as well as midstream services we performed on behalf of another third party shipper, were recorded in gathering revenue — third party in our consolidated statements of operations.

Cash

Cash includes cash on hand and on deposit at banking institutions.

Receivables

Receivables are recorded at the invoiced amount and do not bear interest. When applicable, we reserve for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. We regularly review collectability and establish or adjust the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.

There were no reserves for uncollectible amounts at June 30, 2017 or December 31, 2016.

Fair Value Measurement

The Financial Accounting Standards Board (the “FASB”) ASC 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 we would receive upon selling an asset or that we would pay to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy is used to prioritize input 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 current assets and liabilities approximate fair values due to their short maturities. The carrying value of our revolving credit facility approximates fair value as the facility bears interest at a variable, market rate that resets periodically.

Property and Equipment

Property and equipment is recorded at cost upon acquisition and is depreciated on a straight-line basis over their estimated useful lives or over the lease terms of the assets. Expenditures which extend the useful lives of existing property and equipment are capitalized. When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as a gain or loss.

We routinely assess whether impairment indicators arise during any given quarter and have processes in place to ensure that we become aware of such indicators. Impairment indicators include, but are not limited to, sustained decreases in commodity prices, a decline in customer well results and lower throughput forecasts, and increases in construction or operating

9

costs. For such long-lived assets, impairment exists when the carrying amount of an asset or group of assets exceeds our estimates of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying amount of the long-lived asset(s) is not recoverable, based on the estimated future undiscounted cash flows, the impairment loss would be measured as the excess of the asset’s carrying amount over its estimated fair value. In the event that impairment indicators exist, we conduct an impairment test.

Fair value represents the estimated price between market participants to sell an asset in the principal or most advantageous market for the asset, based on assumptions a market participant would make. When warranted, management assesses the fair value of long-lived assets using commonly accepted techniques and may use more than one source in making such assessments. Sources used to determine fair value include, but are not limited to, recent third-party comparable sales, internally developed discounted cash flow analyses and analyses from outside advisors. Significant changes, such as the condition of an asset or management’s intent to utilize the asset, generally require management to reassess the cash flows related to long-lived assets. No property and equipment impairments were identified during the periods presented in the accompanying consolidated financial statements.

Environmental Matters

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, and do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. At this time, we are unable to assess the timing and/or effect of potential liabilities related to greenhouse gas emissions or other environmental issues. As of June 30, 2017 and December 31, 2016, we had no material environmental matters that required the recognition of a separate liability or specific disclosure.

Asset Retirement Obligations

Our gathering pipelines and compressor stations have an indeterminate life. If properly maintained, they will operate for an indeterminate period as long as supply and demand for natural gas exists, which we expect for the foreseeable future. Accordingly, any retirement obligations associated with such assets cannot be estimated. A liability for asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life exists and can be estimated. We have not recorded any liabilities for asset retirement obligations at June 30, 2017 or December 31, 2016.

Variable Interest Entities

Each of the Anchor, Growth and Additional Systems (the “Limited Partnerships”) is also a limited partnership and a variable interest entity (“VIE”). These VIEs correspond with the manner in which we report our segment information in Note 13–Segment Information, which also includes information regarding the Partnership's involvement with each of these VIEs and their relative contributions to our financial position, operating results and cash flows.

The Partnership fully consolidates each of the Limited Partnerships through its ownership of CONE Midstream Operating Company LLC (the “Operating Company”). The Operating Company, through its general partner ownership interest in each of the Anchor, Growth and Additional Limited Partnerships, is considered to be the primary beneficiary for accounting purposes and has the power to direct all substantive strategic and day-to-day operational decisions of the Limited Partnerships.

Equity Compensation

Equity compensation expense for all unit-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. We recognize unit-based compensation costs on a straight-line basis over the requisite service period of an award, which is generally the same as the award's vesting term. See Note 14–Long Term Incentive Plan, for further discussion.

Income Taxes

We are treated as a partnership for federal and state income tax purposes, with each partner being separately taxed on its share of the Partnership's taxable income. Accordingly, no provision for federal or state income taxes has been recorded in the Partnership's consolidated financial statements for any period presented in the accompanying consolidated financial statements.

Cash Distributions

Our partnership agreement requires that we distribute all of our available cash within 45 days after the end of each quarter to unitholders of record on the applicable record date. This requirement forms the basis of our cash distribution policy and reflects a basic judgment that our unitholders will be better served by distributing our available cash rather than retaining it because, among other reasons, we believe we will generally finance any expansion capital expenditures from external financing sources. Under our current cash distribution policy, we intend to make a minimum quarterly distribution to the holders of our common units and subordinated units of $0.2125 per unit, or $0.85 per unit on an annualized basis, to the extent we have

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sufficient available cash after the establishment of cash reserves and the payment of costs and expenses, including the payment of expenses to our general partner. However, other than the requirement in our partnership agreement to distribute all of our available cash each quarter, we have no legal obligation to make quarterly cash distributions in this or any other amount, and the board of directors of our general partner has considerable discretion to determine the amount of our available cash each quarter. In addition, the board of directors of our general partner may change our cash distribution policy at any time, subject to the requirement in our partnership agreement to distribute all of our available cash quarterly.

Generally, our available cash is the sum of (i) all cash on hand at the end of a quarter after the payment of our expenses and the establishment of cash reserves and (ii) if the board of directors of our general partner so determines, all or any portion of additional cash on hand resulting from working capital borrowings made after the end of the quarter.

Incentive Distribution Rights

Incentive distribution rights (“IDRs”) represent the right to receive an increasing percentage, up to a maximum of 48% (which does not include the 2% general partner interest), of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels described in the table below have been achieved. All of the IDRs are currently held by our general partner. Our general partner may transfer the IDRs separately from its general partner interest.

See Note 3–Net Income Per Limited Partner Unit for additional details regarding achievement of target distribution levels.

Percentage Allocations of Available Cash from Operating Surplus

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner, as holder of our IDRs, and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit Target Amount.” The percentage interests shown for our unitholders and our 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 our general partner include its 2% general partner interest and assume that our general partner has contributed any additional capital necessary to maintain its 2% general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.

			Marginal Percentage Interest in Distributions
Distribution Targets	Total Quarterly Distribution Per Unit Target Amount		Unitholders	General Partner (including IDRs)
Minimum Quarterly Distribution		$0.2125	98%	2%
First Target Distribution	Above $0.2125	up to $0.24438	98%	2%
Second Target Distribution	Above $0.24438	up to $0.26563	85%	15%
Third Target Distribution	Above $0.26563	up to $0.31875	75%	25%
Thereafter	Above $0.31875		50%	50%

The Second and Third Target Distributions were reached for the cash flow quarters ended March 31, 2016 and December 31, 2016, respectively, which were paid within 45 days following the ends of these quarters. All quarterly distributions prior to March 31, 2016 were paid in accordance with the First Target Distribution.

Subordinated Units

Our partnership agreement provides that, during the subordination period, the common unitholders will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.2125 per unit, which is defined in our partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. The practical effect of the subordinated units is to increase the likelihood that, during the subordination period, there will be available cash to be distributed on the common units. The subordination period will end, and the subordinated units will convert to common units, on a one-for-one basis, when certain distribution requirements, as defined in the partnership agreement, have been met.

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CONSOL and Noble Energy currently own 29,163,121 subordinated units in the aggregate, which represents all of our subordinated units.

Recent Accounting Pronouncements

In May 2017, the FASB issued Accounting Standards Update (“ASU”) 2017-09-Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting. ASU 2017-09 provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The updated guidance is effective for interim and annual periods beginning after December 15, 2017, and early adoption is permitted. We do not believe the updated requirements will materially impact our consolidated financial statements.

In January 2017, the FASB issued ASU 2017-01–Business Combinations (Topic 805): Clarifying the Definition of a Business, which changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities is a business. The updated guidance requires an entity to evaluate if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets; if so, the set of transferred assets is not a business. ASU 2017-01 is effective for annual reporting periods beginning after December 31, 2017 and interim periods therein. The Partnership does not expect the adoption of this guidance to have a material impact on its consolidated financial statements.

In December 2016, the FASB issued ASU 2016-19–Technical Corrections and Improvements, which covers a wide range of Topics in the ASC. The amendments in this ASU represent changes to clarify, correct errors, or make minor improvements to the ASC, making it easier to understand and apply by eliminating inconsistencies and providing clarifications. The amendments generally fall into one of the following categories: amendments related to differences between original guidance and the ASC, guidance clarification and reference corrections, simplification, or minor improvements. Most of the amendments in ASU 2016-19 do not require transition guidance and are effective immediately.

In August 2016, the FASB issued ASU 2016-15–Classification of Certain Cash Receipts and Cash Payments (Topic 230). ASU 2016-15 addresses the existing diversity in practice of how several specific cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230, Statement of Cash Flows. ASU 2016-15 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2017. The Partnership does not expect the adoption of this guidance will have a material impact on its consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02–Leases (Topic 842), which is intended to improve financial reporting about leasing transactions. The ASU will require organizations (“lessees”) that lease assets with terms of more than 12 months to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. Organizations that own the assets leased by lessees (“lessors”) will remain largely unchanged from current GAAP. In addition, the ASU will require disclosures to help investors and other financial statement users better understand the amount, timing and uncertainty of cash flows arising from leases. The effective date of this ASU is for fiscal years beginning after December 31, 2018 and interim periods within that year. We are currently evaluating the impact that this standard will have on our financial statements and financial covenants with lenders; however, we do not believe this standard will materially adversely impact our existing credit agreements.

In May 2014, the FASB issued ASU 2014-09–Revenue from Contracts with Customers (Topic 606), which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. The objective of the amendments in this update is to improve financial reporting by creating common revenue recognition guidance under both U.S. GAAP and International Financial Reporting Standards (“IFRS”). The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services and should disclose sufficient information, both qualitative and quantitative, to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The following updates to Topic 606 were made during 2016:

• In March 2016, the FASB updated Topic 606 by issuing ASU 2016-08–Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies how an entity determines whether it is a principal or an agent for goods or services promised to a customer as well as the nature of the goods or services promised to their customers.

• In April 2016, the FASB issued ASU 2016-10–Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing, which seeks to address implementation issues in the areas of identifying performance obligations and licensing.

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• In May 2016, the FASB issued ASU 2016-12–Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients. The update, which was issued in response to feedback received by the FASB-IASB joint revenue recognition transition resource group, seeks to address implementation issues in the areas of collectibility, presentation of sales taxes, noncash consideration, and completed contracts and contract modifications at transition.

After considering the FASB's issuance of a standard that delayed application of Topic 606 by one year, the new standards are effective for annual reporting periods beginning after December 15, 2017, with the option to adopt as early as annual reporting periods beginning after December 15, 2016. Management continues to evaluate the impacts that these standards will have on the Partnership's financial statements; however, the Partnership anticipates using the modified retrospective approach at adoption as it relates to ASU 2014-09.

NOTE 3 — NET INCOME PER LIMITED PARTNER UNIT

We allocate net income between our general partner and limited partners using the two-class method, under which we allocate net income to our limited partners, our general partner and the holders of our IDRs in accordance with the terms of our partnership agreement. We also allocate any earnings in excess of distributions to our limited partners, our general partner and the holders of the IDRs in accordance with the terms of our partnership agreement. We allocate any distributions in excess of earnings for the period to our general partner and our limited partners based on their respective proportionate ownership interests in us, after taking into account distributions to be paid with respect to the IDRs, as set forth in our partnership agreement.

The Partnership calculates historical earnings per unit under the two-class method and allocates the earnings or losses of a transferred business before the date of a dropdown transaction entirely to the general partner. If applicable, the previously reported earnings per unit of the limited partners would not change as a result of a dropdown transaction.

Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as awards under the long-term incentive plan, were exercised, settled or converted into common units.  When it is determined that potential common units resulting from an award subject to performance or market conditions should be included in the diluted net income per limited partner unit calculation, the impact is calculated by applying the treasury stock method. There were 50,905 phantom units that were not included in the calculation for each of the three and six months ended June 30, 2017 because the effect would have been antidilutive. There were also 1,213 and 5,203 phantom units that were excluded for the three and six months ended June 30, 2016, respectively, because the effect would have been antidilutive.

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The following table illustrates the Partnership’s calculation of net income per unit for common and subordinated partner units:

	Three Months Ended June 30,				Six Months Ended   June 30,
(in thousands, except per unit information)	2017		2016		2017		2016
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$	28,991	$	23,217	$	59,058	$	48,006
Less: General partner interest in net income, including incentive distribution rights	1,305		464		2,434		960
Limited partner interest in net income	$	27,686	$	22,753	$	56,624	$	47,046
Net income allocable to common units — Basic and Diluted	$	14,988	$	11,380	$	30,652	$	23,530
Net income allocable to subordinated units — Basic and Diluted	12,698		11,373		25,972		23,516
Limited partner interest in net income — Basic and Diluted	$	27,686	$	22,753	$	56,624	$	47,046
Weighted average limited partner units outstanding — Basic
Common units	34,422		29,180		34,412		29,180
Subordinated units	29,163		29,163		29,163		29,163
Total	63,585		58,343		63,575		58,343
Weighted average limited partner units outstanding — Diluted
Common units	34,481		29,252		34,467		29,234
Subordinated units	29,163		29,163		29,163		29,163
Total	63,644		58,415		63,630		58,397
Net income per limited partner unit — Basic
Common units	$	0.44	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81
Net income per limited partner unit — Diluted
Common units	$	0.43	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81

NOTE 4 — RELATED PARTY

In the ordinary course of business, we have transactions with CONSOL (and certain of its subsidiaries) and Noble Energy, our Sponsors during the three and six months ended June 30, 2017 and 2016, which constitute related party transactions.

During the quarter ended June 30, 2017, the Partnership sold property and equipment with a carrying value of $17.4 million to CONSOL for $14.0 million in cash proceeds. The resulting loss of $3.4 million was recorded in loss on asset sales in the accompanying consolidated statement of operations. The assets that were sold were previously within the Additional Systems.

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Sponsor-related charges within operating expense and general and administrative expense – related party consisted of the following:

	Three Months Ended   June 30,				Six Months Ended   June 30,
(in thousands)	2017		2016		2017		2016
Operational services — CONSOL	$	2,999	$	3,177	$	6,187	$	7,154
Electrical compression	4,090		3,901		8,530		8,268
Total Operating Expense — Related Party	$	7,089	$	7,078	$	14,717	$	15,422
CONSOL	$	2,582	$	2,042	$	5,346	$	3,569
Noble Energy	133		171		305		328
Total General and Administrative Expense — Related Party	$	2,715	$	2,213	$	5,651	$	3,897

In addition to the aforementioned transactions, throughout the six months ended June 30, 2017 and 2016, the Sponsors, through their ownership of CONE Gathering, also regularly reimbursed the Partnership for capital expenditures, initially funded by the Partnership, in proportion to CONE Gathering's noncontrolling ownership interests in the Anchor, Growth and Additional Systems. We also distributed to the Sponsors amounts related to their noncontrolling ownership interest in the earnings of the Anchor, Growth and Additional Systems as well as proceeds from sales of any assets in which the Sponsors have ownership interests through their membership in CONE Gathering. This activity is recorded in the caption “Contributions from (distributions to) general partner and noncontrolling interest holders, net” in the consolidated statements of partners' capital and noncontrolling interest and of cash flows.

Operational Services Agreement

Concurrent with the closing of the IPO, we entered into an operational services agreement with CONSOL. On December 1, 2016, in connection with the consummation of our Sponsors' Exchange Agreement, pursuant to which CONSOL and Noble Energy separated their Marcellus Shale area of mutual interest into two separate operating areas (the “Exchange Agreement”), the operational services agreement was amended and restated. Under the amended and restated operating agreement, CONSOL continues to provide certain operational services to us in support of our gathering pipelines and dehydration, treating and compressor stations and facilities, including routine and emergency maintenance and repair services, routine operational activities, routine administrative services, construction and related services and such other services as we and CONSOL may mutually agree upon from time to time. CONSOL prepares and submits for our approval a maintenance, operating and capital budget on an annual basis. CONSOL submits actual expenditures for reimbursement on a monthly basis, and we reimburse CONSOL for any direct third-party costs incurred by CONSOL in providing these services.

Omnibus Agreement

Concurrent with the closing of the IPO, we entered into an omnibus agreement with CONSOL, Noble Energy, CONE Gathering and our general partner that addresses the following matters:

• our payment of an annually-determined administrative support fee, which will total $0.9 million for the year ending December 31, 2017, for the provision of certain services by CONSOL and its affiliates;

• our payment of an annually-determined administrative support fee, which will total $0.7 million for the year ending December 31, 2017, for the provision of certain executive services by CONSOL and its affiliates;

• our payment of an annually-determined administrative support fee, which will total $0.3 million for the year ending December 31, 2017, for the provision of certain executive services by Noble Energy and its affiliates;

• our obligation to reimburse our Sponsors for all other direct or allocated costs and expenses incurred by our Sponsors in providing general and administrative services (which reimbursement is in addition to certain expenses of our general partner and its affiliates that are reimbursed under our partnership agreement);

• our right of first offer to acquire (i) CONE Gathering’s retained interests in each of our Anchor Systems, Growth Systems and Additional Systems, (ii) CONE Gathering’s other ancillary midstream assets and (iii) any additional midstream assets that CONE Gathering develops; and

• an indemnity from CONE Gathering for liabilities associated with the use, ownership or operation of our assets, including environmental liabilities, to the extent relating to the period of time prior to the closing of the IPO; and our obligation to indemnify CONE Gathering for events and conditions associated with the use, ownership or operation of our assets that occur after the closing of the IPO, including environmental liabilities.

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So long as CONE Gathering controls our general partner, the omnibus agreement will remain in full force and effect. If CONE Gathering ceases to control our general partner, either party may terminate the omnibus agreement, provided that the indemnification obligations will remain in full force and effect in accordance with their terms.

Gathering Agreements

Upon consummation of the Exchange Agreement, we entered into new fixed-fee gathering agreements with each of CNX Gas Company LLC, a wholly owned subsidiary of CONSOL (“CNX Gas”), and Noble Energy that replaced the gathering agreements that had been in place since the IPO. In addition to incorporating changes related to the termination of CONSOL and Noble Energy's upstream joint venture and Joint Development Agreement, the new gathering agreements were designed to provide more clarity on each of CONSOL and Noble Energy's acreage dedications to the Partnership and related releases and to allow each of CONSOL and Noble Energy to independently advance their own development programs. The new gathering agreements were also designed to simplify the decision making process relating to the Partnership's ability to gather third party gas.

Our gathering agreement with Noble Energy was assigned to HG Energy upon consummation of the Noble Energy Asset Sale. The terms of the agreement remain unchanged following the assignment, except as it relates to HG Energy's inability to, without the Partnership's consent, release dedicated acreage in connection with a transfer of such acreage free of the dedication to us, and exercise other initial shipper rights provided under the gathering agreement. HG Energy is currently not a related party of the Partnership; accordingly, the focus of the disclosure below is on current and historical related party transactions, which do not include transactions with HG Energy.

Under the gathering agreements with CNX Gas and Noble Energy(from whom we received related party revenues through June 28, 2017), we receive a fee based on the type and scope of the midstream services we provide, summarized as follows:

• For the services we provide with respect to natural gas from the Marcellus Shale formation that does not require downstream processing, or dry gas, we receive a fee of $0.42 per MMBtu.

• For the services we provide with respect to the natural gas from the Marcellus Shale formation that requires downstream processing, or wet gas, we receive:

•a fee of $0.289 per MMBtu in the Moundsville area (Marshall County, West Virginia);

•a fee of $0.289 per MMBtu in the Pittsburgh International Airport area; and

•a fee of $0.578 per MMBtu for all other areas in the dedication area.

• For the services we provide with respect to natural gas from the Utica Shale formation, we receive a weighted average rate of $0.27 per MMBtu.

• For the condensate services we provide, we receive a fee of $5.25 per barrel (“Bbl”) in the Majorsville area and $2.627 per Bbl in the Moundsville area.

Each of the foregoing fees will escalate by 2.5% on January 1 of each year, beginning on January 1, 2018. Notwithstanding the foregoing, from time to time, CNX Gas may request rate reductions under certain circumstances, which are reviewed by the board of directors of our general partner, with oversight, as our board of directors deems necessary, by our conflicts committee. No rate reduction arrangements are currently active.

We gather, compress, dehydrate and deliver all of CNX Gas' dedicated natural gas in the Marcellus Shale on a first-priority basis and gather, inject, stabilize and store all of of CNX Gas' dedicated condensate on a first-priority basis, with the exception that until December 1, 2018, CNX Gas will receive first-priority service in our Majorsville system with respect to a certain volume of production (revised bi-annually) and any excess production will receive second-priority service.

We receive quarterly updates from CNX Gas on their drilling and development operations, which include detailed descriptions of the drilling plans, production details and well locations for the following 24 months and a three to ten year plan that includes more general development plans. In addition, we regularly meet with CNX Gas to discuss our plans to timely construct the necessary facilities to be able to provide midstream services to them on our dedicated acreage. In the event that we do not perform our obligations under a gathering agreement, CNX Gas will be entitled to certain rights and procedural remedies thereunder, including the temporary and/or permanent release from dedication discussed below and indemnification from us.

In addition to the natural gas and condensate that is produced from the dedicated acreage, CNX Gas may elect to dedicate to us non-Marcellus Shale properties located in the dedication area in which it has an interest. If it elects to dedicate any such property, then it will propose a fee for the associated midstream services we would provide. So long as the proposed fee generates a rate of return consistent with its existing gathering agreement on both incremental capital and operating expense associated with any expenditures necessary to gather gas from such property, any midstream services that we agree to provide will be on a second priority basis; second only to the first priority basis afforded to CNX Gas on its dedicated production.

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Throughput that we currently gather from Utica Shale wells operated by CNX Gas is also addressed in its gathering agreement with us.

While our gathering agreement with CNX Gas, as an initial shipper under our gas gathering agreement, runs with the land and, subject to the exceptions described therein, is binding upon the transferee of any of our dedicated acreage, the gathering agreement with CNX Gas provides that it may divest 25,000 net acres of its dedicated acreage (plus or minus the net of acreage acquired or divested within the dedicated area since our IPO) free of the dedication to us (the “Acreage Bucket”). The amount of net acreage that may be divested by CNX Gas free of the dedication will be increased by the amount, if any, of the net acreage acquired (or deemed to be acquired) by CNX Gas within the geographic boundaries of the dedication area that will become automatically dedicated to us. For purposes of determining if acreage can be released free and clear of the dedications under our gathering agreement with CNX Gas, the actual net acreage divested or acquired may be adjusted upwards or downwards based on the geographic location of such net acreage, the timing of the respective divestiture or acquisition and certain other conditions set forth in the agreement. During the six month period ended June 30, 2017, CNX Gas completed two land transactions, located primarily in the Additional Systems, that impacted our acreage dedication. These transactions involved both developed and undeveloped acreage. At August 7, 2017, CNX Gas has approximately 15,000 acres in its Acreage Bucket.

The Noble Energy gathering agreement also provided for an Acreage Bucket, as described above. However, this right was unique to Noble Energy, as an initial shipper under its gathering agreement, and was not transferred to HG Energy upon assignment of the gathering agreement. In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems and approximated the amount of the Acreage Bucket attributed to Noble Energy at the time of sale. After the Noble Energy Asset Sale, Noble Energy can no longer release acres from dedication.

There are no restrictions under our gathering agreements on the ability of CNX Gas to transfer acreage in the right of first offer (“ROFO”) area, and any such transfer of acreage in the ROFO area will not be subject to our right of first offer.  For additional information on the ROFO area, see Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations–How We Evaluate Our Operations–Throughput Volumes.

Upon completion of its initial term in 2034, each of our gathering agreements will continue in effect from year to year until such time as the agreement is terminated by either us or the other party to such agreement on or before 180 days prior written notice.

NOTE 5 — CONCENTRATION OF CREDIT RISK

CONSOL and Noble Energy accounted for a significant portion of the Partnership's revenue in 2017 and for all of its revenue in 2016. Revenues attributable to our customers were as follows for the periods presented:

	Three Months Ended June 30,				Six Months Ended June 30,
(in thousands)	2017		2016		2017		2016
CONSOL	$	31,953	$	29,825	$	66,339	$	61,624
Noble Energy	23,714		28,582		48,286		59,031
Other	867		—		867		—
Total Revenue	$	56,534	$	58,407	$	115,492	$	120,655

Effective June 28, 2017, upon consummation of the Noble Asset Sale, revenues attributable to Noble Energy ceased.

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NOTE 6 — RECEIVABLES

Receivables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Receivables - related party
CONSOL	$	10,177	$	10,956
Noble Energy	7,904		8,268
CONE Gathering	344		3,210
Receivables - related party	$	18,425	$	22,434
Receivables - third party	5,243		—
Receivables	$	23,668	$	22,434

Receivables - third party primarily includes a portion of our pipe stock that we sold during the quarter ended June 30, 2017 that was not collected until July 2017. See Note 8.

NOTE 7 — PROPERTY AND EQUIPMENT

Property and equipment consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016		Estimated Useful Lives in Years
Land	$	74,935	$	72,878	N/A
Gathering equipment	637,788		643,422		25 — 40
Compression equipment	171,724		169,681		30 — 40
Processing equipment	30,979		30,979		40
Assets under construction	24,782		13,772		N/A
Total Property and Equipment	$	940,208	$	930,732
Less: Accumulated depreciation
Gathering equipment	$	44,955	$	37,275
Compression equipment	12,719		10,590
Processing equipment	4,720		4,307
Total Accumulated Depreciation	$	62,394	$	52,172
Property and Equipment, Net	$	877,814	$	878,560

NOTE 8 — OTHER ASSETS

Other assets consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Pipe stock	$	392	$	8,596
Financing fees	204		286
Other	79		79
Total Other Assets	$	675	$	8,961

During the six months ended June 30, 2017, the Partnership sold a significant portion of its pipe stock to an unrelated third party for approximately $0.5 million below its carrying value, which we recorded as a loss from asset sales in the accompanying consolidated statements of operations. Any amounts outstanding from these sales at June 30, 2017 have been included in Receivables in the accompanying consolidated balance sheets. See Note 6.

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NOTE 9 — ACCOUNTS PAYABLE —RELATED PARTY

Related party payables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
CONSOL:
Expense reimbursements	$	1,131	$	999
Capital expenditures reimbursements	473		1,148
General and administrative services	1,080		1,964
Operational expenditures reimbursements	—		395
Other reimbursements	—		1,060
Total due to CONSOL	2,684		5,566
Noble Energy:
Capital expenditures reimbursements	—		1,105
General and administrative services	44		53
Operational expenditures reimbursements	—		401
Other reimbursements	—		1,060
Total due to Noble Energy	44		2,619
CONE Gathering LLC:
Capital expenditures reimbursement to CONE Gathering LLC	—		104
Total due to CONE Gathering LLC	—		104
Total Accounts Payable — Related Party	$	2,728	$	8,289

NOTE 10 — REVOLVING CREDIT FACILITY

We are party to a credit facility agreement which provides for a $250 million unsecured five year revolving credit facility that matures on September 30, 2019. Our revolving credit facility is available for working capital, capital expenditures, certain acquisitions, distributions, unit repurchases and other lawful partnership purposes. Borrowings under our revolving credit facility bear interest at our option at either:

• the base rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) JP Morgan’s prime rate; or (iii) the daily LIBOR rate for a one month interest period plus 1.00%; in each case, plus a margin varying from 0.125% to 1.00%, depending on our most recent consolidated total leverage ratio (as defined in the agreement governing our revolving credit facility) or our credit rating; or

• the LIBOR rate plus a margin varying from 1.125% to 2.00%, in each case, depending on our most recent consolidated leverage ratio (as defined in the agreement governing our revolving credit facility) or our credit rating, as the case may be.

Interest on base rate loans is payable quarterly. Interest on LIBOR loans is payable on the last day of each interest period or, in the case of interest periods longer than three months, every three months. The unused portion of our revolving credit facility is subject to a commitment fee ranging from 0.15% to 0.35% per annum depending on our most recent consolidated leverage ratio or our credit rating, as the case may be.

The outstanding balances and LIBOR interest rates in effect (plus applicable margin) on our revolving credit facility are as follows for the dates presented.

	June 30, 2017				December 31, 2016
(in thousands, except percentages)	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
Revolving credit facility	$	161,000	2.75	%	$	167,000	2.26	%

Our revolving credit facility also contains covenants and conditions that, among other things, limit (subject to certain exceptions) our ability to incur or guarantee additional debt, make cash distributions (though there will be an exception for

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distributions permitted under the partnership agreement, subject to certain customary conditions), incur certain liens or permit them to exist, make certain investments and acquisitions, enter into certain types of transactions with affiliates, merge or consolidate with another company, and transfer, sell or otherwise dispose of assets. In addition, our revolving credit facility contains other provisions, including circumstances that would result in a change of control, which is defined in the agreement as either CONSOL or Noble Energy failing to each own and control, directly or indirectly, at least 35% of the capital stock of our general partner. A change of control would constitute a default under our revolving credit facility unless waived or amended. Any such waiver or amendment may, among other things, result in a change to existing covenants and conditions based on current credit market conditions and changes in our credit profile as well as incremental costs to the Partnership.

We are subject to covenants that require us to maintain certain financial ratios, the most important of which are as follows:

• The ratio of (i) consolidated total funded debt (as defined in the agreement governing our revolving credit facility) as of the last day of each fiscal quarter to (ii) consolidated EBITDA (as defined in the agreement governing our revolving credit facility) for the four consecutive fiscal quarters ending on the last day of such fiscal quarter may not exceed (A) at any time other than during a qualified acquisition period (as defined in the agreement governing our revolving credit facility), 5.0 to 1.0 and (B) during a qualified acquisition period, 5.5 to 1.0. This consolidated leverage ratio is calculated as the total amount outstanding on our credit facility divided by EBITDA Attributable to General and Limited Partner Ownership Interest in the CONE Midstream Partners LP. The Partnership is in compliance with this financial covenant at June 30, 2017.

• The ratio of (i) consolidated EBITDA for the four consecutive fiscal quarters ending on the last day of each fiscal quarter to (ii) consolidated interest expense (as defined in the agreement governing our revolving credit facility) for such four consecutive fiscal quarters may not be less than 3.0 to 1.0. This consolidated interest coverage ratio is calculated as EBITDA Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP divided by total interest charges. The Partnership is in compliance with this financial covenant at June 30, 2017.

Based on our compliance with the financial covenants, the Partnership had $89.0 million, the maximum amount of revolving credit, available for borrowing at June 30, 2017.

As of June 30, 2017, we had outstanding debt issuance costs of $0.4 million, net of accumulated amortization, which were incurred in connection with the issuance of our credit facility. The debt issuance costs are being amortized in interest expense through September 30, 2019, which is the maturity date of the credit facility.

NOTE 11 — COMMITMENTS AND CONTINGENCIES

We may become involved in claims and other legal matters arising in the ordinary course of business. Although claims are inherently unpredictable, we are not aware of any matters that may have a material adverse effect on our business, financial position, results of operations or cash flows.

NOTE 12 — LEASES

We have entered into various non-cancelable operating leases, primarily related to compression facilities. Future minimum lease payments under operating leases as of June 30, 2017 are as follows:

(in thousands)	Minimum Lease Payments
remainder of 2017	$	2,539
2018	2,426
2019	1,068
2020	366
	$	6,399

Rental expense under operating leases was $1.9 million for the three months ended June 30, 2017 and 2016 and $3.8 million and $4.0 million for six months ended June 30, 2017 and 2016, respectively. These expenses are included within operating expense - third party on our consolidated statement of operations.

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NOTE 13—SEGMENT INFORMATION

Operating segments are the revenue-producing components of a company for which separate financial information is produced internally and is subject to evaluation by the chief operating decision maker in deciding how to allocate resources. The Partnership has three operating segments, which are also its reportable segments - the Anchor Systems, Growth Systems and Additional Systems, each of which does business entirely within the United States of America. See Note 1–Description of Business for details.

Segment results for the periods presented were as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
(in thousands)	2017		2016			2017		2016
Gathering Revenue:
Anchor Systems	$	46,799	$	48,855		$	96,338	$	99,145
Growth Systems	2,018		2,708			4,243		5,599
Additional Systems	7,717		6,844			14,911		15,911
Total Gathering Revenue	$	56,534	$	58,407		$	115,492	$	120,655
Net Income (Loss):
Anchor Systems	$	28,950	$	31,418		$	58,850	$	64,169
Growth Systems	506		(9,251		)	453		(8,316		)
Additional Systems	296		2,301			3,689		5,908
Total Net Income	$	29,752	$	24,468		$	62,992	$	61,761
Depreciation Expense:
Anchor Systems	$	3,748	$	3,550		$	7,491	$	6,854
Growth Systems	543		531			1,088		1,060
Additional Systems	1,384		1,071			2,767		2,078
Total Depreciation Expense	$	5,675	$	5,152		$	11,346	$	9,992
Capital Expenditures for Segment Assets:
Anchor Systems	$	9,996	$	7,070		$	20,149	$	22,241
Growth Systems	382		159			821		228
Additional Systems	1,845		2,109			2,445		11,255
Total Capital Expenditures	$	12,223	$	9,338		$	23,415	$	33,724

Segment assets as of the dates presented were as follows:

(in thousands)	June 30, 2017		December 31, 2016
Segment Assets
Anchor Systems	$	582,236	$	571,415
Growth Systems	97,550		98,447
Additional Systems	229,151		248,695
Total Segment Assets	$	908,937	$	918,557

NOTE 14 — LONG-TERM INCENTIVE PLAN

Under the CONE Midstream Partners LP 2014 Long-Term Incentive Plan (our “LTIP”), our general partner may issue long-term equity based awards to directors, officers and employees of the general partner or its affiliates, or to any consultants, affiliates of our general partner or other individuals who perform services on behalf of the Partnership. The Partnership is responsible for the cost of awards granted under the LTIP, which limits the number of units that may be delivered pursuant to

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vested awards to 5,800,000 common units, subject to proportionate adjustment in the event of unit splits and similar events. Common units subject to awards that are canceled, forfeited, withheld to satisfy tax withholding obligations or otherwise terminated without delivery of the common units will be available for delivery pursuant to other awards.

During the six months ended June 30, 2017, our general partner granted equity-based phantom units under our LTIP. Awards granted to independent directors vest over a period of one year, and awards granted to certain officers and employees of the general partner vest 33% per year over a period of three years. The following table presents phantom unit activity during the six months ended June 30, 2017:

	Number of Units	Weighted Average Grant Date Fair Value
Total awarded and unvested at December 31, 2016	158,117	$	10.57
Granted	67,112	23.86
Vested	(75,734)	10.82
Forfeited	(2,680)	15.04
Total awarded and unvested at June 30, 2017	146,815	$	16.43

The Partnership accounts for phantom units as equity awards and records compensation expense based on the fair value of the awards at their grant date. The Partnership recognized $0.4 million and $0.2 million of compensation expense for the three months ended June 30, 2017 and 2016, respectively and $0.7 million and $0.4 million for six months ended June 30, 2017 and 2016, respectively, which was included in general and administrative expense - related party in the consolidated statements of operations.

At June 30, 2017, the unrecognized compensation related to all outstanding awards was $1.7 million.

NOTE 15 — SUBSEQUENT EVENTS

On July 21, 2017, the Board of Directors of CONE Midstream GP LLC, the Partnership's general partner, declared a cash distribution to the Partnership’s unitholders with respect to the second quarter of 2017 of $0.2922 per common and subordinated unit. The cash distribution will be paid on August 14, 2017 to unitholders of record at the close of business on August 4, 2017.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

You should read the following discussion of the financial condition and results of operations of CONE Midstream Partners LP in conjunction with the historical and unaudited interim consolidated financial statements and notes to the consolidated financial statements. Among other things, those historical unaudited interim consolidated financial statements include more detailed information regarding the basis of presentation for the following information. This discussion contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those discussed in such forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, those identified under "forward-looking statements" below and those discussed in the section entitled "Risk Factors" in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 and in Part II, Item 1A, "Risk Factors" of this Quarterly Report on Form 10-Q. In this Item 2, all references to "we," us," "our," the "Partnership," "CNNX," or similar terms refer to CONE Midstream Partners LP and its subsidiaries.

Executive Overview

We are a master limited partnership formed in May 2014 by CONSOL Energy Inc. (“CONSOL”) and Noble Energy, Inc. (“Noble Energy”) primarily to own, operate, develop and acquire natural gas gathering and other midstream energy assets to service each of CONSOL's and Noble Energy's production in the Marcellus Shale in Pennsylvania and West Virginia. Our assets include natural gas gathering pipelines and compression and dehydration facilities, as well as condensate gathering, collection, separation and stabilization facilities.

On September 30, 2011, CONSOL and Noble Energy entered into a Joint Development Agreement (“JDA”) and related ancillary agreements governing their joint exploration and development of their combined acreage in the Marcellus Shale, which comprised an area of mutual interest (“AMI”) that covered portions of 28 counties in West Virginia and 19 counties in Pennsylvania and included over 26,000 square miles (the “Co-Owned Properties”). Pursuant to the JDA, each of CONSOL and Noble Energy owned an undivided 50% working interest in the jointly owned Marcellus Shale acreage, and under the JDA, any other oil and natural gas interests covering the Marcellus Shale within the AMI that became jointly owned by CONSOL and Noble Energy would have automatically become part of the upstream acreage. 

On December 1, 2016, CONSOL and Noble Energy consummated an Exchange Agreement (the “Exchange Agreement”), pursuant to which, effective as of October 1, 2016, the JDA was terminated and CONSOL and Noble Energy separated their Marcellus Shale AMI into two separate operating areas.  Under the Exchange Agreement, CNX Gas Company LLC, a wholly owned subsidiary of CONSOL (“CNX Gas”), and Noble Energy exchanged certain jointly owned oil and gas properties and related assets that were previously subject to the JDA.

Following consummation of the Exchange Agreement, each of CNX Gas and Noble Energy owned 100% of their respective upstream interests in the Marcellus Shale. Accordingly, we entered into new fixed-fee gathering agreements with each of CNX Gas and Noble Energy that replaced the gathering agreements that had been in place since our initial public offering (“IPO”).

Noble Energy Sale of Upstream Assets

On June 28, 2017, Noble Energy closed the previously announced sale of its upstream assets in northern West Virginia and southern Pennsylvania to HG Energy II Appalachia, LLC (“HG Energy”), a portfolio company of Quantum Energy Partners, LP (“Quantum”), effectively making HG Energy the new shipper on the dedicated acreage that was previously owned by Noble Energy (the “Noble Energy Asset Sale”). In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems, from amounts dedicated to us as per the terms of our gathering agreement, which is more fully discussed in Note 4. The Partnership is in the process of confirming the amount of acreage that was released from dedication to us.

Effective June 28, 2017, the Partnership gathers the production by HG Energy on our dedicated acreage under the terms of our gathering agreement with Noble Energy, which was assigned to HG Energy upon consummation of the Noble Energy Asset Sale.

Noble Energy Proposed Sale of Interests in the Partnership and CONE Gathering

On May 18, 2017, Noble Energy announced that it had reached an agreement to sell its 50% membership interest in CONE Gathering LLC, a Delaware limited liability company and the sole member of our general partner (“CONE Gathering”), as well as 7,110,638 common units and 14,581,560 subordinated units in the Partnership (collectively, the “Interests”), to Wheeling Creek Midstream, LLC (“Wheeling Creek”), a portfolio company of Quantum (the “Wheeling Creek Acquisition”). The proposed transaction, which Noble Energy has announced it expects to close in the second half of 2017, is subject to customary closing conditions. CONSOL has advised Noble Energy that CONSOL disagrees with Noble Energy’s ability to sell its interest in CONE Gathering, which wholly owns our general partner, without first offering a preferential right of purchase to CONSOL. Accordingly, CONSOL has filed a lawsuit against Noble Energy seeking to enforce this right. Noble Energy disputes

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that CONSOL has such a right. See also Item 1A. Risk Factors for other risks associated with the proposed Wheeling Creek Acquisition.

As of August 7, 2017, Noble Energy continues to own the Interests. Accordingly, in this Quarterly Report on Form 10-Q, we may refer to CONSOL and Noble Energy together as our Sponsors.

Ownership of Our Assets

On September 30, 2014, in connection with the completion of the IPO, CONE Gathering contributed to us a 75% controlling interest in our Anchor Systems, a 5% controlling interest in our Growth Systems and a 5% controlling interest in our Additional Systems. Accordingly, most income statement line items, including net income, reflect the results of the Anchor Systems, Growth Systems and Additional Systems on a 100% basis, with the exception of net income attributable to general and limited partner ownership interests in CONE Midstream Partners LP, which only includes our controlling interests in these Systems.

On November 16, 2016 we acquired the remaining 25% limited partner noncontrolling interest in the Anchor Systems from CONE Gathering (the “Anchor Systems Acquisition”). Accordingly, our net income attributable to general and limited partner ownership interests in CONE Midstream Partners LP includes our 100% controlling interest in the Anchor Systems for the three month and six month periods ended June 30, 2017. However, for the three months and six months ended June 30, 2016, net income attributable to general and limited partner ownership interests in CONE Midstream Partners LP only includes our 75% controlling interest in the Anchor Systems during those periods.

Second Quarter 2017 Highlights

The Partnership continued its solid financial performance in the quarter ended June 30, 2017. Compared to the quarter ended June 30, 2016, results attributable to the general partner and limited partner ownership interests in the Partnership increased primarily as a result of the Anchor Systems Acquisition. Comparative results net to the Partnership, with the exception of operating cash flows, which is shown on a gross consolidated basis, were as follows for the quarters ended June 30, 2017 and 2016, respectively:

• Net income of $29.0 million as compared to $23.2 million;

• Average daily throughput volumes of 981 billion Btu per day (BBtu/d) as compared to 857 BBtu/d;

• Cash provided by operating activities of $42.3 million as compared to $41.8 million;

• Adjusted EBITDA (non-GAAP) of $34.4 million as compared to $26.9 million; and

• Distributable cash flow (non-GAAP) of $29.6 million as compared to $23.6 million

Consistent with each of the last four consecutive quarters, the current quarter's cash provided by operating activities exceeded the sum of capital expenditures ($12.2 million), distributions to unitholders ($18.8 million) and interest paid ($1.1 million).

A discussion of why the above metrics are important to management, and how the non-GAAP financial measures reconcile to their nearest comparable financial measures prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) follows below.

How We Evaluate Our Operations

Our management uses a variety of financial and operating metrics to analyze our performance. These metrics are significant factors in assessing our operating results and profitability and include: (i) throughput volumes; (ii) EBITDA and Adjusted EBITDA; (iii) distributable cash flow and (iv) operating expenses.

Throughput Volumes

The amount of revenue we generate primarily depends on the volumes of natural gas and condensate that we gather for our largest customers, CNX Gas and HG Energy, which are primarily affected by upstream development drilling and production volumes from the natural gas wells connected to our gathering pipelines. Their willingness to engage in new drilling in the Marcellus Shale is determined by a number of factors, which include the prevailing and projected prices of natural gas, natural gas liquids (“NGLs”) and crude oil, the cost to drill and operate a well, the relative economics of alternative drilling opportunities available to our customers, the availability and cost of capital, and environmental and government regulations.

In order to meet our contractual obligations under our gathering agreements with CNX Gas and HG Energy with respect to new wells drilled on our dedicated acreage, we will likely incur capital expenditures to extend our gathering systems and facilities to the new wells that each of CNX Gas and HG Energy drill. CONSOL and Noble Energy, through their ownership interests in CONE Gathering, are responsible for their proportionate share (95%) of the total capital expenditures associated with the ongoing build-out of our midstream systems in each of the Growth and Additional Systems.

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Our gathering agreements with CNX Gas and Noble Energy, as initial shippers, run with the land and, subject to the exceptions described therein, is binding upon the transferee of any of our dedicated acreage. The CNX Gas gathering agreement provides, and in the case of Noble Energy, its gathering agreement provided, that CNX Gas and Noble Energy may divest 25,000 net acres of its dedicated acreage (plus or minus the net of acreage acquired or divested within the dedicated area since our IPO) free of the dedication to us (the “Acreage Bucket”). The amount of net acreage that may be divested free of the dedication will be increased by the amount, if any, of the net acreage acquired (or deemed to be acquired) within the geographic boundaries of the dedication area that will become automatically dedicated to us. For purposes of determining if acreage can be released free and clear of the dedications, the actual net acreage divested or acquired may be adjusted upwards or downwards based on the geographic location of such net acreage, the timing of the respective divestiture or acquisition and certain other conditions set forth in the agreements.

During the six month period ended June 30, 2017, CNX Gas completed two land transactions, located primarily in the Additional Systems, that reduced its acreage dedication to us by 22,500 acres. Following these transactions, which involved both developed and undeveloped acreage, CNX Gas has approximately 15,000 acres in its Acreage Bucket. In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems, which approximated the amount of the Acreage Bucket attributed to Noble Energy at the time of sale. After the Noble Energy Asset Sale, Noble Energy can no longer release acres from dedication.

HG Energy does not have an Acreage Bucket, as it is not an initial shipper under the Noble Energy gathering agreement, which was assigned to them upon consummation of the Noble Energy Asset Sale.

At August 7, 2017, we have acreage dedications from CNX Gas and HG Energy of approximately 455,000 aggregate acres, subject to our confirmation of the amount of acreage that was released from dedication to us during 2017.

In addition to our existing dedicated acreage, our gathering agreements provide that any additional acreage covering the Marcellus Shale that is acquired by CNX Gas or HG Energy, respectively, in a “dedication area” that covers over 7,700 square miles in West Virginia and Pennsylvania, and that is not subject to a pre-existing third-party commitment, will be automatically dedicated to us. In addition to our existing dedication acreage and any potential future dedicated acreage, we have also been granted rights of first offer (“ROFO”) by each of CNX Gas and HG Energy to provide midstream services on their respective ROFO acreage, which currently includes approximately 186,000 aggregate net acres of CNX Gas’ and HG Energy's existing Marcellus Shale acreage that is not currently dedicated to us, along with any future acreage covering the Marcellus Shale formation that is acquired by CNX Gas or HG Energy, as applicable, in an area that covers over 18,300 square miles in West Virginia and Pennsylvania, which we refer to as the “ROFO area,” and that is not subject to a pre-existing third-party commitment. 

Adjusted EBITDA & Distributable Cash Flow

Adjusted EBITDA and distributable cash flow are non-GAAP measures that we believe provide information useful to investors in assessing our financial condition and results of operations. For a discussion on how we define Adjusted EBITDA and distributable cash flow and the supporting reconciliations to their most directly comparable GAAP financial measures, please read “Non-GAAP Financial Measures” below.

Operating Expense

Operating expense is comprised of costs directly associated with gathering natural gas at the wellhead and transporting it to interstate and intrastate pipelines, natural gas processing facilities or other delivery points. These costs include electrically-powered compression, direct labor, repairs and maintenance, supplies, ad valorem and property taxes, utilities and contract services. These expenses generally remain stable across broad ranges of throughput volumes but can fluctuate from period to period depending on the mix of activities performed during that period and the timing of these expenses.

Factors Impacting Our Business

We expect our business to continue to be affected by the following key factors. Our expectations are based on assumptions made by us and information currently available to us. To the extent our underlying assumptions about, or interpretations of, available information prove to be incorrect, our actual results may vary materially from our expected results.

Drilling and Development Plans

Our operations are primarily dependent upon CNX Gas' and HG Energy's natural gas production on our dedicated acreage in the Marcellus Shale. Each of CNX Gas and HG Energy maintains its own drilling and development program on their respective upstream acreage, including on our dedicated acreage, and primarily relies on us to deliver the midstream

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infrastructure necessary to accommodate its continuing production growth in the Marcellus Shale. However, we have no control over the level or timing of their exploration and production activities in our areas of operation in the Marcellus Shale. For example, neither of our Sponsors had active drilling activities on our dedicated acreage in 2016, and as of June 30, 2017, CNX Gas had one active rig on our dedicated acreage.

Earlier in 2017, CONSOL announced its plans to reduce drilling activity on its Marcellus Shale acreage during 2018 while accelerating drilling activity in the Utica Shale. Although the Utica Shale acreage is not dedicated to us, we believe that we are advantageously positioned to gather its Utica Shale production, to the extent it is within our operating area, based on the proximity of the drilling locations to our current infrastructure. On August 1, 2017, CONSOL raised its 2017 capital spending and 2018 production guidance and also disclosed plans to drill additional wells in 2017 and accelerate the schedule of turn-in-lines. Subsequent to those disclosures, CONSOL submitted to us their quarterly development plan reflecting the corresponding portion of that additional activity slated to occur within our dedicated area. Based on this development plan, we anticipate the additional development activity planned by CONSOL may have a positive impact on our volumes beginning in 2018; however, we do not anticipate it will have a material impact on 2017 revenues.

We are also actively engaged with HG Energy to provide gathering services to support and increase their current production as well as the future development of their acquired acreage. While we do not expect to receive a detailed development plan from them until the end of August 2017, based on our conversations with them to date, we believe they will pursue more active development than the most recent plan provided by Noble Energy.

Fluctuations in natural gas prices could affect production rates over time and levels of investment by our customers and potential customers in exploration for and development of new natural gas reserves. Over parts of the last two years, persistent low commodity prices caused and may continue to cause producers to delay drilling or shut in production, which would reduce the volumes of natural gas and condensate available for gathering by our midstream systems. If either of CNX Gas or HG Energy reduces or delays drilling or temporarily shuts in production due to persistently low commodity prices or for any other reason, we are not assured a certain amount of revenue, as the gathering agreements with CNX Gas and HG Energy do not contain minimum volume commitments.

Regulatory Compliance

The regulation of natural gas and condensate gathering and transportation activities by federal and state regulatory agencies has a significant impact on our business. For example, the U.S. Department of Transportation's Pipeline and Hazardous Materials Safety Administration has developed regulations that require pipeline operators to implement integrity management programs, including more frequent inspections and other measures to ensure pipeline safety in high-consequence areas. Our operations are also impacted by new regulations, which have increased the time that it takes to obtain required permits.

Additionally, increased regulation of oil and natural gas producers in our areas of operation, including regulation associated with hydraulic fracturing, could reduce regional supply of oil and natural gas and therefore affect throughput on our gathering systems.

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Results of Operations

Quarter Ended June 30, 2017 Compared to the Quarter Ended June 30, 2016

	Quarter Ended June 30,
	2017		2016		Change ($)			Change (%)
	($ in thousands)
Revenue
Gathering revenue — related party	$	55,667	$	58,407	$	(2,740	)	(4.7	)%
Gathering revenue — third party	867		—		867			100.0	%
Total Revenue	56,534		58,407		(1,873		)	(3.2	)%
Expenses
Operating expense — related party	7,089		7,078		11			0.2	%
Operating expense — third party	5,957		7,879		(1,922		)	(24.4	)%
General and administrative expense — related party	2,715		2,213		502			22.7	%
General and administrative expense — third party	981		1,153		(172		)	(14.9	)%
Loss on asset sales	3,241		10,083		(6,842		)	(67.9	)%
Depreciation expense	5,675		5,152		523			10.2	%
Interest expense	1,124		381		743			195.0	%
Total Expense	26,782		33,939		(7,157		)	(21.1	)%
Net Income	$	29,752	$	24,468	$	5,284		21.6	%
Less: Net income attributable to noncontrolling interest	761		1,251		(490		)	(39.2	)%
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP (*)	$	28,991	$	23,217	$	5,774		24.9	%

Operating Statistics - Gathered Volumes for the Quarter Ended June 30, 2017

	Anchor	Growth	Additional	TOTAL	NET TOTAL (*)
Dry Gas (BBtu/d) (**)	589	47	11	647	592
Wet Gas (BBtu/d) (**)	373	4	190	567	383
Condensate (MMcfe/d)	6	—	3	9	6
Total Gathered Volumes	968	51	204	1,223	981

Operating Statistics - Gathered Volumes for the Quarter Ended June 30, 2016

	Anchor	Growth	Additional	TOTAL	NET TOTAL (*)
Dry Gas (BBtu/d) (**)	775	64	16	855	585
Wet Gas (BBtu/d) (**)	347	6	132	485	267
Condensate (MMcfe/d)	6	—	6	12	5
Total Gathered Volumes	1,128	70	154	1,352	857

(*)On November 16, 2016, the Partnership acquired the remaining 25% noncontrolling interest in the Anchor Systems from CONE Gathering. The Partnership owned a 100% controlling limited partner interest in the Anchor Systems during the quarter ended June 30, 2017 and a 75% controlling interest in the Anchor Systems during the quarter ended June 30, 2016. See "Ownership of Our Assets" above.

(**) Classification as dry or wet is based upon the shipping destination of the related volumes. Because our customers have the option to ship a portion of their natural gas to destinations associated with either our wet system or our dry system, due to any number of factors, volumes may be classified as "wet" in one period and as "dry" in the comparative period. Although there were no such instances in the periods presented above, this remains a possibility in future periods.

Revenue    

Our revenue typically increases or decreases as our customers’ production on our dedicated acreage increases or decreases. Since we charge a higher fee for natural gas that is shipped through our wet system than through our dry system, our

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revenue can also be impacted by the relative mix of gathered volumes by area, which may vary dependent upon our customers' elections as to where to deliver their produced volumes, which may change dynamically depending on the most current commodity prices at the time of shipment.

Total revenue decreased approximately 3.2% to $56.5 million for the three months ended June 30, 2017 compared to approximately $58.4 million for the three months ended June 30, 2016 despite a 9.5% decrease in the total volumes that we gathered between the two quarters. This is primarily due to the mix of the type of gas that we gathered in the current quarter compared to the prior year quarter. In the comparative periods, we gathered 16.9% more wet gas in the current year quarter than the prior year quarter and 24.3% less dry gas in the current quarter than the prior year quarter. Our overall decrease in volumes gathered of 9.5% compared to the prior year quarter was primarily the result of well declines exceeding the benefit of new wells being turned in line over the last 12 months. The volume decrease was primarily within our Anchor Systems.

Operating Expense

Total operating expenses were approximately $13.0 million in the current quarter compared to approximately $15.0 million in the prior year quarter. Included in total operating expense was electrically-powered compression expense of $4.1 million for the three months ended June 30, 2017 compared to $3.9 million for the three months ended June 30, 2016, which was reimbursed by our customers pursuant to our gas gathering agreements. After adjusting for the electrically-powered compression expense reimbursement, operating expenses decreased by approximately 19.4% in the current quarter compared to the prior year quarter, primarily as a result of adherence to operating cost control measures implemented by our operations team in the prior year.

General and Administrative Expense

General and administrative expense is comprised of direct charges for the management and operation of our assets. Total general and administrative expense was approximately $3.7 million in the current quarter compared to approximately $3.4 million in the prior year quarter, due primarily to changes in how our general partner allocated certain personnel-related costs in the current quarter, including incentive compensation.

Loss on Asset Sales

During the quarter ended June 30, 2017, the Partnership sold property and equipment with a carrying value of $17.4 million to CNX Gas for $14.0 million in cash proceeds. In connection with its receipt of midstream assets from us and its follow on sale of combined upstream and midstream assets to an unrelated third party, CNX Gas also released approximately 10,000 acres from dedication to us under its Acreage Bucket. Our sale of midstream assets resulted in a loss of $3.4 million, which was recorded in loss on asset sales in the accompanying consolidated statement of operations. The assets that were sold, and acreage that was released, were previously within the Additional Systems; accordingly the net impact to earnings attributable to general and limited partners' ownership interests in the Partnership was $0.2 million.

During the quarter ended June 30, 2016, we sold a portion of excess pipe supply from the Growth Systems to an unrelated third party for an amount that was below its carrying value.  We recorded a loss of $10.1 million related to the sale during the 2016 quarter; however, the net impact to earnings attributable to general and limited partners' ownership interests in the Partnership was $0.5 million.

Depreciation Expense    

Depreciation expense is recognized on gathering and other equipment on a straight-line basis, with useful lives ranging from 25-40 years. Total depreciation expense was approximately $5.7 million in the three months ended June 30, 2017 compared to approximately $5.2 million in the three months ended June 30, 2016. The increase is the result of additional assets placed into service over time.

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Six Months Ended June 30, 2017 Compared to the Six Months Ended June 30, 2016

	Six Months Ended June 30,
	2017		2016		Change ($)			Change (%)
	($ in thousands)
Revenue
Gathering revenue — related party	114,625		120,655		(6,030		)	(5.0	)%
Gathering revenue — third party	867		—		867			100.0	%
Total Revenue	115,492		120,655		(5,163		)	(4.3	)%
Expenses
Operating expense — related party	14,717		15,422		(705		)	(4.6	)%
Operating expense — third party	12,590		16,553		(3,963		)	(23.9	)%
General and administrative expense — related party	5,651		3,897		1,754			45.0	%
General and administrative expense — third party	2,120		2,147		(27		)	(1.3	)%
Loss on asset sales	3,914		10,083		(6,169		)	(61.2	)%
Depreciation expense	11,346		9,992		1,354			13.6	%
Interest expense	2,162		800		1,362			170.3	%
Total Expense	52,500		58,894		(6,394		)	(10.9	)%
Net Income	$	62,992	$	61,761	$	1,231		2.0	%
Less: Net income attributable to noncontrolling interest	3,934		13,755		(9,821		)	(71.4	)%
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP (*)	$	59,058	$	48,006	$	11,052		23.0	%

Operating Statistics - Gathered Volumes for the Six Months Ended June 30, 2017

	Anchor	Growth	Additional	TOTAL	NET TOTAL (*)
Dry Gas (BBtu/d) (**)	625	50	20	695	629
Wet Gas (BBtu/d) (**)	378	4	173	555	387
Condensate (MMcfe/d)	5	—	3	8	5
Total Gathered Volumes	1,008	54	196	1,258	1,021

Operating Statistics - Gathered Volumes for the Six Months Ended June 30, 2016

	Anchor	Growth	Additional	TOTAL	NET TOTAL (*)
Dry Gas (BBtu/d) (**)	712	66	20	798	538
Wet Gas (BBtu/d) (**)	402	6	154	562	310
Condensate (MMcfe/d)	6	—	7	13	5
Total Gathered Volumes	1,120	72	181	1,373	853

(*)On November 16, 2016, the Partnership acquired the remaining 25% noncontrolling interest in the Anchor Systems from CONE Gathering. The Partnership owned a 100% controlling limited partner interest in the Anchor Systems during the six months ended June 30, 2017 and a 75% controlling interest in the Anchor Systems during the six months ended June 30, 2016. See "Ownership of Our Assets" above.

(**) Classification as dry or wet is based upon the shipping destination of the related volumes. Because our customers have the option to ship a portion of their natural gas to destinations associated with either our wet system or our dry system, due to any number of factors, volumes may be classified as "wet" in one period and as "dry" in the comparative period. Although there were no such instances in the periods presented above, this remains a possibility in future periods.

Revenue    

Our revenue typically increases or decreases as our customers’ production on our dedicated acreage increases or decreases. Since we charge a higher fee for natural gas that is shipped through our wet system than through our dry system, our revenue can also be impacted by the relative mix of gathered volumes by area, which may vary dependent upon our customers'

29

elections as to where to deliver their produced volumes, which may change dynamically depending on the most current commodity prices at the time of shipment.

Total revenue decreased approximately 4.3% to $115.5 million for the six months ended June 30, 2017 compared to $120.7 million for the six months ended June 30, 2016, while gathered volumes decreased approximately 8.4% in the current six month period compared to the prior year period. The volume decrease compared to the prior year period was partially offset by the annual 2.5% increase in gathering fees that we charge our Sponsors per our gas gathering agreements and a positive mix of wet gas gathered versus dry gas gathered in the current period compared to the prior year period.

Operating Expense

Total operating expenses were approximately $27.3 million for the six months ended June 30, 2017 compared to approximately $32.0 million for the six months ended June 30, 2016. Included in total operating expense was electrically-powered compression expense of $8.6 million for the six months ended June 30, 2017 compared to $8.3 million for the six months ended June 30, 2016, which was reimbursed by our customers pursuant to our gas gathering agreements. After adjusting for the electrically-powered compression expense reimbursement, operating expenses decreased by approximately 21.0% in the current six month period compared to the prior year period, primarily as a result of our adherence to operating cost control measures implemented in the prior year period.

General and Administrative Expense

General and administrative expense is comprised of direct charges for the management and operation of our assets. Total general and administrative expense was approximately $7.8 million for the six months ended June 30, 2017 compared to approximately $6.0 million for the six months ended June 30, 2016, due primarily to changes in how the general partner allocated certain personnel-related costs in the current quarter, including incentive compensation.

Loss on Asset Sales

During the six months ended June 30, 2017, the Partnership sold property and equipment with a carrying value of $17.4 million to CNX Gas for $14.0 million in cash proceeds. In connection with its receipt of midstream assets from us and its follow on sale of combined upstream and midstream assets to an unrelated third party, CNX Gas also released approximately 10,000 acres from dedication to us under its Acreage Bucket. Our sale of midstream assets resulted in a loss of $3.4 million, which was recorded in loss on asset sales in the accompanying consolidated statement of operations. The assets that were sold, and acreage that was released, were previously within the Additional Systems; accordingly the net impact to earnings attributable to general and limited partners' ownership interests in the Partnership was $0.2 million. In addition, we also sold a significant portion of our pipe stock to an unrelated third party for approximately $0.5 million below its carrying value during the current six month period.

During the six months ended June 30, 2016, we sold a portion of excess pipe supply from the Growth Systems to an unrelated third party for an amount that was below its carrying value.  We recorded a loss of $10.1 million related to the sale during the 2016 quarter; however, the net impact to earnings attributable to general and limited partners' ownership interests in the Partnership was $0.5 million.

Depreciation Expense    

Depreciation expense is recognized on gathering and other equipment on a straight-line basis, with useful lives ranging from 25-40 years. Total depreciation expense was approximately $11.3 million for the six months ended June 30, 2017 compared to approximately $10.0 million for the six months ended June 30, 2016. The increase is the result of additional assets placed into service over time.

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Definition of Non-GAAP Financial Measures

EBITDA and Adjusted EBITDA

We define EBITDA as net income (loss) before net interest expense, depreciation and amortization, and Adjusted EBITDA as EBITDA adjusted for non-cash items which should not be included in the calculation of distributable cash flow. EBITDA and Adjusted EBITDA are used as supplemental financial measures by management and by external users of our financial statements, such as investors, industry analysts, lenders and ratings agencies, to assess:

• our operating performance as compared to those of other companies in the midstream energy industry, without regard to financing methods, historical cost basis or capital structure;

• the ability of our assets to generate sufficient cash flow to make distributions to our partners;

• our ability to incur and service debt and fund capital expenditures; and

• the viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.

We believe that the presentation of EBITDA and Adjusted EBITDA provides information that is useful to investors in assessing our financial condition and results of operations. The GAAP measures most directly comparable to EBITDA and Adjusted EBITDA are net income and net cash provided by operating activities. EBITDA and Adjusted EBITDA should not be considered alternatives to net income, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. EBITDA and Adjusted EBITDA exclude some, but not all, items that affect net income or net cash, and these measures may vary from those of other companies. As a result, EBITDA and Adjusted EBITDA as presented herein may not be comparable to similarly titled measures that other companies may use.

Distributable Cash Flow

We define distributable cash flow as Adjusted EBITDA less net income attributable to noncontrolling interest, cash interest paid and maintenance capital expenditures, each net to the Partnership. Distributable cash flow does not reflect changes in working capital balances.

Distributable cash flow is used as a supplemental financial measure by management and by external users of our financial statements, such as investors, industry analysts, lenders and ratings agencies, to assess:

• the ability of our assets to generate cash sufficient to support our indebtedness and make future cash distributions to our unitholders; and

• the attractiveness of capital projects and acquisitions and the overall rates of return on alternative investment opportunities.

We believe that the presentation of distributable cash flow in this report provides information useful to investors in assessing our financial condition and results of operations. The GAAP measures most directly comparable to distributable cash flow are net income and net cash provided by operating activities. Distributable cash flow should not be considered an alternative to net income, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Distributable cash flow excludes some, but not all, items that affect net income or net cash, and these measures may vary from those of other companies. As a result, our distributable cash flow may not be comparable to similarly titled measures that other companies may use.

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The following table presents a reconciliation of the non-GAAP measures of adjusted EBITDA and distributable cash flow to the most directly comparable GAAP financial measures of net income and net cash provided by operating activities.

	Three Months Ended   June 30,						Six Months Ended   June 30,
(in thousands)	2017			2016			2017			2016
Net Income	$	29,752		$	24,468		$	62,992		$	61,761
Depreciation expense	5,675			5,152			11,346			9,992
Interest expense	1,124			381			2,162			800
EBITDA	36,551			30,001			76,500			72,553
Non-cash unit-based compensation expense	367			219			650			355
Loss on asset sales	3,241			10,083			3,914			10,083
Adjusted EBITDA	40,159			40,303			81,064			82,991
Less:
Net income attributable to noncontrolling interest	761			1,251			3,934			13,755
Depreciation expense attributable to noncontrolling interest	1,833			2,409			3,663			4,694
Other expenses attributable to noncontrolling interest	112			127			194			316
Loss on asset sales attributable to noncontrolling interest	3,079			9,579			3,718			9,579
Adjusted EBITDA attributable to General and Limited Partner ownership interest in CONE Midstream Partners LP	$	34,374		$	26,937		$	69,555		$	54,647
Less: cash interest paid, net	1,079			254			2,079			484
Less: maintenance capital expenditures, net of reimbursements	3,715			3,112			7,596			5,951
Distributable Cash Flow	$	29,580		$	23,571		$	59,880		$	48,212
Net Cash Provided by Operating Activities	$	42,258		$	41,777		$	76,434		$	82,957
Interest expense	1,124			381			2,162			800
Loss on asset sales	3,241			10,083			3,914			10,083
Other, including changes in working capital	(6,464		)	(11,938		)	(1,446		)	(10,849		)
Adjusted EBITDA	40,159			40,303			81,064			82,991
Less:
Net income attributable to noncontrolling interest	761			1,251			3,934			13,755
Depreciation expense attributable to noncontrolling interest	1,833			2,409			3,663			4,694
Other expenses attributable to noncontrolling interest	112			127			194			316
Loss on asset sales attributable to noncontrolling interest	3,079			9,579			3,718			9,579
Adjusted EBITDA attributable to General and Limited Partner ownership interest in CONE Midstream Partners LP	$	34,374		$	26,937		$	69,555		$	54,647
Less: cash interest paid, net	1,079			254			2,079			484
Less: maintenance capital expenditures, net of reimbursements	3,715			3,112			7,596			5,951
Distributable Cash Flow	$	29,580		$	23,571		$	59,880		$	48,212

Distributable cash flow is a non-GAAP measure that is net to the Partnership. The $6.0 million and $11.7 million increases in the current three month and six month periods, respectively, compared to the 2016 periods were primarily attributable to the Anchor Systems Acquisition consummated in the fourth quarter of 2016.

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Liquidity and Capital Resources

Liquidity and Financing Arrangements

We satisfy our working capital requirements, fund capital expenditures and acquisitions and make cash distributions with cash generated from operations and borrowings under our revolving credit facility. If necessary, we may issue additional equity or debt securities to satisfy future growth. We believe that cash generated from these sources will continue to be sufficient to meet our short-term working capital requirements and long-term capital expenditure requirements and to make quarterly cash distributions.

Revolving Credit Facility

We maintain a $250.0 million revolving credit facility, which is available for working capital, capital expenditures, certain acquisitions, distributions, unit repurchases and other lawful partnership purposes. As of June 30, 2017, we had an outstanding balance on our revolving credit facility of $161.0 million, and based on our compliance with the financial covenants governed by the revolving credit facility, we had $89.0 million, the maximum amount of revolving credit, available for borrowing. We incurred $2.1 million of cash interest expense on the revolving credit facility (not including amortization of revolver fees) during the six months ended June 30, 2017.

For additional information on our revolving credit facility, see Item 1. Consolidated Financial Statements, Note 10–Revolving Credit Facility, which is incorporated herein by reference.

Cash Flows

Net cash provided by or used in operating activities, investing activities and financing activities were as follows for the periods presented:

	Six Months Ended June 30,
(in thousands)	2017			2016			Change
Net cash provided by operating activities	$	76,434		$	82,957		$	(6,523	)
Net cash used in investing activities	$	(9,415	)	$	(33,724	)	$	24,309
Net cash used in financing activities	$	(68,574	)	$	(44,354	)	$	(24,220	)

Net cash provided by operating activities decreased approximately $6.5 million for the six months ended June 30, 2017 compared to the six months ended June 30, 2016. The primary reason for the change is timing of working capital payments, none of which was individually significant.

Net cash used in investing activities decreased $24.3 million during the six months ended June 30, 2017 compared to the prior year period due primarily to $14.0 million we received from the sale of long term assets in the current period as well as a reduction of approximately $10.3 million in capital expenditures.

Net cash used in financing activities increased approximately $24.2 million during the six months ended June 30, 2017 compared to the prior year period. The Sponsors, through their ownership of CONE Gathering, regularly reimburse the Partnership for capital expenditures, initially funded by the Partnership, related to their noncontrolling ownership interests in the Anchor, Growth and Additional Systems, less their noncontrolling interests in the ongoing earnings in the Anchor, Growth and Additional Systems, and sales of any assets in which the Sponsors have ownership interests through their membership in CONE Gathering. The $24.2 million increase in cash used in financing activities during the six months ended June 30, 2017 compared to the prior year period is primarily due to net payments we made to the Sponsors under the above circumstances.

Capital Expenditures

The midstream energy business is capital intensive and requires maintenance of existing gathering systems and other midstream assets and facilities, as well as the acquisition or construction and development of new gathering systems and other midstream assets and facilities. Our partnership agreement requires that we categorize our capital expenditures as either:

• Maintenance capital expenditures, which are cash expenditures (including expenditures for the construction or development of new capital assets or the replacement, improvement or expansion of existing capital assets) made to maintain, over the long term, our operating capacity, operating income or revenue. Examples of maintenance capital expenditures are expenditures to repair, refurbish and replace pipelines, to maintain equipment reliability, integrity and safety and to comply with environmental laws and regulations. In addition, we designate a portion of our capital expenditures to connect new wells to maintain gathering throughput as maintenance capital to the extent such capital expenditures are necessary to maintain, over the long term, our operating capacity, operating income or revenue; or

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• Expansion capital expenditures, which are cash expenditures to construct new midstream infrastructure and those expenditures incurred in order to extend the useful lives of our assets, reduce costs, increase revenues or increase system throughput or capacity from current levels, including well connections that increase existing system throughput. Examples of expansion capital expenditures include the construction, development or acquisition of additional gathering pipelines and compressor stations, in each case to the extent such capital expenditures are expected to expand our operating capacity, operating income or revenue. In the future, if we make acquisitions that increase system throughput or capacity, the associated capital expenditures may also be considered expansion capital expenditures.

Capital Expenditures for the Six Months Ended June 30, 2017

	Anchor		Growth		Additional		TOTAL
Capital Investment
Maintenance capital	$	7,508	$	437	$	1,314	$	9,259
Expansion capital	12,641		384		1,131		14,156
Total Capital Investment	$	20,149	$	821	$	2,445	$	23,415
Capital Investment Net to the Partnership
Maintenance capital	$	7,508	$	22	$	66	$	7,596
Expansion capital	12,641		19		56		12,716
Total Capital Investment Net to the Partnership	$	20,149	$	41	$	122	$	20,312

We anticipate that we will continue to make expansion capital expenditures in the future. Consequently, our ability to develop and maintain sources of funds to meet our capital requirements is critical to our ability to meet our growth objectives. We expect that any significant future expansion capital expenditures will be funded by borrowings under our revolving credit facility and/or the issuance of debt and equity securities.

Insurance Program

We maintain insurance policies with insurers in amounts and with coverage and deductibles that we believe are reasonable and prudent. We cannot, however, assure 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.

Cash Distributions

Under our current cash distribution policy, we intend to pay a minimum quarterly distribution of $0.2125 per unit per quarter, which equates to an aggregate distribution of approximately $13.8 million per quarter, or approximately $55.1 million per year, based on the general partner interest and the number of common and subordinated units outstanding as of June 30, 2017.  However, we do not have a legal or contractual obligation to pay distributions quarterly or on any other basis at our minimum quarterly distribution rate or at any other rate. Under our cash distribution policy, the decision to make a distribution as well as the amount of any distribution is determined by our general partner, taking into consideration the terms of the partnership agreement.

On July 21, 2017, the board of directors of our general partner declared a cash distribution to our unitholders of $0.2922 per common and subordinated unit with respect to the second quarter of 2017. The cash distribution will be paid on August 14, 2017 to unitholders of record as of the close of business on August 4, 2017.

For additional information on our cash distribution policy, see Item 1. Consolidated Financial Statements, Note 2–Significant Accounting Policies–Cash Distributions, which is incorporated herein by reference.

Off-Balance Sheet Arrangements

We do not maintain any off-balance sheet transactions, arrangements, obligations or other relationships with unconsolidated entities or others that are reasonably likely to have a material current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources which are not disclosed in the notes to the unaudited consolidated financial statements of this Quarterly Report on Form 10-Q.

Contractual Obligations

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For a discussion of total debt outstanding under our revolving credit facility, see Item 1. Consolidated Financial Statements, Note 10–Revolving Credit Facility, which is incorporated herein by reference.

Critical Accounting Policies

For a description of the Partnership’s accounting policies and any new accounting accounting policies or updates to existing accounting policies as a result of new accounting pronouncements, see Item 1. Consolidated Financial Statements, Note 2–Significant Accounting Policies–Recent Accounting Pronouncements, which is incorporated herein by reference.  The application of the Partnership’s accounting policies may require management to make judgments and estimates about the amounts reflected in the Consolidated Financial Statements. If applicable, management uses historical experience and all available information to make these estimates and judgments. Different amounts could be reported using different assumptions and estimates.

As of June 30, 2017, the Partnership did not have any accounting policies that we deemed to be critical or that would require significant judgment.

Forward-Looking Statements

This report contains forward-looking statements. Statements that are predictive in nature, that depend upon or refer to future events or conditions or that include the words “believe,” “expect,” “anticipate,” “intend,” “estimate”, “will” and other expressions that are predictions of or indicate future events and trends and that do not relate to historical matters identify forward-looking statements. Our forward-looking statements include statements about our business strategy, our industry, our future profitability, our expected capital expenditures and the impact of such expenditures on our performance, the costs of being a publicly traded partnership, our capital programs and our Sponsors.

A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. 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:

• the effects of changes in market prices of natural gas, NGLs and crude oil on the drilling and development plans of CNX Gas or HG Energy on our dedicated acreage and the volumes of natural gas and condensate that are produced on our dedicated acreage;

• changes in the drilling and development plans of CNX Gas or HG Energy in the Marcellus Shale and Utica Shale;

• the ability of CNX Gas or HG Energy to meet their drilling and development plans in the Marcellus Shale and Utica Shale;

• the release of acreage from dedication by CNX Gas as an initial shipper under our gas gathering agreement;

• transfers of acreage by CNX Gas in the right of first offer area, which are not subject to our right of first offer;

• the outcome, or timing of the outcome, from any outstanding litigation involving CONSOL and Noble Energy;

• non-performance or non-payment by the counterparties to our gathering agreements;

• the demand for natural gas and condensate gathering services;

• changes in general economic conditions;

• competitive conditions in our industry;

• actions taken by third-party operators, gatherers, processors and transporters;

• our ability to successfully implement our business plan;

• our ability to complete internal growth projects on time and on budget;

• the price and availability of debt and equity financing;

• the availability and price of oil and natural gas to the consumer compared to the price of alternative and competing fuels;

• competition from the same and alternative energy sources;

• energy efficiency and technology trends;

• operating hazards and other risks incidental to our midstream services;

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

• interest rates;

• labor relations;

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• defaults by parties to our gathering agreements;

• changes in availability and cost of capital;

• changes in our tax status;

• the effect of existing and future laws and government regulations;

• the effects of future litigation; and

• certain factors discussed elsewhere in this report.

You should not place undue reliance on our forward-looking statements. Although forward-looking statements reflect our good faith beliefs at the time they are made, forward-looking statements involve known and unknown risks, uncertainties and other factors, including the factors described under “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2016 and in Part II. Item 1A. “Risk Factors” of this Quarterly Report on 10-Q, which may cause our actual results, performance or achievements to differ materially from anticipated future results, performance or achievements expressed or implied by such forward-looking statements. We undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events, changed circumstances or otherwise, unless required by law.

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ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

We generate a substantial portion of our revenues pursuant to fee-based gathering agreements with our largest customers CONSOL and, following the Noble Energy Asset Sale, HG Energy based on acreage dedications and do not have minimum volume commitments. We are paid based on the volumes of natural gas and condensate that we gather and handle, rather than the underlying value of the commodity. Consequently, our existing operations and cash flows do not have significant direct exposure to commodity price risk. However, we are indirectly exposed to commodity price risks through CONSOL and HG Energy, who may reduce or shut in production due to depressed commodity prices. Although we intend to enter into similar fee-based gathering agreements with new customers in the future, our efforts to negotiate terms with third parties may not be successful.

In the future, we may acquire or develop additional midstream assets in a manner that increases our exposure to commodity price risk. Such exposure to the volatility of natural gas, NGL and crude oil prices could have a material adverse effect on our business, financial condition, results of operations, cash flows and ability to make cash distributions to our unitholders.

Interest Rate Risk

We maintain a $250.0 million revolving credit facility. Assuming the June 30, 2017 outstanding balance on our revolving credit facility of $161.0 million was outstanding for the entire year, an increase of one percentage point in the interest rates would have resulted in an increase to interest expense of $1.6 million. Accordingly, our results of operations, cash flows and financial condition, all of which affect our ability to make cash distributions to our unitholders, could be materially adversely affected by significant increases in interest rates.

Our revolving credit facility contains other provisions, including circumstances that would result in a change of control, which is defined in the agreement as either of CONSOL or Noble Energy failing to each own and control, directly or indirectly, at least 35% of the capital stock of the general partner. A change of control would constitute a default under our revolving credit facility unless waived or amended. Any such waiver or amendment may, among other things, result in a change to existing covenants and conditions based on current credit market conditions and changes in our credit profile as well as incremental costs to the Partnership.

Credit Risk

We are subject to credit risk due to the concentration of our receivables from two significant customers for gas gathering services.  At June 30, 2017, our receivables were primarily from our Sponsors, CONSOL and Noble Energy, which were subsequently collected in full during July 2017.  We generally do not require our customers to post collateral.  The inability or failure of our significant customers to meet their obligations to us, or their insolvency or liquidation, may adversely affect our financial results.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of management of the Partnership’s general partner, including the general partner’s Principal Executive Officer and Principal Financial Officer, an evaluation of the Partnership’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (Exchange Act)), was conducted as of the end of the period covered by this report. Based upon this evaluation, the Chief Executive Officer and Chief Financial Officer of the Partnership’s general partner have concluded that the Partnership’s disclosure controls and procedures were effective as of the end of the period covered by this report.

Changes in Internal Control over Financial Reporting

There were no changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the second quarter of 2017 that have materially affected, or are reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

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PART II: OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Refer to Part I, Item 1. Consolidated Financial Statements, Note 11–Commitments and Contingencies, which is incorporated herein by reference.

ITEM 1A. RISK FACTORS

Information regarding risk factors is discussed in Item 1A, “Risk Factors” of the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2016 and Quarterly Report on Form 10-Q for the quarter ended March 31, 2017. With the exception of the update below, there have been no material changes from the risk factors previously disclosed by the Partnership.

We cannot currently determine what impact, if any, Noble Energy’s divestiture of its upstream assets in the Marcellus Shale will have on the Partnership.

On June 28, 2017, Noble Energy closed the previously announced transaction divesting its upstream assets in northern West Virginia and southern Pennsylvania to HG Energy II Appalachia, LLC (“HG Energy”), a portfolio company of Quantum Energy Partners, LP (“Quantum”). As part of the transaction, HG Energy succeeded to, and their production on the acreage that is dedicated to the Partnership will continue to be gathered by the Partnership at the fees that are outlined in our gathering agreement with Noble Energy.  We do not yet know HG Energy's drilling plans with respect to the Marcellus acreage, and they are under no obligation to pursue business strategies that are favorable to us.  Additionally, we will be subject to fluctuations in HG Energy's creditworthiness and overall financial condition, which following consummation of the transaction, may subject us to the risk of non-payment or non-performance by HG Energy under our gathering agreement, which could materially adversely affect our business, financial condition, results of operations, cash flows and ability to make cash distributions.

Our ability to operate successfully after the Wheeling Creek Acquisition will be largely dependent upon the successful integration of the key personnel and board members who will join us following consummation of the Wheeling Creek Acquisition.

Our ability to successfully operate after the Wheeling Creek Acquisition will be dependent upon the integration of the key personnel and board members who will join us following consummation of the Wheeling Creek Acquisition. While we cannot presently fully ascertain the future roles of the current members of our management following consummation of the acquisition, we currently anticipate that, effective upon consummation of Wheeling Creek Acquisition, John T. Lewis will resign as the chief executive officer of our general partner and as a member of the board of directors of our general partner and of CONE Gathering. Kenneth M. Fisher will also resign as a member of the board of directors of our general partner and of CONE Gathering, and Kirk A. Moore will resign as the general counsel and secretary of our general partner. The individuals that are appointed to the board and designated as our officers as a result of these resignations may be unfamiliar with our operations and/or master limited partnerships, which could increase the time required to fully integrate them into the Partnership.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Not applicable.

ITEM 3.     DEFAULTS UPON SENIOR SECURITIES

Not applicable.

ITEM 4.     MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5.     OTHER INFORMATION

Not applicable.

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ITEM 6. EXHIBITS

		Incorporated by Reference
Exhibit Number	Exhibit Description	Form	SEC File Number	Exhibit	Filing Date
3.1*	Certificate of Limited Partnership of CONE Midstream Partners LP	S-1	333-198352	3.1	08/25/2014
3.2*	First Amended and Restated Agreement of Limited Partnership of CONE Midstream Partners LP, dated as of September 30, 2014	8-K	001-36635	3.1	10/03/2014
31.1†	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934
31.2†	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934
32.1‡	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350
32.2‡	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350
101.INS†	XBRL Instance Document.
101.SCH†	XBRL Taxonomy Extension Schema Document.
101.CAL†	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF†	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB†	XBRL Taxonomy Extension Labels Linkbase Document.
101.PRE†	XBRL Taxonomy Extension Presentation Linkbase Document.

* Incorporated by reference into this Quarterly Report on Form 10-Q as indicated.

^† Filed herewith.

^‡ Furnished herewith.

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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.

Dated: August 7, 2017

CONE MIDSTREAM PARTNERS LP
By:	CONE MIDSTREAM GP, LLC, its general partner
By:	/S/ JOHN T. LEWIS
	John T. Lewis
	Chief Executive Officer and Director (Duly Authorized Officer and Principal Executive Officer)
By:	/S/ DAVID M. KHANI
	David M. Khani
	Chief Financial Officer and Director (Duly Authorized Officer and Principal Financial Officer)
By:	/S/ BRIAN R. RICH
	Brian R. Rich
	Chief Accounting Officer (Duly Authorized Officer and Principal Accounting Officer)

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EX-31.1

Exhibit 31.1

CERTIFICATION

I, John T. Lewis, certify that:

1. I have reviewed this quarterly report on Form 10-Q of CONE Midstream Partners LP;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	August 7, 2017
/S/ JOHN T. LEWIS
John T. Lewis
Chief Executive Officer
CONE Midstream GP LLC (the general partner of CONE Midstream Partners LP)
(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION

I, David M. Khani, certify that:

1. I have reviewed this quarterly report on Form 10-Q of CONE Midstream Partners LP;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	August 7, 2017
/S/ DAVID M. KHANI
David M. Khani
Chief Financial Officer
CONE Midstream GP LLC (the general partner of CONE Midstream Partners LP)
(Principal Financial Officer)

EX-32.1

Exhibit 32.1

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, John T. Lewis, Chairman of the Board and Chief Executive Officer (principal executive officer) of CONE Midstream Partners LP (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended June 30, 2017, of the Registrant (the “Report”):

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	August 7, 2017
/S/ JOHN T. LEWIS
John T. Lewis
Chief Executive Officer
CONE Midstream GP LLC (the general partner of CONE Midstream Partners LP)
(Principal Executive Officer)

EX-32.2

Exhibit 32.2

CERTIFICATION

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002,

18 U.S.C. Section 1350

I, David M. Khani, Chief Financial Officer and Director (principal financial officer) of CONE Midstream Partners LP (the “Registrant”), certify that to my knowledge, based upon a review of the Quarterly Report on Form 10-Q for the period ended June 30, 2017, of the Registrant (the “Report”):

(1)The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Registrant.

Date:	August 7, 2017
/S/ DAVID M. KHANI
David M. Khani
Chief Financial Officer
CONE Midstream GP LLC (the general partner of CONE Midstream Partners LP)
(Principal Financial Officer)

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Aug. 07, 2017
Entity Information [Line Items]
Entity Registrant Name	CONE Midstream Partners LP
Entity Central Index Key	0001610418
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q2
Amendment Flag	false
Common Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		34,422,212
Subordinated Units
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding		29,163,121

XML

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenue
Gathering revenue — related party		$ 55,667	$ 58,407	$ 114,625	$ 120,655
Gathering revenue — third party		867	0	867	0
Total Revenue		56,534	58,407	115,492	120,655
Expenses
Operating expense — related party		7,089	7,078	14,717	15,422
Operating expense — third party		5,957	7,879	12,590	16,553
General and administrative expense — related party		2,715	2,213	5,651	3,897
General and administrative expense — third party		981	1,153	2,120	2,147
Loss on asset sales		3,241	10,083	3,914	10,083
Depreciation expense		5,675	5,152	11,346	9,992
Interest expense		1,124	381	2,162	800
Total Expense		26,782	33,939	52,500	58,894
Net Income		29,752	24,468	62,992	61,761
Less: Net income attributable to noncontrolling interest		761	1,251	3,934	13,755
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP		28,991	23,217	59,058	48,006
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP		28,991	23,217	59,058	48,006
Less: General partner interest in net income, including incentive distribution rights		1,305	464	2,434	960
Limited partner interest in net income		$ 27,686	$ 22,753	$ 56,624	$ 47,046
Net income per limited partner unit - Basic (in dollars per unit)		$ 0.44	$ 0.39	$ 0.89	$ 0.81
Net income per limited partner unit - Diluted (in dollars per unit)		$ 0.44	$ 0.39	$ 0.89	$ 0.81
Limited partner units outstanding - Basic (in shares)		63,585	58,343	63,575	58,343
Limited partner units outstanding - Diluted (in shares)		63,644	58,415	63,630	58,397
Cash distributions declared per unit (in dollars per share)	[1]	$ 0.2922	$ 0.2540	$ 0.5743	$ 0.4990

[1] Represents the cash distributions declared during the month following the end of each respective quarterly period. See Note 15.

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CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Current Assets:
Cash	$ 4,866	$ 6,421
Receivables — related party (Note 6)	18,425	22,434
Receivables — third party (Note 6)	5,243	0
Other current assets	1,914	2,181
Total Current Assets	30,448	31,036
Property and Equipment:
Property and equipment (Note 7)	940,208	930,732
Less — accumulated depreciation	62,394	52,172
Property and Equipment, Net	877,814	878,560
Other assets (Note 8)	675	8,961
TOTAL ASSETS	908,937	918,557
Current Liabilities:
Accounts payable	18,880	18,007
Accounts payable — related party (Note 9)	2,728	8,289
Total Current Liabilities	21,608	26,296
Other Liabilities:
Revolving credit facility (Note 10)	161,000	167,000
Total Liabilities	182,608	193,296
Partners' Capital:
General partner interest	(1,451)	(2,311)
Partners' capital attributable to CONE Midstream Partners LP	372,535	350,055
Noncontrolling interest	353,794	375,206
Total Partners' Capital	726,329	725,261
TOTAL LIABILITIES AND PARTNERS' CAPITAL	908,937	918,557
Common Units
Partners' Capital:
Limited partners' capital	430,171	418,352
Subordinated Units
Partners' Capital:
Limited partners' capital	$ (56,185)	$ (65,986)

XML

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - shares	Jun. 30, 2017	Dec. 31, 2016
Common Units
Units issued (in shares)	34,422,212	34,363,371
Units outstanding (in shares)	34,422,212	34,363,371
Subordinated Units
Units issued (in shares)	29,163,121	29,163,121
Units outstanding (in shares)	29,163,121	29,163,121

XML

CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL AND NONCONTROLLING INTEREST (Unaudited) - 6 months ended Jun. 30, 2017 - USD ($) $ in Thousands	Total	Total Capital Attributable to Partners	Total Capital Attributable to Partners Limited Partners Common Units	Total Capital Attributable to Partners Limited Partners Subordinated Units	Total Capital Attributable to Partners General Partner	Noncontrolling Interest
Partners' Capital, beginning balance at Dec. 31, 2016	$ 725,261	$ 350,055	$ 418,352	$ (65,986)	$ (2,311)	$ 375,206
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	62,992	59,058	30,652	25,972	2,434	3,934
Contributions to (distributions from) general partner and noncontrolling interest holders, net	(25,317)	29			29	(25,346)
Quarterly distributions to unitholders	(36,846)	(36,846)	(19,072)	(16,171)	(1,603)
Unit-based compensation	650	650	650
Vested units withheld for unitholder taxes	(411)	(411)	(411)
Partners' Capital, ending balance at Jun. 30, 2017	$ 726,329	$ 372,535	$ 430,171	$ (56,185)	$ (1,451)	$ 353,794

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash Flows from Operating Activities:
Net income	$ 62,992	$ 61,761
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation expense and amortization of debt issuance costs	11,430	10,073
Unit-based compensation	650	355
Loss on asset sales	3,914	10,083
Other	167	151
Changes in assets and liabilities:
Receivables — related party	4,009	12,285
Receivables — third party	(867)	0
Other current and non-current assets	3,574	822
Accounts payable	(3,645)	(12,533)
Accounts payable — related party	(5,790)	(40)
Net Cash Provided by Operating Activities	76,434	82,957
Cash Flows from Investing Activities:
Capital expenditures	(23,415)	(33,724)
Proceeds from sale of assets	14,000	0
Net Cash Used in Investing Activities	(9,415)	(33,724)
Cash Flows from Financing Activities:
Contributions to (distributions from) general partner and noncontrolling interest holders, net	(25,317)	10,823
Quarterly distributions to unitholders	(36,846)	(28,654)
Net payments on revolving credit facility	(6,000)	(26,500)
Vested units withheld for unitholders taxes	(411)	(23)
Net Cash Used In Financing Activities	(68,574)	(44,354)
Net (Decrease) Increase in Cash	(1,555)	4,879
Cash at Beginning of Period	6,421	217
Cash at End of Period	4,866	5,096
Cash paid during the period for:
Interest	$ 2,171	$ 893

XML

DESCRIPTION OF BUSINESS

6 Months Ended

Jun. 30, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

DESCRIPTION OF BUSINESS

DESCRIPTION OF BUSINESS

CONE Midstream Partners LP (the “Partnership") is a master limited partnership formed in May 2014 by CONSOL Energy Inc. (NYSE: CNX) (“CONSOL”) and Noble Energy, Inc. (NYSE: NBL) (“Noble Energy”) primarily to own, operate, develop and acquire natural gas gathering and other midstream energy assets to service each of CONSOL's and Noble Energy's production in the Marcellus Shale in Pennsylvania and West Virginia. Our assets include natural gas gathering pipelines and compression and dehydration facilities, as well as condensate gathering, collection, separation and stabilization facilities. The Partnership's general partner is CONE Midstream GP LLC (our “general partner”), a wholly owned subsidiary of CONE Gathering LLC (“CONE Gathering”). CONE Gathering, a Delaware limited liability company, is a joint venture formed by CONSOL and Noble Energy in September 2011.

Noble Energy Sale of Upstream Assets

On June 28, 2017, Noble Energy closed the previously announced sale of its upstream assets in northern West Virginia and southern Pennsylvania to HG Energy II Appalachia, LLC (“HG Energy”), a portfolio company of Quantum Energy Partners, LP (“Quantum”), effectively making HG Energy the new shipper on the dedicated acreage that was previously owned by Noble Energy (the “Noble Energy Asset Sale”). In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems, from amounts dedicated to us as per the terms of our gathering agreement, which is more fully discussed in Note 4. The Partnership is in the process of confirming the amount of acreage that was released from dedication to us.

Effective June 28, 2017, the Partnership gathers the natural gas and condensate volumes produced by HG Energy on our dedicated acreage under the terms of our gathering agreement with Noble Energy, which was assigned to HG Energy upon consummation of the Noble Energy Asset Sale.

Noble Energy Proposed Sale of Interests in CONE Gathering and the Partnership

On May 18, 2017, Noble Energy announced that it had reached an agreement to divest the holding company which owns its 50% membership interest in CONE Gathering, as well as 7,110,638 common units and 14,581,560 subordinated units in the Partnership (collectively, the “Interests”), to Wheeling Creek Midstream, LLC (“Wheeling Creek”), a portfolio company of Quantum (the “Wheeling Creek Acquisition”). The proposed transaction, which Noble Energy has announced it expects to close in the second half of 2017, is subject to customary closing conditions. CONSOL has advised Noble Energy that CONSOL disagrees with Noble Energy’s ability to sell its interest in CONE Gathering, which wholly owns our general partner, without first offering a preferential right of purchase to CONSOL. Accordingly, CONSOL has filed a lawsuit against Noble Energy seeking to enforce this right. Noble Energy disputes that CONSOL has such a right.

As of August 7, 2017, Noble Energy continues to own the Interests. Accordingly, in this Quarterly Report on Form 10-Q, we may refer to CONSOL and Noble Energy together as our Sponsors.

Description of Business

In order to effectively manage our business we have divided our current midstream assets among three operating segments that we refer to as our “Anchor Systems,” “Growth Systems” and “Additional Systems” based on their relative current cash flows, growth profiles, capital expenditure requirements and the timing of their development.

• Our Anchor Systems include our most developed midstream systems that generate the largest portion of our current cash flows, which includes our three primary midstream systems (the McQuay System, the Majorsville System and the Mamont System) and related assets.

• Our Growth Systems are primarily located in the dry gas regions of our dedicated acreage that are generally in earlier phases of development and require substantial future expansion capital expenditures to materially increase production, which would primarily be funded by CONSOL and Noble Energy in proportion to CONE Gathering's 95% retained ownership interest.

• Our Additional Systems include several gathering systems primarily located in the wet gas regions of our dedicated acreage that we expect will require lower levels of expansion capital investment relative to our Growth Systems. The substantial majority of capital investment on these systems would primarily be funded by CONSOL and Noble Energy in proportion to CONE Gathering's 95% retained ownership interest.

On September 30, 2014, in connection with the closing of the Partnership's initial public offering (“IPO”), CONE Gathering contributed to the Partnership a 75% controlling interest in the Anchor Systems, a 5% controlling interest in the Growth Systems and a 5% controlling interest in the Additional Systems. On November 16, 2016, the Partnership acquired the remaining 25% noncontrolling interest in the Anchor Systems from CONE Gathering (the “Anchor Systems Acquisition”), which was accounted for as a transaction between unitholders under Accounting Standards Codification (“ASC”) 810 - Consolidations. Accordingly, at December 31, 2016 and June 30, 2017, the Partnership owned a 100% controlling limited partner interest in the Anchor Systems and a 5% controlling limited partner interest in each of the Growth and Additional Systems.

In order to maintain operational flexibility, our operations are conducted through, and our operating assets are owned by, our operating subsidiaries. However, neither we nor our operating subsidiaries have any employees. Our general partner has the sole responsibility for providing the personnel necessary to conduct our operations, whether through directly hiring employees or by obtaining the services of others, which may include personnel of our Sponsors as provided through contractual relationships with the Partnership. All of the personnel that conduct our business are employed or contracted by our general partner and its affiliates, including our Sponsors, but we sometimes refer to these individuals as our employees because they provide services directly to us. See Note 4 for details.

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SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation and Use of Estimates

The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and various disclosures. Actual results could differ from those estimates, which are evaluated on an ongoing basis, utilizing historical experience and other methods considered reasonable under the particular circumstances. Although these estimates are based on management’s best available knowledge at the time, changes in facts and circumstances or discovery of new facts or circumstances may result in revised estimates and actual results may differ from these estimates. Effects on the Partnership’s business, financial position and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revision become known. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation of the accompanying consolidated financial statements have been included.

The balance sheet at December 31, 2016 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements.

Principles of Consolidation

The consolidated financial statements include the accounts of the Partnership and all of its controlled subsidiaries, including 100% of each of the Anchor Systems, Growth Systems and Additional Systems. Although the Partnership has less than a 100% economic interest in the Growth and Additional Systems, each are consolidated fully with the results of the Partnership for all periods following the IPO. However, after adjusting for noncontrolling interests, net income attributable to general and limited partner ownership interests in the Partnership reflect only that portion of net income that is attributable to the Partnership's unitholders. As a result of the Anchor Systems Acquisition, net income attributable to general and limited partner ownership interests in the Partnership includes 100% of the results of the Anchor Systems for periods subsequent to November 16, 2016.

Transactions between the Partnership and its Sponsors have been identified in the consolidated financial statements as transactions between related parties and are discussed in Note 4.

Jumpstart Our Business Startups Act (“JOBS Act”)

Under the JOBS Act, for as long as the Partnership remains an “emerging growth company” as defined in the JOBS Act, we may take advantage of certain exemptions from the Securities and Exchange Commission's (“SEC”) reporting requirements that are applicable to other public companies that are not emerging growth companies, including not being required to provide an auditor’s attestation report on management’s assessment of the effectiveness of its system of internal control over financial reporting pursuant to Section 404 of the Sarbanes-Oxley Act, reduced disclosure obligations regarding executive compensation in our periodic reports, and exemptions from the requirements of holding a nonbinding advisory vote on executive compensation and seeking unitholder approval of any golden parachute payments not previously approved. We may take advantage of these reporting exemptions until we are no longer an emerging growth company. We continue to be an emerging growth company at June 30, 2017.

The Partnership will remain an emerging growth company for up to five years from the date of our IPO (through December 31, 2019), although we will lose that status sooner if:

• we have more than $1.0 billion of revenues in a fiscal year;

• the limited partner interests held by non-affiliates have a market value of more than $700 million as of the last business day of our most recently completed second fiscal quarter, which determination shall be made as of the last day of such fiscal year; or

• we issue more than $1.0 billion of non-convertible debt over a three-year period.

The JOBS Act also provides that an emerging growth company can delay adopting new or revised accounting standards until such time as those standards apply to private companies. The Partnership has irrevocably elected to “opt out” of this exemption and, therefore, is and will be subject to the same new or revised accounting standards as other public companies that are not emerging growth companies.

Revenue Recognition

During the quarter ended June 30, 2017, our revenues primarily consisted of fees, which we charge on a per unit basis, for gathering natural gas that was produced by CONSOL and Noble Energy. We recognize revenue when services have been rendered, the prices are fixed or determinable, and collectibility is reasonably assured.

The fees we charged CONSOL and Noble Energy, prior to consummation of the Noble Asset Sale on June 28, 2017, were recorded in gathering revenue — related party in our consolidated statements of operations. Following consummation of the Noble Asset Sale, fees from midstream services we performed for HG Energy, as well as midstream services we performed on behalf of another third party shipper, were recorded in gathering revenue — third party in our consolidated statements of operations.

Cash

Cash includes cash on hand and on deposit at banking institutions.

Receivables

Receivables are recorded at the invoiced amount and do not bear interest. When applicable, we reserve for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. We regularly review collectability and establish or adjust the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.

There were no reserves for uncollectible amounts at June 30, 2017 or December 31, 2016.

Fair Value Measurement

The Financial Accounting Standards Board (the “FASB”) ASC 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 we would receive upon selling an asset or that we would pay to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy is used to prioritize input 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 current assets and liabilities approximate fair values due to their short maturities. The carrying value of our revolving credit facility approximates fair value as the facility bears interest at a variable, market rate that resets periodically.

Property and Equipment

Property and equipment is recorded at cost upon acquisition and is depreciated on a straight-line basis over their estimated useful lives or over the lease terms of the assets. Expenditures which extend the useful lives of existing property and equipment are capitalized. When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as a gain or loss.

We routinely assess whether impairment indicators arise during any given quarter and have processes in place to ensure that we become aware of such indicators. Impairment indicators include, but are not limited to, sustained decreases in commodity prices, a decline in customer well results and lower throughput forecasts, and increases in construction or operating costs. For such long-lived assets, impairment exists when the carrying amount of an asset or group of assets exceeds our estimates of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying amount of the long-lived asset(s) is not recoverable, based on the estimated future undiscounted cash flows, the impairment loss would be measured as the excess of the asset’s carrying amount over its estimated fair value. In the event that impairment indicators exist, we conduct an impairment test.

Fair value represents the estimated price between market participants to sell an asset in the principal or most advantageous market for the asset, based on assumptions a market participant would make. When warranted, management assesses the fair value of long-lived assets using commonly accepted techniques and may use more than one source in making such assessments. Sources used to determine fair value include, but are not limited to, recent third-party comparable sales, internally developed discounted cash flow analyses and analyses from outside advisors. Significant changes, such as the condition of an asset or management’s intent to utilize the asset, generally require management to reassess the cash flows related to long-lived assets. No property and equipment impairments were identified during the periods presented in the accompanying consolidated financial statements.

Environmental Matters

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, and do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. At this time, we are unable to assess the timing and/or effect of potential liabilities related to greenhouse gas emissions or other environmental issues. As of June 30, 2017 and December 31, 2016, we had no material environmental matters that required the recognition of a separate liability or specific disclosure.

Asset Retirement Obligations

Our gathering pipelines and compressor stations have an indeterminate life. If properly maintained, they will operate for an indeterminate period as long as supply and demand for natural gas exists, which we expect for the foreseeable future. Accordingly, any retirement obligations associated with such assets cannot be estimated. A liability for asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life exists and can be estimated. We have not recorded any liabilities for asset retirement obligations at June 30, 2017 or December 31, 2016.

Variable Interest Entities

Each of the Anchor, Growth and Additional Systems (the “Limited Partnerships”) is also a limited partnership and a variable interest entity (“VIE”). These VIEs correspond with the manner in which we report our segment information in Note 13–Segment Information, which also includes information regarding the Partnership's involvement with each of these VIEs and their relative contributions to our financial position, operating results and cash flows.

The Partnership fully consolidates each of the Limited Partnerships through its ownership of CONE Midstream Operating Company LLC (the “Operating Company”). The Operating Company, through its general partner ownership interest in each of the Anchor, Growth and Additional Limited Partnerships, is considered to be the primary beneficiary for accounting purposes and has the power to direct all substantive strategic and day-to-day operational decisions of the Limited Partnerships.

Equity Compensation

Equity compensation expense for all unit-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. We recognize unit-based compensation costs on a straight-line basis over the requisite service period of an award, which is generally the same as the award's vesting term. See Note 14–Long Term Incentive Plan, for further discussion.

Income Taxes

We are treated as a partnership for federal and state income tax purposes, with each partner being separately taxed on its share of the Partnership's taxable income. Accordingly, no provision for federal or state income taxes has been recorded in the Partnership's consolidated financial statements for any period presented in the accompanying consolidated financial statements.

Cash Distributions

Our partnership agreement requires that we distribute all of our available cash within 45 days after the end of each quarter to unitholders of record on the applicable record date. This requirement forms the basis of our cash distribution policy and reflects a basic judgment that our unitholders will be better served by distributing our available cash rather than retaining it because, among other reasons, we believe we will generally finance any expansion capital expenditures from external financing sources. Under our current cash distribution policy, we intend to make a minimum quarterly distribution to the holders of our common units and subordinated units of $0.2125 per unit, or $0.85 per unit on an annualized basis, to the extent we have sufficient available cash after the establishment of cash reserves and the payment of costs and expenses, including the payment of expenses to our general partner. However, other than the requirement in our partnership agreement to distribute all of our available cash each quarter, we have no legal obligation to make quarterly cash distributions in this or any other amount, and the board of directors of our general partner has considerable discretion to determine the amount of our available cash each quarter. In addition, the board of directors of our general partner may change our cash distribution policy at any time, subject to the requirement in our partnership agreement to distribute all of our available cash quarterly.

Generally, our available cash is the sum of (i) all cash on hand at the end of a quarter after the payment of our expenses and the establishment of cash reserves and (ii) if the board of directors of our general partner so determines, all or any portion of additional cash on hand resulting from working capital borrowings made after the end of the quarter.

Incentive Distribution Rights

Incentive distribution rights (“IDRs”) represent the right to receive an increasing percentage, up to a maximum of 48% (which does not include the 2% general partner interest), of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels described in the table below have been achieved. All of the IDRs are currently held by our general partner. Our general partner may transfer the IDRs separately from its general partner interest.

See Note 3–Net Income Per Limited Partner Unit for additional details regarding achievement of target distribution levels.

Percentage Allocations of Available Cash from Operating Surplus

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner, as holder of our IDRs, and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit Target Amount.” The percentage interests shown for our unitholders and our 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 our general partner include its 2% general partner interest and assume that our general partner has contributed any additional capital necessary to maintain its 2% general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.

			Marginal Percentage Interest in Distributions
Distribution Targets	Total Quarterly Distribution Per Unit Target Amount		Unitholders	General Partner (including IDRs)
Minimum Quarterly Distribution		$0.2125	98%	2%
First Target Distribution	Above $0.2125	up to $0.24438	98%	2%
Second Target Distribution	Above $0.24438	up to $0.26563	85%	15%
Third Target Distribution	Above $0.26563	up to $0.31875	75%	25%
Thereafter	Above $0.31875		50%	50%

The Second and Third Target Distributions were reached for the cash flow quarters ended March 31, 2016 and December 31, 2016, respectively, which were paid within 45 days following the ends of these quarters. All quarterly distributions prior to March 31, 2016 were paid in accordance with the First Target Distribution.

Subordinated Units

Our partnership agreement provides that, during the subordination period, the common unitholders will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.2125 per unit, which is defined in our partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. The practical effect of the subordinated units is to increase the likelihood that, during the subordination period, there will be available cash to be distributed on the common units. The subordination period will end, and the subordinated units will convert to common units, on a one-for-one basis, when certain distribution requirements, as defined in the partnership agreement, have been met.

CONSOL and Noble Energy currently own 29,163,121 subordinated units in the aggregate, which represents all of our subordinated units.

Recent Accounting Pronouncements

In May 2017, the FASB issued Accounting Standards Update (“ASU”) 2017-09-Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting. ASU 2017-09 provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The updated guidance is effective for interim and annual periods beginning after December 15, 2017, and early adoption is permitted. We do not believe the updated requirements will materially impact our consolidated financial statements.

In January 2017, the FASB issued ASU 2017-01–Business Combinations (Topic 805): Clarifying the Definition of a Business, which changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities is a business. The updated guidance requires an entity to evaluate if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets; if so, the set of transferred assets is not a business. ASU 2017-01 is effective for annual reporting periods beginning after December 31, 2017 and interim periods therein. The Partnership does not expect the adoption of this guidance to have a material impact on its consolidated financial statements.

In December 2016, the FASB issued ASU 2016-19–Technical Corrections and Improvements, which covers a wide range of Topics in the ASC. The amendments in this ASU represent changes to clarify, correct errors, or make minor improvements to the ASC, making it easier to understand and apply by eliminating inconsistencies and providing clarifications. The amendments generally fall into one of the following categories: amendments related to differences between original guidance and the ASC, guidance clarification and reference corrections, simplification, or minor improvements. Most of the amendments in ASU 2016-19 do not require transition guidance and are effective immediately.

In August 2016, the FASB issued ASU 2016-15–Classification of Certain Cash Receipts and Cash Payments (Topic 230). ASU 2016-15 addresses the existing diversity in practice of how several specific cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230, Statement of Cash Flows. ASU 2016-15 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2017. The Partnership does not expect the adoption of this guidance will have a material impact on its consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02–Leases (Topic 842), which is intended to improve financial reporting about leasing transactions. The ASU will require organizations (“lessees”) that lease assets with terms of more than 12 months to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. Organizations that own the assets leased by lessees (“lessors”) will remain largely unchanged from current GAAP. In addition, the ASU will require disclosures to help investors and other financial statement users better understand the amount, timing and uncertainty of cash flows arising from leases. The effective date of this ASU is for fiscal years beginning after December 31, 2018 and interim periods within that year. We are currently evaluating the impact that this standard will have on our financial statements and financial covenants with lenders; however, we do not believe this standard will materially adversely impact our existing credit agreements.

In May 2014, the FASB issued ASU 2014-09–Revenue from Contracts with Customers (Topic 606), which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. The objective of the amendments in this update is to improve financial reporting by creating common revenue recognition guidance under both U.S. GAAP and International Financial Reporting Standards (“IFRS”). The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services and should disclose sufficient information, both qualitative and quantitative, to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The following updates to Topic 606 were made during 2016:

• In March 2016, the FASB updated Topic 606 by issuing ASU 2016-08–Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies how an entity determines whether it is a principal or an agent for goods or services promised to a customer as well as the nature of the goods or services promised to their customers.

• In April 2016, the FASB issued ASU 2016-10–Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing, which seeks to address implementation issues in the areas of identifying performance obligations and licensing.

• In May 2016, the FASB issued ASU 2016-12–Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients. The update, which was issued in response to feedback received by the FASB-IASB joint revenue recognition transition resource group, seeks to address implementation issues in the areas of collectibility, presentation of sales taxes, noncash consideration, and completed contracts and contract modifications at transition.

After considering the FASB's issuance of a standard that delayed application of Topic 606 by one year, the new standards are effective for annual reporting periods beginning after December 15, 2017, with the option to adopt as early as annual reporting periods beginning after December 15, 2016. Management continues to evaluate the impacts that these standards will have on the Partnership's financial statements; however, the Partnership anticipates using the modified retrospective approach at adoption as it relates to ASU 2014-09.

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NET INCOME PER LIMITED PARTNER UNIT

6 Months Ended

Jun. 30, 2017

Earnings Per Share [Abstract]

NET INCOME PER LIMITED PARTNER UNIT

NET INCOME PER LIMITED PARTNER UNIT

We allocate net income between our general partner and limited partners using the two-class method, under which we allocate net income to our limited partners, our general partner and the holders of our IDRs in accordance with the terms of our partnership agreement. We also allocate any earnings in excess of distributions to our limited partners, our general partner and the holders of the IDRs in accordance with the terms of our partnership agreement. We allocate any distributions in excess of earnings for the period to our general partner and our limited partners based on their respective proportionate ownership interests in us, after taking into account distributions to be paid with respect to the IDRs, as set forth in our partnership agreement.

The Partnership calculates historical earnings per unit under the two-class method and allocates the earnings or losses of a transferred business before the date of a dropdown transaction entirely to the general partner. If applicable, the previously reported earnings per unit of the limited partners would not change as a result of a dropdown transaction.

Diluted net income per limited partner unit reflects the potential dilution that could occur if securities or agreements to issue common units, such as awards under the long-term incentive plan, were exercised, settled or converted into common units.  When it is determined that potential common units resulting from an award subject to performance or market conditions should be included in the diluted net income per limited partner unit calculation, the impact is calculated by applying the treasury stock method. There were 50,905 phantom units that were not included in the calculation for each of the three and six months ended June 30, 2017 because the effect would have been antidilutive. There were also 1,213 and 5,203 phantom units that were excluded for the three and six months ended June 30, 2016, respectively, because the effect would have been antidilutive.

The following table illustrates the Partnership’s calculation of net income per unit for common and subordinated partner units:

	Three Months Ended June 30,				Six Months Ended   June 30,
(in thousands, except per unit information)	2017		2016		2017		2016
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$	28,991	$	23,217	$	59,058	$	48,006
Less: General partner interest in net income, including incentive distribution rights	1,305		464		2,434		960
Limited partner interest in net income	$	27,686	$	22,753	$	56,624	$	47,046
Net income allocable to common units — Basic and Diluted	$	14,988	$	11,380	$	30,652	$	23,530
Net income allocable to subordinated units — Basic and Diluted	12,698		11,373		25,972		23,516
Limited partner interest in net income — Basic and Diluted	$	27,686	$	22,753	$	56,624	$	47,046
Weighted average limited partner units outstanding — Basic
Common units	34,422		29,180		34,412		29,180
Subordinated units	29,163		29,163		29,163		29,163
Total	63,585		58,343		63,575		58,343
Weighted average limited partner units outstanding — Diluted
Common units	34,481		29,252		34,467		29,234
Subordinated units	29,163		29,163		29,163		29,163
Total	63,644		58,415		63,630		58,397
Net income per limited partner unit — Basic
Common units	$	0.44	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81
Net income per limited partner unit — Diluted
Common units	$	0.43	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81

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RELATED PARTY

6 Months Ended

Jun. 30, 2017

Related Party Transactions [Abstract]

RELATED PARTY

RELATED PARTY

In the ordinary course of business, we have transactions with CONSOL (and certain of its subsidiaries) and Noble Energy, our Sponsors during the three and six months ended June 30, 2017 and 2016, which constitute related party transactions.

During the quarter ended June 30, 2017, the Partnership sold property and equipment with a carrying value of $17.4 million to CONSOL for $14.0 million in cash proceeds. The resulting loss of $3.4 million was recorded in loss on asset sales in the accompanying consolidated statement of operations. The assets that were sold were previously within the Additional Systems.

Sponsor-related charges within operating expense and general and administrative expense – related party consisted of the following:

	Three Months Ended   June 30,				Six Months Ended   June 30,
(in thousands)	2017		2016		2017		2016
Operational services — CONSOL	$	2,999	$	3,177	$	6,187	$	7,154
Electrical compression	4,090		3,901		8,530		8,268
Total Operating Expense — Related Party	$	7,089	$	7,078	$	14,717	$	15,422
CONSOL	$	2,582	$	2,042	$	5,346	$	3,569
Noble Energy	133		171		305		328
Total General and Administrative Expense — Related Party	$	2,715	$	2,213	$	5,651	$	3,897

In addition to the aforementioned transactions, throughout the six months ended June 30, 2017 and 2016, the Sponsors, through their ownership of CONE Gathering, also regularly reimbursed the Partnership for capital expenditures, initially funded by the Partnership, in proportion to CONE Gathering's noncontrolling ownership interests in the Anchor, Growth and Additional Systems. We also distributed to the Sponsors amounts related to their noncontrolling ownership interest in the earnings of the Anchor, Growth and Additional Systems as well as proceeds from sales of any assets in which the Sponsors have ownership interests through their membership in CONE Gathering. This activity is recorded in the caption “Contributions from (distributions to) general partner and noncontrolling interest holders, net” in the consolidated statements of partners' capital and noncontrolling interest and of cash flows.

Operational Services Agreement

Concurrent with the closing of the IPO, we entered into an operational services agreement with CONSOL. On December 1, 2016, in connection with the consummation of our Sponsors' Exchange Agreement, pursuant to which CONSOL and Noble Energy separated their Marcellus Shale area of mutual interest into two separate operating areas (the “Exchange Agreement”), the operational services agreement was amended and restated. Under the amended and restated operating agreement, CONSOL continues to provide certain operational services to us in support of our gathering pipelines and dehydration, treating and compressor stations and facilities, including routine and emergency maintenance and repair services, routine operational activities, routine administrative services, construction and related services and such other services as we and CONSOL may mutually agree upon from time to time. CONSOL prepares and submits for our approval a maintenance, operating and capital budget on an annual basis. CONSOL submits actual expenditures for reimbursement on a monthly basis, and we reimburse CONSOL for any direct third-party costs incurred by CONSOL in providing these services.

Omnibus Agreement

Concurrent with the closing of the IPO, we entered into an omnibus agreement with CONSOL, Noble Energy, CONE Gathering and our general partner that addresses the following matters:

• our payment of an annually-determined administrative support fee, which will total $0.9 million for the year ending December 31, 2017, for the provision of certain services by CONSOL and its affiliates;

• our payment of an annually-determined administrative support fee, which will total $0.7 million for the year ending December 31, 2017, for the provision of certain executive services by CONSOL and its affiliates;

• our payment of an annually-determined administrative support fee, which will total $0.3 million for the year ending December 31, 2017, for the provision of certain executive services by Noble Energy and its affiliates;

• our obligation to reimburse our Sponsors for all other direct or allocated costs and expenses incurred by our Sponsors in providing general and administrative services (which reimbursement is in addition to certain expenses of our general partner and its affiliates that are reimbursed under our partnership agreement);

• our right of first offer to acquire (i) CONE Gathering’s retained interests in each of our Anchor Systems, Growth Systems and Additional Systems, (ii) CONE Gathering’s other ancillary midstream assets and (iii) any additional midstream assets that CONE Gathering develops; and

• an indemnity from CONE Gathering for liabilities associated with the use, ownership or operation of our assets, including environmental liabilities, to the extent relating to the period of time prior to the closing of the IPO; and our obligation to indemnify CONE Gathering for events and conditions associated with the use, ownership or operation of our assets that occur after the closing of the IPO, including environmental liabilities.

So long as CONE Gathering controls our general partner, the omnibus agreement will remain in full force and effect. If CONE Gathering ceases to control our general partner, either party may terminate the omnibus agreement, provided that the indemnification obligations will remain in full force and effect in accordance with their terms.

Gathering Agreements

Upon consummation of the Exchange Agreement, we entered into new fixed-fee gathering agreements with each of CNX Gas Company LLC, a wholly owned subsidiary of CONSOL (“CNX Gas”), and Noble Energy that replaced the gathering agreements that had been in place since the IPO. In addition to incorporating changes related to the termination of CONSOL and Noble Energy's upstream joint venture and Joint Development Agreement, the new gathering agreements were designed to provide more clarity on each of CONSOL and Noble Energy's acreage dedications to the Partnership and related releases and to allow each of CONSOL and Noble Energy to independently advance their own development programs. The new gathering agreements were also designed to simplify the decision making process relating to the Partnership's ability to gather third party gas.

Our gathering agreement with Noble Energy was assigned to HG Energy upon consummation of the Noble Energy Asset Sale. The terms of the agreement remain unchanged following the assignment, except as it relates to HG Energy's inability to, without the Partnership's consent, release dedicated acreage in connection with a transfer of such acreage free of the dedication to us, and exercise other initial shipper rights provided under the gathering agreement. HG Energy is currently not a related party of the Partnership; accordingly, the focus of the disclosure below is on current and historical related party transactions, which do not include transactions with HG Energy.

Under the gathering agreements with CNX Gas and Noble Energy(from whom we received related party revenues through June 28, 2017), we receive a fee based on the type and scope of the midstream services we provide, summarized as follows:

• For the services we provide with respect to natural gas from the Marcellus Shale formation that does not require downstream processing, or dry gas, we receive a fee of $0.42 per MMBtu.

• For the services we provide with respect to the natural gas from the Marcellus Shale formation that requires downstream processing, or wet gas, we receive:

•a fee of $0.289 per MMBtu in the Moundsville area (Marshall County, West Virginia);

•a fee of $0.289 per MMBtu in the Pittsburgh International Airport area; and

•a fee of $0.578 per MMBtu for all other areas in the dedication area.

• For the services we provide with respect to natural gas from the Utica Shale formation, we receive a weighted average rate of $0.27 per MMBtu.

• For the condensate services we provide, we receive a fee of $5.25 per barrel (“Bbl”) in the Majorsville area and $2.627 per Bbl in the Moundsville area.

Each of the foregoing fees will escalate by 2.5% on January 1 of each year, beginning on January 1, 2018. Notwithstanding the foregoing, from time to time, CNX Gas may request rate reductions under certain circumstances, which are reviewed by the board of directors of our general partner, with oversight, as our board of directors deems necessary, by our conflicts committee. No rate reduction arrangements are currently active.

We gather, compress, dehydrate and deliver all of CNX Gas' dedicated natural gas in the Marcellus Shale on a first-priority basis and gather, inject, stabilize and store all of of CNX Gas' dedicated condensate on a first-priority basis, with the exception that until December 1, 2018, CNX Gas will receive first-priority service in our Majorsville system with respect to a certain volume of production (revised bi-annually) and any excess production will receive second-priority service.

We receive quarterly updates from CNX Gas on their drilling and development operations, which include detailed descriptions of the drilling plans, production details and well locations for the following 24 months and a three to ten year plan that includes more general development plans. In addition, we regularly meet with CNX Gas to discuss our plans to timely construct the necessary facilities to be able to provide midstream services to them on our dedicated acreage. In the event that we do not perform our obligations under a gathering agreement, CNX Gas will be entitled to certain rights and procedural remedies thereunder, including the temporary and/or permanent release from dedication discussed below and indemnification from us.

In addition to the natural gas and condensate that is produced from the dedicated acreage, CNX Gas may elect to dedicate to us non-Marcellus Shale properties located in the dedication area in which it has an interest. If it elects to dedicate any such property, then it will propose a fee for the associated midstream services we would provide. So long as the proposed fee generates a rate of return consistent with its existing gathering agreement on both incremental capital and operating expense associated with any expenditures necessary to gather gas from such property, any midstream services that we agree to provide will be on a second priority basis; second only to the first priority basis afforded to CNX Gas on its dedicated production. Throughput that we currently gather from Utica Shale wells operated by CNX Gas is also addressed in its gathering agreement with us.

While our gathering agreement with CNX Gas, as an initial shipper under our gas gathering agreement, runs with the land and, subject to the exceptions described therein, is binding upon the transferee of any of our dedicated acreage, the gathering agreement with CNX Gas provides that it may divest 25,000 net acres of its dedicated acreage (plus or minus the net of acreage acquired or divested within the dedicated area since our IPO) free of the dedication to us (the “Acreage Bucket”). The amount of net acreage that may be divested by CNX Gas free of the dedication will be increased by the amount, if any, of the net acreage acquired (or deemed to be acquired) by CNX Gas within the geographic boundaries of the dedication area that will become automatically dedicated to us. For purposes of determining if acreage can be released free and clear of the dedications under our gathering agreement with CNX Gas, the actual net acreage divested or acquired may be adjusted upwards or downwards based on the geographic location of such net acreage, the timing of the respective divestiture or acquisition and certain other conditions set forth in the agreement. During the six month period ended June 30, 2017, CNX Gas completed two land transactions, located primarily in the Additional Systems, that impacted our acreage dedication. These transactions involved both developed and undeveloped acreage. At August 7, 2017, CNX Gas has approximately 15,000 acres in its Acreage Bucket.

The Noble Energy gathering agreement also provided for an Acreage Bucket, as described above. However, this right was unique to Noble Energy, as an initial shipper under its gathering agreement, and was not transferred to HG Energy upon assignment of the gathering agreement. In connection with the Noble Energy Asset Sale, Noble Energy provided notice to the Partnership of its release of approximately 37,000 undeveloped acres, which were primarily within the Growth and Additional Systems and approximated the amount of the Acreage Bucket attributed to Noble Energy at the time of sale. After the Noble Energy Asset Sale, Noble Energy can no longer release acres from dedication.

There are no restrictions under our gathering agreements on the ability of CNX Gas to transfer acreage in the right of first offer (“ROFO”) area, and any such transfer of acreage in the ROFO area will not be subject to our right of first offer.  For additional information on the ROFO area, see Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations–How We Evaluate Our Operations–Throughput Volumes.

Upon completion of its initial term in 2034, each of our gathering agreements will continue in effect from year to year until such time as the agreement is terminated by either us or the other party to such agreement on or before 180 days prior written notice.

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CONCENTRATION OF CREDIT RISK

6 Months Ended

Jun. 30, 2017

Risks and Uncertainties [Abstract]

CONCENTRATION OF CREDIT RISK

CONCENTRATION OF CREDIT RISK

CONSOL and Noble Energy accounted for a significant portion of the Partnership's revenue in 2017 and for all of its revenue in 2016. Revenues attributable to our customers were as follows for the periods presented:

	Three Months Ended June 30,				Six Months Ended June 30,
(in thousands)	2017		2016		2017		2016
CONSOL	$	31,953	$	29,825	$	66,339	$	61,624
Noble Energy	23,714		28,582		48,286		59,031
Other	867		—		867		—
Total Revenue	$	56,534	$	58,407	$	115,492	$	120,655

Effective June 28, 2017, upon consummation of the Noble Asset Sale, revenues attributable to Noble Energy ceased.

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RECEIVABLES

6 Months Ended

Jun. 30, 2017

Receivables [Abstract]

RECEIVABLES

RECEIVABLES

Receivables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Receivables - related party
CONSOL	$	10,177	$	10,956
Noble Energy	7,904		8,268
CONE Gathering	344		3,210
Receivables - related party	$	18,425	$	22,434
Receivables - third party	5,243		—
Receivables	$	23,668	$	22,434

Receivables - third party primarily includes a portion of our pipe stock that we sold during the quarter ended June 30, 2017 that was not collected until July 2017. See Note 8.

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PROPERTY AND EQUIPMENT

6 Months Ended

Jun. 30, 2017

Property, Plant and Equipment [Abstract]

PROPERTY AND EQUIPMENT

PROPERTY AND EQUIPMENT

Property and equipment consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016		Estimated Useful Lives in Years
Land	$	74,935	$	72,878	N/A
Gathering equipment	637,788		643,422		25 — 40
Compression equipment	171,724		169,681		30 — 40
Processing equipment	30,979		30,979		40
Assets under construction	24,782		13,772		N/A
Total Property and Equipment	$	940,208	$	930,732
Less: Accumulated depreciation
Gathering equipment	$	44,955	$	37,275
Compression equipment	12,719		10,590
Processing equipment	4,720		4,307
Total Accumulated Depreciation	$	62,394	$	52,172
Property and Equipment, Net	$	877,814	$	878,560

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OTHER ASSETS

6 Months Ended

Jun. 30, 2017

Other Assets [Abstract]

OTHER ASSETS

OTHER ASSETS

Other assets consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Pipe stock	$	392	$	8,596
Financing fees	204		286
Other	79		79
Total Other Assets	$	675	$	8,961

During the six months ended June 30, 2017, the Partnership sold a significant portion of its pipe stock to an unrelated third party for approximately $0.5 million below its carrying value, which we recorded as a loss from asset sales in the accompanying consolidated statements of operations. Any amounts outstanding from these sales at June 30, 2017 have been included in Receivables in the accompanying consolidated balance sheets. See Note 6.

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ACCOUNTS PAYABLE - RELATED PARTY

6 Months Ended

Jun. 30, 2017

Payables and Accruals [Abstract]

ACCOUNTS PAYABLE - RELATED PARTY

ACCOUNTS PAYABLE —RELATED PARTY

Related party payables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
CONSOL:
Expense reimbursements	$	1,131	$	999
Capital expenditures reimbursements	473		1,148
General and administrative services	1,080		1,964
Operational expenditures reimbursements	—		395
Other reimbursements	—		1,060
Total due to CONSOL	2,684		5,566
Noble Energy:
Capital expenditures reimbursements	—		1,105
General and administrative services	44		53
Operational expenditures reimbursements	—		401
Other reimbursements	—		1,060
Total due to Noble Energy	44		2,619
CONE Gathering LLC:
Capital expenditures reimbursement to CONE Gathering LLC	—		104
Total due to CONE Gathering LLC	—		104
Total Accounts Payable — Related Party	$	2,728	$	8,289

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REVOLVING CREDIT FACILITY

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

REVOLVING CREDIT FACILITY

REVOLVING CREDIT FACILITY

We are party to a credit facility agreement which provides for a $250 million unsecured five year revolving credit facility that matures on September 30, 2019. Our revolving credit facility is available for working capital, capital expenditures, certain acquisitions, distributions, unit repurchases and other lawful partnership purposes. Borrowings under our revolving credit facility bear interest at our option at either:

• the base rate, which is defined as the highest of (i) the federal funds rate plus 0.50%; (ii) JP Morgan’s prime rate; or (iii) the daily LIBOR rate for a one month interest period plus 1.00%; in each case, plus a margin varying from 0.125% to 1.00%, depending on our most recent consolidated total leverage ratio (as defined in the agreement governing our revolving credit facility) or our credit rating; or

• the LIBOR rate plus a margin varying from 1.125% to 2.00%, in each case, depending on our most recent consolidated leverage ratio (as defined in the agreement governing our revolving credit facility) or our credit rating, as the case may be.

Interest on base rate loans is payable quarterly. Interest on LIBOR loans is payable on the last day of each interest period or, in the case of interest periods longer than three months, every three months. The unused portion of our revolving credit facility is subject to a commitment fee ranging from 0.15% to 0.35% per annum depending on our most recent consolidated leverage ratio or our credit rating, as the case may be.

The outstanding balances and LIBOR interest rates in effect (plus applicable margin) on our revolving credit facility are as follows for the dates presented.

	June 30, 2017				December 31, 2016
(in thousands, except percentages)	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
Revolving credit facility	$	161,000	2.75	%	$	167,000	2.26	%

Our revolving credit facility also contains covenants and conditions that, among other things, limit (subject to certain exceptions) our ability to incur or guarantee additional debt, make cash distributions (though there will be an exception for distributions permitted under the partnership agreement, subject to certain customary conditions), incur certain liens or permit them to exist, make certain investments and acquisitions, enter into certain types of transactions with affiliates, merge or consolidate with another company, and transfer, sell or otherwise dispose of assets. In addition, our revolving credit facility contains other provisions, including circumstances that would result in a change of control, which is defined in the agreement as either CONSOL or Noble Energy failing to each own and control, directly or indirectly, at least 35% of the capital stock of our general partner. A change of control would constitute a default under our revolving credit facility unless waived or amended. Any such waiver or amendment may, among other things, result in a change to existing covenants and conditions based on current credit market conditions and changes in our credit profile as well as incremental costs to the Partnership.

We are subject to covenants that require us to maintain certain financial ratios, the most important of which are as follows:

• The ratio of (i) consolidated total funded debt (as defined in the agreement governing our revolving credit facility) as of the last day of each fiscal quarter to (ii) consolidated EBITDA (as defined in the agreement governing our revolving credit facility) for the four consecutive fiscal quarters ending on the last day of such fiscal quarter may not exceed (A) at any time other than during a qualified acquisition period (as defined in the agreement governing our revolving credit facility), 5.0 to 1.0 and (B) during a qualified acquisition period, 5.5 to 1.0. This consolidated leverage ratio is calculated as the total amount outstanding on our credit facility divided by EBITDA Attributable to General and Limited Partner Ownership Interest in the CONE Midstream Partners LP. The Partnership is in compliance with this financial covenant at June 30, 2017.

• The ratio of (i) consolidated EBITDA for the four consecutive fiscal quarters ending on the last day of each fiscal quarter to (ii) consolidated interest expense (as defined in the agreement governing our revolving credit facility) for such four consecutive fiscal quarters may not be less than 3.0 to 1.0. This consolidated interest coverage ratio is calculated as EBITDA Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP divided by total interest charges. The Partnership is in compliance with this financial covenant at June 30, 2017.

Based on our compliance with the financial covenants, the Partnership had $89.0 million, the maximum amount of revolving credit, available for borrowing at June 30, 2017.

As of June 30, 2017, we had outstanding debt issuance costs of $0.4 million, net of accumulated amortization, which were incurred in connection with the issuance of our credit facility. The debt issuance costs are being amortized in interest expense through September 30, 2019, which is the maturity date of the credit facility.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

We may become involved in claims and other legal matters arising in the ordinary course of business. Although claims are inherently unpredictable, we are not aware of any matters that may have a material adverse effect on our business, financial position, results of operations or cash flows.

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LEASES

6 Months Ended

Jun. 30, 2017

Leases, Operating [Abstract]

LEASES

LEASES

We have entered into various non-cancelable operating leases, primarily related to compression facilities. Future minimum lease payments under operating leases as of June 30, 2017 are as follows:

(in thousands)	Minimum Lease Payments
remainder of 2017	$	2,539
2018	2,426
2019	1,068
2020	366
	$	6,399

Rental expense under operating leases was $1.9 million for the three months ended June 30, 2017 and 2016 and $3.8 million and $4.0 million for six months ended June 30, 2017 and 2016, respectively. These expenses are included within operating expense - third party on our consolidated statement of operations.

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SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

SEGMENT INFORMATION

SEGMENT INFORMATION

Operating segments are the revenue-producing components of a company for which separate financial information is produced internally and is subject to evaluation by the chief operating decision maker in deciding how to allocate resources. The Partnership has three operating segments, which are also its reportable segments - the Anchor Systems, Growth Systems and Additional Systems, each of which does business entirely within the United States of America. See Note 1–Description of Business for details.

Segment results for the periods presented were as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
(in thousands)	2017		2016			2017		2016
Gathering Revenue:
Anchor Systems	$	46,799	$	48,855		$	96,338	$	99,145
Growth Systems	2,018		2,708			4,243		5,599
Additional Systems	7,717		6,844			14,911		15,911
Total Gathering Revenue	$	56,534	$	58,407		$	115,492	$	120,655
Net Income (Loss):
Anchor Systems	$	28,950	$	31,418		$	58,850	$	64,169
Growth Systems	506		(9,251		)	453		(8,316		)
Additional Systems	296		2,301			3,689		5,908
Total Net Income	$	29,752	$	24,468		$	62,992	$	61,761
Depreciation Expense:
Anchor Systems	$	3,748	$	3,550		$	7,491	$	6,854
Growth Systems	543		531			1,088		1,060
Additional Systems	1,384		1,071			2,767		2,078
Total Depreciation Expense	$	5,675	$	5,152		$	11,346	$	9,992
Capital Expenditures for Segment Assets:
Anchor Systems	$	9,996	$	7,070		$	20,149	$	22,241
Growth Systems	382		159			821		228
Additional Systems	1,845		2,109			2,445		11,255
Total Capital Expenditures	$	12,223	$	9,338		$	23,415	$	33,724

Segment assets as of the dates presented were as follows:

(in thousands)	June 30, 2017		December 31, 2016
Segment Assets
Anchor Systems	$	582,236	$	571,415
Growth Systems	97,550		98,447
Additional Systems	229,151		248,695
Total Segment Assets	$	908,937	$	918,557

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LONG-TERM INCENTIVE PLAN

6 Months Ended

Jun. 30, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

LONG-TERM INCENTIVE PLAN

LONG-TERM INCENTIVE PLAN

Under the CONE Midstream Partners LP 2014 Long-Term Incentive Plan (our “LTIP”), our general partner may issue long-term equity based awards to directors, officers and employees of the general partner or its affiliates, or to any consultants, affiliates of our general partner or other individuals who perform services on behalf of the Partnership. The Partnership is responsible for the cost of awards granted under the LTIP, which limits the number of units that may be delivered pursuant to vested awards to 5,800,000 common units, subject to proportionate adjustment in the event of unit splits and similar events. Common units subject to awards that are canceled, forfeited, withheld to satisfy tax withholding obligations or otherwise terminated without delivery of the common units will be available for delivery pursuant to other awards.

During the six months ended June 30, 2017, our general partner granted equity-based phantom units under our LTIP. Awards granted to independent directors vest over a period of one year, and awards granted to certain officers and employees of the general partner vest 33% per year over a period of three years. The following table presents phantom unit activity during the six months ended June 30, 2017:

	Number of Units	Weighted Average Grant Date Fair Value
Total awarded and unvested at December 31, 2016	158,117	$	10.57
Granted	67,112	23.86
Vested	(75,734)	10.82
Forfeited	(2,680)	15.04
Total awarded and unvested at June 30, 2017	146,815	$	16.43

The Partnership accounts for phantom units as equity awards and records compensation expense based on the fair value of the awards at their grant date. The Partnership recognized $0.4 million and $0.2 million of compensation expense for the three months ended June 30, 2017 and 2016, respectively and $0.7 million and $0.4 million for six months ended June 30, 2017 and 2016, respectively, which was included in general and administrative expense - related party in the consolidated statements of operations.

At June 30, 2017, the unrecognized compensation related to all outstanding awards was $1.7 million.

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SUBSEQUENT EVENTS

6 Months Ended

Jun. 30, 2017

Subsequent Events [Abstract]

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS

On July 21, 2017, the Board of Directors of CONE Midstream GP LLC, the Partnership's general partner, declared a cash distribution to the Partnership’s unitholders with respect to the second quarter of 2017 of $0.2922 per common and subordinated unit. The cash distribution will be paid on August 14, 2017 to unitholders of record at the close of business on August 4, 2017.

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SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

Basis of Accounting

The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”).

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and various disclosures. Actual results could differ from those estimates, which are evaluated on an ongoing basis, utilizing historical experience and other methods considered reasonable under the particular circumstances. Although these estimates are based on management’s best available knowledge at the time, changes in facts and circumstances or discovery of new facts or circumstances may result in revised estimates and actual results may differ from these estimates. Effects on the Partnership’s business, financial position and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revision become known.

Principles of Consolidation

The consolidated financial statements include the accounts of the Partnership and all of its controlled subsidiaries, including 100% of each of the Anchor Systems, Growth Systems and Additional Systems. Although the Partnership has less than a 100% economic interest in the Growth and Additional Systems, each are consolidated fully with the results of the Partnership for all periods following the IPO. However, after adjusting for noncontrolling interests, net income attributable to general and limited partner ownership interests in the Partnership reflect only that portion of net income that is attributable to the Partnership's unitholders. As a result of the Anchor Systems Acquisition, net income attributable to general and limited partner ownership interests in the Partnership includes 100% of the results of the Anchor Systems for periods subsequent to November 16, 2016.

Transactions between the Partnership and its Sponsors have been identified in the consolidated financial statements as transactions between related parties and are discussed in Note 4.

Revenue Recognition

During the quarter ended June 30, 2017, our revenues primarily consisted of fees, which we charge on a per unit basis, for gathering natural gas that was produced by CONSOL and Noble Energy. We recognize revenue when services have been rendered, the prices are fixed or determinable, and collectibility is reasonably assured.

The fees we charged CONSOL and Noble Energy, prior to consummation of the Noble Asset Sale on June 28, 2017, were recorded in gathering revenue — related party in our consolidated statements of operations. Following consummation of the Noble Asset Sale, fees from midstream services we performed for HG Energy, as well as midstream services we performed on behalf of another third party shipper, were recorded in gathering revenue — third party in our consolidated statements of operations.

Cash

Cash includes cash on hand and on deposit at banking institutions.

Receivables

Receivables are recorded at the invoiced amount and do not bear interest. When applicable, we reserve for specific accounts receivable when it is probable that all or a part of an outstanding balance will not be collected. Collectability is determined based on terms of sale, credit status of customers and various other circumstances. We regularly review collectability and establish or adjust the allowance as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote.

Fair Value Measurement

The Financial Accounting Standards Board (the “FASB”) ASC 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 we would receive upon selling an asset or that we would pay to transfer a liability in an orderly transaction between market participants at the measurement date. A fair value hierarchy is used to prioritize input 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 current assets and liabilities approximate fair values due to their short maturities. The carrying value of our revolving credit facility approximates fair value as the facility bears interest at a variable, market rate that resets periodically.

Property and Equipment

Property and equipment is recorded at cost upon acquisition and is depreciated on a straight-line basis over their estimated useful lives or over the lease terms of the assets. Expenditures which extend the useful lives of existing property and equipment are capitalized. When properties are retired or otherwise disposed, the related cost and accumulated depreciation are removed from the respective accounts and any profit or loss on disposition is recognized as a gain or loss.

We routinely assess whether impairment indicators arise during any given quarter and have processes in place to ensure that we become aware of such indicators. Impairment indicators include, but are not limited to, sustained decreases in commodity prices, a decline in customer well results and lower throughput forecasts, and increases in construction or operating costs. For such long-lived assets, impairment exists when the carrying amount of an asset or group of assets exceeds our estimates of the undiscounted cash flows expected to result from the use and eventual disposition of the asset or group of assets. If the carrying amount of the long-lived asset(s) is not recoverable, based on the estimated future undiscounted cash flows, the impairment loss would be measured as the excess of the asset’s carrying amount over its estimated fair value. In the event that impairment indicators exist, we conduct an impairment test.

Fair value represents the estimated price between market participants to sell an asset in the principal or most advantageous market for the asset, based on assumptions a market participant would make. When warranted, management assesses the fair value of long-lived assets using commonly accepted techniques and may use more than one source in making such assessments. Sources used to determine fair value include, but are not limited to, recent third-party comparable sales, internally developed discounted cash flow analyses and analyses from outside advisors. Significant changes, such as the condition of an asset or management’s intent to utilize the asset, generally require management to reassess the cash flows related to long-lived assets. No property and equipment impairments were identified during the periods presented in the accompanying consolidated financial statements.

Environmental Matters

We are subject to various federal, state and local laws and regulations relating to the protection of the environment. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, and do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. At this time, we are unable to assess the timing and/or effect of potential liabilities related to greenhouse gas emissions or other environmental issues.

Asset Retirement Obligations

Our gathering pipelines and compressor stations have an indeterminate life. If properly maintained, they will operate for an indeterminate period as long as supply and demand for natural gas exists, which we expect for the foreseeable future. Accordingly, any retirement obligations associated with such assets cannot be estimated. A liability for asset retirement obligations will be recorded only if and when a future retirement obligation with a determinable life exists and can be estimated.

Variable Interest Entities

Each of the Anchor, Growth and Additional Systems (the “Limited Partnerships”) is also a limited partnership and a variable interest entity (“VIE”). These VIEs correspond with the manner in which we report our segment information in Note 13–Segment Information, which also includes information regarding the Partnership's involvement with each of these VIEs and their relative contributions to our financial position, operating results and cash flows.

The Partnership fully consolidates each of the Limited Partnerships through its ownership of CONE Midstream Operating Company LLC (the “Operating Company”). The Operating Company, through its general partner ownership interest in each of the Anchor, Growth and Additional Limited Partnerships, is considered to be the primary beneficiary for accounting purposes and has the power to direct all substantive strategic and day-to-day operational decisions of the Limited Partnerships.

Equity Compensation

Equity compensation expense for all unit-based compensation awards is based on the grant date fair value estimated in accordance with the provisions of the Stock Compensation Topic of the FASB Accounting Standards Codification. We recognize unit-based compensation costs on a straight-line basis over the requisite service period of an award, which is generally the same as the award's vesting term.

Income Taxes

We are treated as a partnership for federal and state income tax purposes, with each partner being separately taxed on its share of the Partnership's taxable income. Accordingly, no provision for federal or state income taxes has been recorded in the Partnership's consolidated financial statements for any period presented in the accompanying consolidated financial statements.

Cash Distributions

Our partnership agreement requires that we distribute all of our available cash within 45 days after the end of each quarter to unitholders of record on the applicable record date. This requirement forms the basis of our cash distribution policy and reflects a basic judgment that our unitholders will be better served by distributing our available cash rather than retaining it because, among other reasons, we believe we will generally finance any expansion capital expenditures from external financing sources. Under our current cash distribution policy, we intend to make a minimum quarterly distribution to the holders of our common units and subordinated units of $0.2125 per unit, or $0.85 per unit on an annualized basis, to the extent we have sufficient available cash after the establishment of cash reserves and the payment of costs and expenses, including the payment of expenses to our general partner. However, other than the requirement in our partnership agreement to distribute all of our available cash each quarter, we have no legal obligation to make quarterly cash distributions in this or any other amount, and the board of directors of our general partner has considerable discretion to determine the amount of our available cash each quarter. In addition, the board of directors of our general partner may change our cash distribution policy at any time, subject to the requirement in our partnership agreement to distribute all of our available cash quarterly.

Generally, our available cash is the sum of (i) all cash on hand at the end of a quarter after the payment of our expenses and the establishment of cash reserves and (ii) if the board of directors of our general partner so determines, all or any portion of additional cash on hand resulting from working capital borrowings made after the end of the quarter.

Subordinated Units and Incentive Distribution Rights

Incentive distribution rights (“IDRs”) represent the right to receive an increasing percentage, up to a maximum of 48% (which does not include the 2% general partner interest), of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels described in the table below have been achieved. All of the IDRs are currently held by our general partner. Our general partner may transfer the IDRs separately from its general partner interest.

Our partnership agreement provides that, during the subordination period, the common unitholders will have the right to receive distributions of available cash from operating surplus each quarter in an amount equal to $0.2125 per unit, which is defined in our partnership agreement as the minimum quarterly distribution, plus any arrearages in the payment of the minimum quarterly distribution on the common units from prior quarters, before any distributions of available cash from operating surplus may be made on the subordinated units. The practical effect of the subordinated units is to increase the likelihood that, during the subordination period, there will be available cash to be distributed on the common units. The subordination period will end, and the subordinated units will convert to common units, on a one-for-one basis, when certain distribution requirements, as defined in the partnership agreement, have been met.

Recent Accounting Pronouncements

In May 2017, the FASB issued Accounting Standards Update (“ASU”) 2017-09-Compensation - Stock Compensation (Topic 718): Scope of Modification Accounting. ASU 2017-09 provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The updated guidance is effective for interim and annual periods beginning after December 15, 2017, and early adoption is permitted. We do not believe the updated requirements will materially impact our consolidated financial statements.

In January 2017, the FASB issued ASU 2017-01–Business Combinations (Topic 805): Clarifying the Definition of a Business, which changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities is a business. The updated guidance requires an entity to evaluate if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets; if so, the set of transferred assets is not a business. ASU 2017-01 is effective for annual reporting periods beginning after December 31, 2017 and interim periods therein. The Partnership does not expect the adoption of this guidance to have a material impact on its consolidated financial statements.

In December 2016, the FASB issued ASU 2016-19–Technical Corrections and Improvements, which covers a wide range of Topics in the ASC. The amendments in this ASU represent changes to clarify, correct errors, or make minor improvements to the ASC, making it easier to understand and apply by eliminating inconsistencies and providing clarifications. The amendments generally fall into one of the following categories: amendments related to differences between original guidance and the ASC, guidance clarification and reference corrections, simplification, or minor improvements. Most of the amendments in ASU 2016-19 do not require transition guidance and are effective immediately.

In August 2016, the FASB issued ASU 2016-15–Classification of Certain Cash Receipts and Cash Payments (Topic 230). ASU 2016-15 addresses the existing diversity in practice of how several specific cash receipts and cash payments are presented and classified in the statement of cash flows under Topic 230, Statement of Cash Flows. ASU 2016-15 is effective for annual reporting periods, and interim periods therein, beginning after December 15, 2017. The Partnership does not expect the adoption of this guidance will have a material impact on its consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02–Leases (Topic 842), which is intended to improve financial reporting about leasing transactions. The ASU will require organizations (“lessees”) that lease assets with terms of more than 12 months to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. Organizations that own the assets leased by lessees (“lessors”) will remain largely unchanged from current GAAP. In addition, the ASU will require disclosures to help investors and other financial statement users better understand the amount, timing and uncertainty of cash flows arising from leases. The effective date of this ASU is for fiscal years beginning after December 31, 2018 and interim periods within that year. We are currently evaluating the impact that this standard will have on our financial statements and financial covenants with lenders; however, we do not believe this standard will materially adversely impact our existing credit agreements.

In May 2014, the FASB issued ASU 2014-09–Revenue from Contracts with Customers (Topic 606), which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. The objective of the amendments in this update is to improve financial reporting by creating common revenue recognition guidance under both U.S. GAAP and International Financial Reporting Standards (“IFRS”). The core principle of the guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services and should disclose sufficient information, both qualitative and quantitative, to enable users of financial statements to understand the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. The following updates to Topic 606 were made during 2016:

• In March 2016, the FASB updated Topic 606 by issuing ASU 2016-08–Principal versus Agent Considerations (Reporting Revenue Gross versus Net), which clarifies how an entity determines whether it is a principal or an agent for goods or services promised to a customer as well as the nature of the goods or services promised to their customers.

• In April 2016, the FASB issued ASU 2016-10–Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing, which seeks to address implementation issues in the areas of identifying performance obligations and licensing.

• In May 2016, the FASB issued ASU 2016-12–Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients. The update, which was issued in response to feedback received by the FASB-IASB joint revenue recognition transition resource group, seeks to address implementation issues in the areas of collectibility, presentation of sales taxes, noncash consideration, and completed contracts and contract modifications at transition.

After considering the FASB's issuance of a standard that delayed application of Topic 606 by one year, the new standards are effective for annual reporting periods beginning after December 15, 2017, with the option to adopt as early as annual reporting periods beginning after December 15, 2016. Management continues to evaluate the impacts that these standards will have on the Partnership's financial statements; however, the Partnership anticipates using the modified retrospective approach at adoption as it relates to ASU 2014-09.

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SIGNIFICANT ACCOUNTING POLICIES (Tables)

6 Months Ended

Jun. 30, 2017

Accounting Policies [Abstract]

Schedule of Target Distributions

The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner, as holder of our IDRs, and the unitholders in any available cash from operating surplus we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution Per Unit Target Amount.” The percentage interests shown for our unitholders and our 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 our general partner include its 2% general partner interest and assume that our general partner has contributed any additional capital necessary to maintain its 2% general partner interest, our general partner has not transferred its incentive distribution rights and that there are no arrearages on common units.

			Marginal Percentage Interest in Distributions
Distribution Targets	Total Quarterly Distribution Per Unit Target Amount		Unitholders	General Partner (including IDRs)
Minimum Quarterly Distribution		$0.2125	98%	2%
First Target Distribution	Above $0.2125	up to $0.24438	98%	2%
Second Target Distribution	Above $0.24438	up to $0.26563	85%	15%
Third Target Distribution	Above $0.26563	up to $0.31875	75%	25%
Thereafter	Above $0.31875		50%	50%

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NET INCOME PER LIMITED PARTNER UNIT (Tables)

6 Months Ended

Jun. 30, 2017

Earnings Per Share [Abstract]

Schedule of Net Income (Loss) Per Unit

The following table illustrates the Partnership’s calculation of net income per unit for common and subordinated partner units:

	Three Months Ended June 30,				Six Months Ended   June 30,
(in thousands, except per unit information)	2017		2016		2017		2016
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$	28,991	$	23,217	$	59,058	$	48,006
Less: General partner interest in net income, including incentive distribution rights	1,305		464		2,434		960
Limited partner interest in net income	$	27,686	$	22,753	$	56,624	$	47,046
Net income allocable to common units — Basic and Diluted	$	14,988	$	11,380	$	30,652	$	23,530
Net income allocable to subordinated units — Basic and Diluted	12,698		11,373		25,972		23,516
Limited partner interest in net income — Basic and Diluted	$	27,686	$	22,753	$	56,624	$	47,046
Weighted average limited partner units outstanding — Basic
Common units	34,422		29,180		34,412		29,180
Subordinated units	29,163		29,163		29,163		29,163
Total	63,585		58,343		63,575		58,343
Weighted average limited partner units outstanding — Diluted
Common units	34,481		29,252		34,467		29,234
Subordinated units	29,163		29,163		29,163		29,163
Total	63,644		58,415		63,630		58,397
Net income per limited partner unit — Basic
Common units	$	0.44	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81
Net income per limited partner unit — Diluted
Common units	$	0.43	$	0.39	$	0.89	$	0.81
Subordinated units	0.44		0.39		0.89		0.81
Total	$	0.44	$	0.39	$	0.89	$	0.81

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RELATED PARTY (Tables)

6 Months Ended

Jun. 30, 2017

Related Party Transactions [Abstract]

Schedule of Related Party Transactions

Sponsor-related charges within operating expense and general and administrative expense – related party consisted of the following:

	Three Months Ended   June 30,				Six Months Ended   June 30,
(in thousands)	2017		2016		2017		2016
Operational services — CONSOL	$	2,999	$	3,177	$	6,187	$	7,154
Electrical compression	4,090		3,901		8,530		8,268
Total Operating Expense — Related Party	$	7,089	$	7,078	$	14,717	$	15,422
CONSOL	$	2,582	$	2,042	$	5,346	$	3,569
Noble Energy	133		171		305		328
Total General and Administrative Expense — Related Party	$	2,715	$	2,213	$	5,651	$	3,897

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CONCENTRATION OF CREDIT RISK (Tables)

6 Months Ended

Jun. 30, 2017

Risks and Uncertainties [Abstract]

Schedule of Revenue from Sponsors

Revenues attributable to our customers were as follows for the periods presented:

	Three Months Ended June 30,				Six Months Ended June 30,
(in thousands)	2017		2016		2017		2016
CONSOL	$	31,953	$	29,825	$	66,339	$	61,624
Noble Energy	23,714		28,582		48,286		59,031
Other	867		—		867		—
Total Revenue	$	56,534	$	58,407	$	115,492	$	120,655

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RECEIVABLES (Tables)

6 Months Ended

Jun. 30, 2017

Receivables [Abstract]

Schedule of Receivables

Receivables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Receivables - related party
CONSOL	$	10,177	$	10,956
Noble Energy	7,904		8,268
CONE Gathering	344		3,210
Receivables - related party	$	18,425	$	22,434
Receivables - third party	5,243		—
Receivables	$	23,668	$	22,434

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PROPERTY AND EQUIPMENT (Tables)

6 Months Ended

Jun. 30, 2017

Property, Plant and Equipment [Abstract]

Property and Equipment

Property and equipment consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016		Estimated Useful Lives in Years
Land	$	74,935	$	72,878	N/A
Gathering equipment	637,788		643,422		25 — 40
Compression equipment	171,724		169,681		30 — 40
Processing equipment	30,979		30,979		40
Assets under construction	24,782		13,772		N/A
Total Property and Equipment	$	940,208	$	930,732
Less: Accumulated depreciation
Gathering equipment	$	44,955	$	37,275
Compression equipment	12,719		10,590
Processing equipment	4,720		4,307
Total Accumulated Depreciation	$	62,394	$	52,172
Property and Equipment, Net	$	877,814	$	878,560

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OTHER ASSETS (Tables)

6 Months Ended

Jun. 30, 2017

Other Assets [Abstract]

Schedule of Other Assets

Other assets consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
Pipe stock	$	392	$	8,596
Financing fees	204		286
Other	79		79
Total Other Assets	$	675	$	8,961

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ACCOUNTS PAYABLE - RELATED PARTY (Tables)

6 Months Ended

Jun. 30, 2017

Payables and Accruals [Abstract]

Schedule of Related Party Payables

Related party payables consisted of the following:

(in thousands)	June 30, 2017		December 31, 2016
CONSOL:
Expense reimbursements	$	1,131	$	999
Capital expenditures reimbursements	473		1,148
General and administrative services	1,080		1,964
Operational expenditures reimbursements	—		395
Other reimbursements	—		1,060
Total due to CONSOL	2,684		5,566
Noble Energy:
Capital expenditures reimbursements	—		1,105
General and administrative services	44		53
Operational expenditures reimbursements	—		401
Other reimbursements	—		1,060
Total due to Noble Energy	44		2,619
CONE Gathering LLC:
Capital expenditures reimbursement to CONE Gathering LLC	—		104
Total due to CONE Gathering LLC	—		104
Total Accounts Payable — Related Party	$	2,728	$	8,289

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REVOLVING CREDIT FACILITY (Tables)

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The outstanding balances and LIBOR interest rates in effect (plus applicable margin) on our revolving credit facility are as follows for the dates presented.

	June 30, 2017				December 31, 2016
(in thousands, except percentages)	Amount Outstanding		Interest Rate		Amount Outstanding		Interest Rate
Revolving credit facility	$	161,000	2.75	%	$	167,000	2.26	%

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LEASES (Tables)

6 Months Ended

Jun. 30, 2017

Leases, Operating [Abstract]

Future minimum lease payments

Future minimum lease payments under operating leases as of June 30, 2017 are as follows:

(in thousands)	Minimum Lease Payments
remainder of 2017	$	2,539
2018	2,426
2019	1,068
2020	366
	$	6,399

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SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2017

Segment Reporting [Abstract]

Schedule of Operating Revenues and Income from Operations

Segment results for the periods presented were as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
(in thousands)	2017		2016			2017		2016
Gathering Revenue:
Anchor Systems	$	46,799	$	48,855		$	96,338	$	99,145
Growth Systems	2,018		2,708			4,243		5,599
Additional Systems	7,717		6,844			14,911		15,911
Total Gathering Revenue	$	56,534	$	58,407		$	115,492	$	120,655
Net Income (Loss):
Anchor Systems	$	28,950	$	31,418		$	58,850	$	64,169
Growth Systems	506		(9,251		)	453		(8,316		)
Additional Systems	296		2,301			3,689		5,908
Total Net Income	$	29,752	$	24,468		$	62,992	$	61,761
Depreciation Expense:
Anchor Systems	$	3,748	$	3,550		$	7,491	$	6,854
Growth Systems	543		531			1,088		1,060
Additional Systems	1,384		1,071			2,767		2,078
Total Depreciation Expense	$	5,675	$	5,152		$	11,346	$	9,992
Capital Expenditures for Segment Assets:
Anchor Systems	$	9,996	$	7,070		$	20,149	$	22,241
Growth Systems	382		159			821		228
Additional Systems	1,845		2,109			2,445		11,255
Total Capital Expenditures	$	12,223	$	9,338		$	23,415	$	33,724

Reconciliation of Assets from Segment to Consolidated

Segment assets as of the dates presented were as follows:

(in thousands)	June 30, 2017		December 31, 2016
Segment Assets
Anchor Systems	$	582,236	$	571,415
Growth Systems	97,550		98,447
Additional Systems	229,151		248,695
Total Segment Assets	$	908,937	$	918,557

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LONG-TERM INCENTIVE PLAN (Tables)

6 Months Ended

Jun. 30, 2017

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Schedule of Nonvested Performance-based Units Activity

The following table presents phantom unit activity during the six months ended June 30, 2017:

	Number of Units	Weighted Average Grant Date Fair Value
Total awarded and unvested at December 31, 2016	158,117	$	10.57
Granted	67,112	23.86
Vested	(75,734)	10.82
Forfeited	(2,680)	15.04
Total awarded and unvested at June 30, 2017	146,815	$	16.43

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DESCRIPTION OF BUSINESS (Details) a in Thousands		6 Months Ended
	Jun. 28, 2017 a	Jun. 30, 2017 segment	May 18, 2017 shares	Dec. 31, 2016	Nov. 16, 2016	Sep. 30, 2014
Schedule of Equity Method Investments [Line Items]
Number of operating segments | segment		3
Growth Systems
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percent)						5.00%
Ownership percentage after all transactions		5.00%		5.00%
Growth Systems | CONE Gathering
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent		95.00%
Additional Systems
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percent)						5.00%
Ownership percentage after all transactions		5.00%		5.00%
Additional Systems | CONE Gathering
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent		95.00%
Anchor Systems
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percent)						75.00%
Anchor Systems
Schedule of Equity Method Investments [Line Items]
Limited partner controlling interest acquired, percentage					25.00%
Ownership percentage after all transactions		100.00%		100.00%
Noble Energy | Growth and Additional Systems
Schedule of Equity Method Investments [Line Items]
Acres divested | a	37
CONE Gathering | Noble Energy | Wheeling Creek
Schedule of Equity Method Investments [Line Items]
Membership interest to be sold			50.00%
CONE Gathering | Noble Energy | Common Units | Wheeling Creek
Schedule of Equity Method Investments [Line Items]
Units to be sold (in units)			7,110,638
CONE Gathering | Noble Energy | Subordinated Units | Wheeling Creek
Schedule of Equity Method Investments [Line Items]
Units to be sold (in units)			14,581,560

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SIGNIFICANT ACCOUNTING POLICIES - ADDITIONAL INFORMATION (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Schedule of Target Distributions [Line Items]
Reserves for uncollectible amounts	$ 0		$ 0		$ 0
Property and equipment impairments	0	$ 0	0	$ 0
Asset retirement obligation	0		0		$ 0
Provision for federal or state income taxes	$ 0	$ 0	$ 0	$ 0
Period to distribute available cash (in days)			45 days
Quarterly distribution to limited partner (in dollars per unit)			$ 0.2125
Annual distribution to limited partner (in dollars per unit)			$ 0.85
General partner's ownership interest (as a percent)			2.00%
Maximum
Schedule of Target Distributions [Line Items]
Incentive distribution, rate (as a percent)			48.00%
Subordinated Units
Schedule of Target Distributions [Line Items]
Units outstanding (in shares)	29,163,121		29,163,121		29,163,121

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SIGNIFICANT ACCOUNTING POLICIES - SCHEDULE OF TARGET DISTRIBUTIONS (Details)	6 Months Ended
	Jun. 30, 2017 $ / shares
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.2125
Minimum Quarterly Distribution
Schedule of Target Distributions [Line Items]
Marginal percentage interest in distributions, unitholders (as a percent)	98.00%
Marginal percentage interest in distributions, general partner (as a percent)	2.00%
First Target Distribution
Schedule of Target Distributions [Line Items]
Marginal percentage interest in distributions, unitholders (as a percent)	98.00%
Marginal percentage interest in distributions, general partner (as a percent)	2.00%
First Target Distribution | Minimum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.2125
First Target Distribution | Maximum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.24438
Second Target Distribution
Schedule of Target Distributions [Line Items]
Marginal percentage interest in distributions, unitholders (as a percent)	85.00%
Marginal percentage interest in distributions, general partner (as a percent)	15.00%
Second Target Distribution | Minimum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.24438
Second Target Distribution | Maximum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.26563
Third Target Distribution
Schedule of Target Distributions [Line Items]
Marginal percentage interest in distributions, unitholders (as a percent)	75.00%
Marginal percentage interest in distributions, general partner (as a percent)	25.00%
Third Target Distribution | Minimum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.26563
Third Target Distribution | Maximum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.31875
Thereafter Distributions
Schedule of Target Distributions [Line Items]
Marginal percentage interest in distributions, unitholders (as a percent)	50.00%
Marginal percentage interest in distributions, general partner (as a percent)	50.00%
Thereafter Distributions | Minimum
Schedule of Target Distributions [Line Items]
Quarterly distribution to limited partner (in dollars per unit)	$ 0.31875

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NET INCOME PER LIMITED PARTNER UNIT (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Limited Partners' Capital Account [Line Items]
Antidilutive securities excluded from computation of earnings per share (in units)	50,905	1,213	50,905	5,203
Net Income Attributable to General and Limited Partner Ownership Interest in CONE Midstream Partners LP	$ 28,991	$ 23,217	$ 59,058	$ 48,006
Less: General partner interest in net income, including incentive distribution rights	1,305	464	2,434	960
Limited partner interest in net income	$ 27,686	$ 22,753	$ 56,624	$ 47,046
Weighted average limited partner units outstanding — Basic (in units)	63,585,000	58,343,000	63,575,000	58,343,000
Weighted average limited partner units outstanding — Diluted (in units)	63,644,000	58,415,000	63,630,000	58,397,000
Net income per limited partner unit — Basic (in dollars per unit)	$ 0.44	$ 0.39	$ 0.89	$ 0.81
Net income per limited partner unit - Diluted (in dollars per unit)	$ 0.44	$ 0.39	$ 0.89	$ 0.81
Common Units
Limited Partners' Capital Account [Line Items]
Limited partner interest in net income	$ 14,988	$ 11,380	$ 30,652	$ 23,530
Weighted average limited partner units outstanding — Basic (in units)	34,422,000	29,180,000	34,412,000	29,180,000
Weighted average limited partner units outstanding — Diluted (in units)	34,481,000	29,252,000	34,467,000	29,234,000
Net income per limited partner unit — Basic (in dollars per unit)	$ 0.44	$ 0.39	$ 0.89	$ 0.81
Net income per limited partner unit - Diluted (in dollars per unit)	$ 0.43	$ 0.39	$ 0.89	$ 0.81
Subordinated Units
Limited Partners' Capital Account [Line Items]
Limited partner interest in net income	$ 12,698	$ 11,373	$ 25,972	$ 23,516
Weighted average limited partner units outstanding — Basic (in units)	29,163,000	29,163,000	29,163,000	29,163,000
Weighted average limited partner units outstanding — Diluted (in units)	29,163,000	29,163,000	29,163,000	29,163,000
Net income per limited partner unit — Basic (in dollars per unit)	$ 0.44	$ 0.39	$ 0.89	$ 0.81
Net income per limited partner unit - Diluted (in dollars per unit)	$ 0.44	$ 0.39	$ 0.89	$ 0.81

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RELATED PARTY (Details) $ in Thousands		3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 28, 2017 a	Jun. 30, 2017 USD ($) a $ / bbl $ / MMBTU	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($) a $ / bbl $ / MMBTU	Jun. 30, 2016 USD ($)	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)
Related Party Transaction [Line Items]
Property and equipment, net		$ 877,814		$ 877,814			$ 878,560
Gas Gathering Agreements
Related Party Transaction [Line Items]
Downstream fees receivable (in dollars per MMBtu) | $ / MMBTU		0.578		0.578
Conditional fee increase, percent				2.50%
Operational update period plan (in months)				24 months
Termination period (in days)				180 days
Gas Gathering Agreements | Minimum
Related Party Transaction [Line Items]
Term of Agreement (in years)				3 years
Gas Gathering Agreements | Maximum
Related Party Transaction [Line Items]
Term of Agreement (in years)				10 years
Sponsors may divest up to (in net acres) | a				25,000
Acreage to be released from dedication | a		15,000		15,000
Gas Gathering Agreements | Marcellus Shale Formation
Related Party Transaction [Line Items]
Fees receivable, excluding downstream (in dollars per MMBtu) | $ / MMBTU		0.42		0.42
Gas Gathering Agreements | West Virgina
Related Party Transaction [Line Items]
Downstream fees receivable (in dollars per MMBtu) | $ / MMBTU		0.289		0.289
Condensate fees receivable (in dollars per Bbl) | $ / bbl		2.627		2.627
Gas Gathering Agreements | Pennsylvania
Related Party Transaction [Line Items]
Downstream fees receivable (in dollars per MMBtu) | $ / MMBTU		0.289		0.289
Condensate fees receivable (in dollars per Bbl) | $ / bbl		5.25		5.25
Gas Gathering Agreements | Utica Shale Formation
Related Party Transaction [Line Items]
Downstream fees receivable, weighted average (in dollars per MMBtu) | $ / MMBTU				0.27
Affiliated Entity | CONSOL | Forecast | Administrative Services
Related Party Transaction [Line Items]
General and administrative expenses						$ 900
Affiliated Entity | CONSOL | Forecast | Executive Administrative Services
Related Party Transaction [Line Items]
General and administrative expenses						700
Affiliated Entity | Noble Energy | Forecast | Executive Administrative Services
Related Party Transaction [Line Items]
General and administrative expenses						$ 300
Additional Systems | Affiliated Entity | CONSOL
Related Party Transaction [Line Items]
Property and equipment, net		$ 17,400		$ 17,400
Proceeds from sale of assets		14,000		14,000
Loss on asset sales		3,400		3,400
Operating Expense | Affiliated Entity
Related Party Transaction [Line Items]
Operating expense		7,089	$ 7,078	14,717	$ 15,422
Operating Expense | Affiliated Entity | CONSOL and Noble | Electrically-Powered Compression Reimbursement
Related Party Transaction [Line Items]
Operating expense		4,090	3,901	8,530	8,268
Operating Expense | Affiliated Entity | CONSOL | Shared Service Agreement
Related Party Transaction [Line Items]
Operating expense		2,999	3,177	6,187	7,154
General and administrative services | Affiliated Entity
Related Party Transaction [Line Items]
General and administrative expenses		2,715	2,213	5,651	3,897
General and administrative services | Affiliated Entity | CONSOL | Shared Service Agreement
Related Party Transaction [Line Items]
General and administrative expenses		2,582	2,042	5,346	3,569
General and administrative services | Affiliated Entity | Noble Energy
Related Party Transaction [Line Items]
General and administrative expenses		$ 133	$ 171	$ 305	$ 328
Noble Energy | Growth and Additional Systems
Related Party Transaction [Line Items]
Acres divested | a	37,000

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CONCENTRATION OF CREDIT RISK (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Concentration Risk [Line Items]
Revenue	$ 56,534	$ 58,407	$ 115,492	$ 120,655
Sales Revenue, Net | Customer Concentration Risk
Concentration Risk [Line Items]
Revenue	56,534	58,407	115,492	120,655
Sales Revenue, Net | Customer Concentration Risk | CONSOL
Concentration Risk [Line Items]
Revenue	31,953	29,825	66,339	61,624
Sales Revenue, Net | Customer Concentration Risk | Noble Energy
Concentration Risk [Line Items]
Revenue	23,714	28,582	48,286	59,031
Sales Revenue, Net | Customer Concentration Risk | Other
Concentration Risk [Line Items]
Revenue	$ 867	$ 0	$ 867	$ 0

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RECEIVABLES (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables - related party	$ 18,425	$ 22,434
Receivables - third party	5,243	0
Receivables	23,668	22,434
Affiliated Entity | Gathering Fees | CONSOL
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables - related party	10,177	10,956
Affiliated Entity | Gathering Fees | Noble Energy
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables - related party	7,904	8,268
Affiliated Entity | Other | CONE Gathering
Accounts, Notes, Loans and Financing Receivable [Line Items]
Receivables - related party	$ 344	$ 3,210

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PROPERTY AND EQUIPMENT (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 940,208	$ 930,732
Less — accumulated depreciation	62,394	52,172
Property and Equipment, Net	877,814	878,560
Land
Property, Plant and Equipment [Line Items]
Total Property and Equipment	74,935	72,878
Gathering equipment
Property, Plant and Equipment [Line Items]
Total Property and Equipment	637,788	643,422
Less — accumulated depreciation	$ 44,955	37,275
Gathering equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	25 years
Gathering equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	40 years
Compression equipment
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 171,724	169,681
Less — accumulated depreciation	$ 12,719	10,590
Compression equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life	30 years
Compression equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life	40 years
Processing equipment
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 30,979	30,979
Less — accumulated depreciation	$ 4,720	4,307
Estimated useful life	40 years
Assets under construction
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 24,782	$ 13,772

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OTHER ASSETS (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Other Assets [Abstract]
Pipe stock	$ 392	$ 8,596
Financing fees	204	286
Other	79	79
Total Other Assets	$ 675	$ 8,961

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OTHER ASSETS - NARRATIVE (Details) $ in Millions	6 Months Ended
	Jun. 30, 2017 USD ($)
Other Assets [Abstract]
Loss on sale of other assets - amount below carrying value	$ 0.5

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ACCOUNTS PAYABLE - RELATED PARTY (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	$ 2,728	$ 8,289
Affiliated Entity | CONSOL
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	2,684	5,566
Affiliated Entity | CONSOL | Expense reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	1,131	999
Affiliated Entity | CONSOL | Capital expenditures reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	473	1,148
Affiliated Entity | CONSOL | General and administrative services
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	1,080	1,964
Affiliated Entity | CONSOL | Operational expenditures reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	395
Affiliated Entity | CONSOL | Other reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	1,060
Affiliated Entity | Noble Energy
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	44	2,619
Affiliated Entity | Noble Energy | Capital expenditures reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	1,105
Affiliated Entity | Noble Energy | General and administrative services
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	44	53
Affiliated Entity | Noble Energy | Operational expenditures reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	401
Affiliated Entity | Noble Energy | Other reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	1,060
Affiliated Entity | CONE Gathering
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	0	104
Affiliated Entity | CONE Gathering | Capital expenditures reimbursements
Related Party Transaction [Line Items]
Total Accounts Payable — Related Party	$ 0	$ 104

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REVOLVING CREDIT FACILITY - ADDITIONAL INFORMATION (Details) - Credit Facility		6 Months Ended
	Sep. 30, 2014 USD ($)	Jun. 30, 2017 USD ($)
Debt Instrument [Line Items]
Revolving credit facility	$ 250,000,000
Debt instrument, term	5 years
Debt covenant, consolidated total funded debt to EBITDA ratio measurement period (in years)		1 year
Consolidated total funded debt to EBITDA ratio, outside acquisition period		5.00
Debt covenant, funded debt to EBITDA ratio, acquisition period		5.50
Interest expense ratio		3.00
Remaining borrowing capacity		$ 89,000,000
Unamortized debt issuance expense		$ 400,000
Minimum
Debt Instrument [Line Items]
Commitment fee percentage		0.15%
Maximum
Debt Instrument [Line Items]
Commitment fee percentage		0.35%
Federal Funds Rate
Debt Instrument [Line Items]
Basis spread on variable rate		0.50%
Base Rate, London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate		1.00%
LIBOR plus 1% | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate		0.125%
LIBOR plus 1% | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate		1.00%
LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate		1.125%
LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate		2.00%

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REVOLVING CREDIT FACILITY - SUMMARY OF REVOLVING CREDIT FACILITY (Details) - Credit Facility - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Line of Credit Facility [Line Items]
Line of credit, outstanding amount	$ 161,000	$ 167,000
Stated interest rate	2.75%	2.26%

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LEASES (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Leases, Operating [Abstract]
remainder of 2017	$ 2,539		$ 2,539
2018	2,426		2,426
2019	1,068		1,068
2020	366		366
Total future minimum lease payments	6,399		6,399
Rental expense	$ 1,900	$ 1,900	$ 3,800	$ 4,000

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SEGMENT INFORMATION (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017 USD ($)	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($) segment	Jun. 30, 2016 USD ($)	Dec. 31, 2016 USD ($)
Segment Reporting [Abstract]
Number of operating segments | segment			3
Segment Reporting Information [Line Items]
Gathering Revenue:	$ 56,534	$ 58,407	$ 115,492	$ 120,655
Net Income (Loss):	29,752	24,468	62,992	61,761
Depreciation Expense:	5,675	5,152	11,346	9,992
Capital Expenditures for Segment Assets:	12,223	9,338	23,415	33,724
Segment Assets	908,937		908,937		$ 918,557
Anchor Systems
Segment Reporting Information [Line Items]
Gathering Revenue:	46,799	48,855	96,338	99,145
Net Income (Loss):	28,950	31,418	58,850	64,169
Depreciation Expense:	3,748	3,550	7,491	6,854
Capital Expenditures for Segment Assets:	9,996	7,070	20,149	22,241
Segment Assets	582,236		582,236		571,415
Growth Systems
Segment Reporting Information [Line Items]
Gathering Revenue:	2,018	2,708	4,243	5,599
Net Income (Loss):	506	(9,251)	453	(8,316)
Depreciation Expense:	543	531	1,088	1,060
Capital Expenditures for Segment Assets:	382	159	821	228
Segment Assets	97,550		97,550		98,447
Additional Systems
Segment Reporting Information [Line Items]
Gathering Revenue:	7,717	6,844	14,911	15,911
Net Income (Loss):	296	2,301	3,689	5,908
Depreciation Expense:	1,384	1,071	2,767	2,078
Capital Expenditures for Segment Assets:	1,845	$ 2,109	2,445	$ 11,255
Segment Assets	$ 229,151		$ 229,151		$ 248,695

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LONG-TERM INCENTIVE PLAN (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation costs	$ 1.7		$ 1.7
Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Total awarded and unvested, beginning balance (in shares)			158,117
Granted (in shares)			67,112
Vested (in shares)			(75,734)
Forfeited (in shares)			(2,680)
Total awarded and unvested, ending balance (in shares)	146,815		146,815
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Total awarded and unvested, beginning balance (in shares)			$ 10.57
Granted (in dollars per share)			23.86
Vested (in dollars per share)			10.82
Forfeited (in dollars per share)			15.04
Total awarded and unvested, ending balance (in shares)	$ 16.43		$ 16.43
2014 LTIP | Director
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			1 year
2014 LTIP | Employee
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Annual award vesting percentage			33.00%
2014 LTIP | Officer
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Annual award vesting percentage			33.00%
2014 LTIP | Common Units | Stock Compensation Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of common units authorized (in units)	5,800,000		5,800,000
2014 LTIP | Common Units | Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit based compensation	$ 0.4	$ 0.2	$ 0.7	$ 0.4

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SUBSEQUENT EVENTS (Details) - $ / shares			3 Months Ended		6 Months Ended
		Jul. 21, 2017	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Subsequent Event [Line Items]
Cash distributions declared per unit (in dollars per share)	[1]		$ 0.2922	$ 0.2540	$ 0.5743	$ 0.4990
Subsequent Event
Subsequent Event [Line Items]
Cash distributions declared per unit (in dollars per share)	[1]	$ 0.2922

[1] Represents the cash distributions declared during the month following the end of each respective quarterly period. See Note 15.