CNX Midstream Partners (CNXM) 10-Q 29 Oct 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 29, 2019
Cover page.
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
Document Transition Report	false
Entity File Number	001-36635
Entity Registrant Name	CNX MIDSTREAM PARTNERS LP
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	47-1054194
Entity Address, Address Line One	1000 CONSOL Energy Drive
Entity Address, City or Town	Canonsburg
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	15317-6506
City Area Code	724
Local Phone Number	485-4000
Title of 12(b) Security	Common Units Representing Limited Partner Interests
Trading Symbol	CNXM
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		63,736,622
Entity Central Index Key	0001610418
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Amendment Flag	false

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue
Gathering revenue — related party		$ 55,453	$ 41,022	$ 168,434	$ 116,328
Gathering revenue — third party		18,523	19,946	55,862	69,523
Total Revenue		73,976	60,968	224,296	185,851
Expenses
Operating expense — related party (Note 4)		6,105	5,131	18,167	14,645
Operating expense — third party		5,612	4,870	17,774	20,744
General and administrative expense — related party		3,573	3,060	11,567	10,292
General and administrative expense — third party		1,236	1,771	4,136	6,639
Loss on asset sales and abandonments		0	0	7,229	2,501
Depreciation expense		6,184	5,306	17,694	16,605
Interest expense		7,601	7,255	22,625	16,863
Total Expenses		30,311	27,393	99,192	88,289
Net Income		43,665	33,575	125,104	97,562
Less: Net (loss) income attributable to noncontrolling interest		(298)	(64)	(711)	6,071
Net Income Attributable to General and Limited Partner Ownership Interest in CNX Midstream Partners LP		43,963	33,639	125,815	91,491
Calculation of Limited Partner Interest in Net Income:
Net Income Attributable to General and Limited Partner Ownership Interest in CNX Midstream Partners LP		43,963	33,639	125,815	91,491
Less: General partner interest in net income, including incentive distribution rights		7,103	3,697	18,707	8,752
Limited partner interest in net income		$ 36,860	$ 29,942	$ 107,108	$ 82,739
Earnings per limited partner unit:
Basic (in dollars per unit)		$ 0.58	$ 0.47	$ 1.68	$ 1.30
Diluted (in dollars per unit)		$ 0.58	$ 0.47	$ 1.68	$ 1.30
Weighted average number of limited partner units outstanding (in thousands):
Basic (in shares)		63,735	63,638	63,722	63,633
Diluted (in shares)		63,770	63,709	63,763	63,682
Cash distributions declared per unit (in dollars per share)	[1]	$ 0.4001	$ 0.3479	$ 1.1598	$ 1.0085
[1]	Represents the cash distributions declared during the month following the end of each respective quarterly period. See Note 11.

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current Assets:
Cash	$ 1,735	$ 3,966
Receivables — related party	17,845	17,073
Receivables — third party	6,074	7,028
Other current assets	1,646	2,383
Total Current Assets	27,300	30,450
Property and Equipment (Note 5):
Property and equipment	1,244,472	974,394
Less — accumulated depreciation	100,295	82,619
Property and Equipment — Net	1,144,177	891,775
Other Assets:
Operating lease right-of-use assets (Note 8)	6,281
Other assets	3,508	3,203
Total Other Assets	9,789	3,203
TOTAL ASSETS	1,181,266	925,428
Current Liabilities:
Trade accounts payable	33,414	9,401
Accrued interest payable	1,237	7,761
Accrued liabilities	64,467	26,757
Due to related party (Note 4)	3,788	4,980
Total Current Liabilities	102,906	48,899
Other Liabilities:
Revolving credit facility (Note 6)	246,000	84,000
Long-term debt (Note 7)	393,925	393,215
Long-term operating lease liabilities (Note 8)	40
Total Other Liabilities	639,965	477,215
Total Liabilities	742,871	526,114
Partners’ Capital and Noncontrolling Interest:
Limited partner units (63,735,464 issued and outstanding at September 30, 2019 and 63,639,676 issued and outstanding at December 31, 2018)	357,085	320,543
General partner interest	14,150	10,900
Partners’ capital attributable to CNX Midstream Partners LP	371,235	331,443
Noncontrolling interest	67,160	67,871
Total Partners’ Capital and Noncontrolling Interest	438,395	399,314
TOTAL LIABILITIES AND PARTNERS’ CAPITAL	$ 1,181,266	$ 925,428

CONSOLIDATED BALANCE SHEETS (_2

CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - shares	Sep. 30, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Units issued (in shares)	63,735,464	63,639,676
Units outstanding (in shares)	63,735,464	63,639,676

CONSOLIDATED STATEMENTS OF PART

CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL AND NONCONTROLLING INTEREST (Unaudited) - USD ($) $ in Thousands	Total	Total Capital Attributable to Partners	Total Capital Attributable to PartnersLimited Partners	Total Capital Attributable to PartnersGeneral Partner	Noncontrolling Interest
Partners' Capital, beginning balance at Dec. 31, 2017	$ 751,111	$ 393,755	$ 389,427	$ 4,328	$ 357,356
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	97,562	91,491	82,739	8,752	6,071
Contributions from (distributions to) general partner and noncontrolling interest holders, net	(3,505)	20		20	(3,525)
Quarterly distributions to unitholders	(68,365)	(68,365)	(61,963)	(6,402)
Acquisition of Shirley-Penns System	(265,000)	(153,587)	(153,587)		(111,413)
HG Energy Transaction	(133,080)	46,420	46,420		(179,500)
Noncash contribution of assets held by general partner	3,105	3,105		3,105
Unit-based compensation	1,775	1,775	1,775
Vested units withheld for taxes	(348)	(348)	(348)
Partners' Capital, ending balance at Sep. 30, 2018	383,255	314,266	304,463	9,803	68,989
Partners' Capital, beginning balance at Jun. 30, 2018	373,351	304,298	295,405	8,893	69,053
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	33,575	33,639	29,942	3,697	(64)
Quarterly distributions to unitholders	(24,176)	(24,176)	(21,389)	(2,787)
Unit-based compensation	506	506	506
Vested units withheld for taxes	(1)	(1)	(1)
Partners' Capital, ending balance at Sep. 30, 2018	383,255	314,266	304,463	9,803	68,989
Partners' Capital, beginning balance at Dec. 31, 2018	399,314	331,443	320,543	10,900	67,871
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	125,104	125,815	107,108	18,707	(711)
Contributions from (distributions to) general partner and noncontrolling interest holders, net	31	31		31
Quarterly distributions to unitholders	(86,845)	(86,845)	(71,357)	(15,488)
Unit-based compensation	1,481	1,481	1,481
Vested units withheld for taxes	(690)	(690)	(690)
Partners' Capital, ending balance at Sep. 30, 2019	438,395	371,235	357,085	14,150	67,160
Partners' Capital, beginning balance at Jun. 30, 2019	425,038	357,580	344,530	13,050	67,458
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income (loss)	43,665	43,963	36,860	7,103	(298)
Contributions from (distributions to) general partner and noncontrolling interest holders, net	1	1		1
Quarterly distributions to unitholders	(30,637)	(30,637)	(24,633)	(6,004)
Unit-based compensation	328	328	328
Partners' Capital, ending balance at Sep. 30, 2019	$ 438,395	$ 371,235	$ 357,085	$ 14,150	$ 67,160

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash Flows from Operating Activities:
Net income	$ 125,104	$ 97,562
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation expense and amortization of debt issuance costs	19,107	17,729
Unit-based compensation	1,481	1,775
Loss on asset sales and abandonments	7,229	2,501
Other	49	388
Changes in assets and liabilities:
Due to/from affiliate	(1,622)	124
Receivables — third party	954	1,066
Other current and non-current assets	(5,301)	4
Accounts payable and other accrued liabilities	28,679	10,058
Net Cash Provided by Operating Activities	175,680	131,207
Cash Flows from Investing Activities:
Capital expenditures	(251,156)	(85,828)
Proceeds from sale of assets	0	6,462
Net Cash Used in Investing Activities	(251,156)	(79,366)
Cash Flows from Financing Activities:
Contributions from (distributions to) general partner and noncontrolling interest holders, net	31	(3,505)
Vested units withheld for unitholder taxes	(690)	(348)
Quarterly distributions to unitholders	(86,845)	(68,365)
Net payments on unsecured $250.0 million credit facility	0	(149,500)
Net borrowings on secured $600.0 million credit facility	162,000	44,000
Proceeds from issuance of long-term debt, net of discount	0	394,000
Debt issuance costs	(1,251)	(5,367)
Acquisition of Shirley-Penns System	0	(265,000)
Net Cash Provided by (Used in) Financing Activities	73,245	(54,085)
Net Decrease in Cash	(2,231)	(2,244)
Cash at Beginning of Period	3,966	3,194
Cash at End of Period	1,735	950
Cash paid during the period for:
Interest	31,274	14,652
Noncash investing activities:
Accrued capital expenditures	$ 41,596	$ 29,907

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (Parenthetical) - Credit Facility	Sep. 30, 2019USD ($)
Unsecured Debt
Revolving credit facility	$ 250,000,000
Secured Debt
Revolving credit facility	$ 600,000,000

DESCRIPTION OF BUSINESS

DESCRIPTION OF BUSINESS	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
DESCRIPTION OF BUSINESS	DESCRIPTION OF BUSINESS CNX Midstream Partners LP (the “Partnership”, or “we”, “us”, or “our”) is a growth-oriented master limited partnership focused on the ownership, operation, development and acquisition of natural gas gathering and other midstream energy assets to service our customers’ production in the Marcellus Shale and Utica 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. We are managed by our general partner, CNX Midstream GP LLC (the “general partner”), a wholly owned subsidiary of CNX Gathering LLC (“CNX Gathering”). CNX Gathering is a wholly owned subsidiary of CNX Gas Company LLC (“CNX Gas”), which is a wholly owned subsidiary of CNX Resources Corporation (NYSE: CNX) (“CNX Resources”). Accordingly, CNX Resources is the sole sponsor of the Partnership, and we may refer to CNX Resources as the “Sponsor” throughout this Quarterly Report on Form 10-Q. Description of Business Our midstream assets consist of two operating segments that we refer to as our “Anchor 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, in which the Partnership owns a 100% controlling interest, include our most developed midstream systems that generate the largest portion of our current cash flows, including our five primary midstream systems (the McQuay, Majorsville, Dry Ridge, Mamont and Shirley-Penns Systems), a 20” high-pressure pipeline contributed to us in the CNX Transaction (discussed below) and related assets. • Our Additional Systems, in which the Partnership owns a 5% controlling interest, include several gathering systems throughout our dedicated acreage. Revenues from our Additional Systems are currently derived primarily from the Pittsburgh Airport area, which is within the wet gas region of our dedicated acreage. Currently, the substantial majority of capital investment in these systems would be funded directly by CNX Resources in proportion to CNX Gathering’s 95% retained ownership interest. As a result of the CNX Transaction and HG Energy Transaction (described below), the Partnership distributed its ownership interests in (i) our “Growth Systems,” which were primarily located in the dry gas regions of our dedicated acreage in central West Virginia, and (ii) the Moundsville area assets formerly within the Additional Systems, to CNX Gathering. CNX Gathering subsequently transferred these assets to HG Energy II Appalachia, LLC (“HG Energy”). 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 CNX Resources as provided through contractual relationships with the Partnership. All of the personnel who conduct our business are employed or contracted by our general partner and its affiliates, including our Sponsor, but we sometimes refer to these individuals as our employees because they provide services directly to us. See Note 4–Related Party Transactions for additional information. Transactions with our Sponsor and HG Energy On May 3, 2018, we announced a strategic transaction with our Sponsor, pursuant to which we amended our gas gathering agreement (“GGA”) with CNX Resources to provide for the following (collectively, the “CNX Transaction”): • Dedication to the Partnership of approximately 16,100 additional Utica acres in our Anchor Systems; • Commitment to develop 40 additional wells in the Anchor Systems by 2023, subject to the terms of the GGA; • Contribution to the Anchor Systems of a 20” high pressure pipeline in addition to a one-time payment to us of approximately $2.0 million in cash; and • Distribution of our 5% interest in the Growth Systems and related assets, as well as our 5% interest in the Moundsville midstream assets that were a part of the Additional Systems, to CNX Gathering, which subsequently transferred these assets to HG Energy. On May 3, 2018, we also announced a strategic transaction with HG Energy, pursuant to which we amended our GGA with HG Energy to provide for the following (collectively, the “HG Energy Transaction”): • Release from dedication of approximately 18,000 acres, net to the Partnership, which was comprised of approximately 275,000 acres (or approximately 14,000 acres, net to the Partnership) within the Growth and Additional Systems and approximately 4,200 scattered acres located in the Anchor Systems; • Removal of our obligation to provide gathering services or make capital investments in the Growth Systems or in the Moundsville area of the Additional Systems; and • Commitment by HG Energy to develop 12 additional wells in the Anchor Systems by 2021, subject to the terms of the HG Energy GGA. Following the CNX Transaction and HG Energy Transaction, the aggregate number of Anchor Systems well commitments to the Partnership, five years from the date of the transaction, increased from 140 wells to 192 wells. The Partnership has no remaining interests in the Growth Systems or the Moundsville area assets that were historically included within the Additional Systems. Acquisition of Shirley-Penns System Prior to March 16, 2018, CNX Gathering owned a 95% noncontrolling interest and the Partnership owned the remaining 5% controlling interest in the Additional Systems, which owned the gathering system and related assets commonly referred to as the Shirley-Penns System (the “Shirley-Penns System”). On March 16, 2018, the Partnership acquired the remaining 95% interest in the Shirley-Penns System, pursuant to which the Additional Systems transferred its interest in the Shirley-Penns System on a pro rata basis to CNX Gathering and the Partnership in accordance with each transferee’s respective ownership interest in the Additional Systems. Following such transfer, CNX Gathering sold its aggregate interest in the Shirley-Penns System to the Partnership for $265.0 million , and it now resides in the Anchor Systems (the “Shirley-Penns Acquisition”). The Partnership funded the Shirley-Penns Acquisition with a portion of the proceeds from the issuance of 6.5% senior notes due 2026 (the “Senior Notes”). See Note 7–Long-Term Debt for additional information. Following the Shirley-Penns Acquisition, the Partnership owns a 100% controlling interest in the Shirley-Penns System. The Additional Systems continue to include several other gathering systems in which the Partnership owns a 5% controlling interest.

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2019
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 considered necessary for a fair presentation of the accompanying consolidated financial statements have been included. The balance sheet at December 31, 2018 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. For further information, refer to the Consolidated Financial Statements and related notes for the year ended December 31, 2018 included in CNX Midstream Partners LP’s (the “Partnership”, or “we”, “us”, or “our”) Annual Report on Form 10-K as filed with the Securities and Exchange Commission (SEC) on February 7, 2019. 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 in the applicable periods presented within this Quarterly Report on Form 10-Q. Although the Partnership has less than a 100% economic interest in the Additional Systems and, for the period prior to May 3, 2018, had less than a 100% economic interest in the Growth Systems, each has been consolidated fully with the results of the Partnership in the applicable periods. 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. For example, net income attributable to general and limited partner ownership interests in the Partnership includes 100% of the results of the Shirley-Penns Systems for the period subsequent to the closing date of the Shirley-Penns Acquisition. Transactions between the Partnership and CNX Resources have been identified in the consolidated financial statements as transactions between related parties and are disclosed in Note 4–Related Party Transactions. Revenue Recognition On January 1, 2018, the Partnership adopted Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers and all the related amendments (“new revenue standard”) using the modified retrospective method. We did not have a transition adjustment as a result of the adoption of the new revenue standard. Revenues from contracts with customers We record revenue when obligations under the terms of the contracts with our shippers are satisfied; generally, this occurs on a daily basis as we gather natural gas at the wellhead. Revenue is measured as the amount of consideration we expect to receive in exchange for providing the natural gas gathering services. Nature of performance obligations At contract inception, we assess the services promised in our contracts with customers and identify a performance obligation for each promised service that is distinct. To identify the performance obligations, we consider all of the services promised in the contract, regardless of whether they are explicitly stated or are implied by customary business practices. Our revenue is generated from natural gas gathering activities. The gas gathering services are interruptible in nature and include charges for the volume of gas actually gathered and do not guarantee access to the system. Volumetric-based fees relate to actual volumes gathered. In general, the interruptible gathering of each unit one million British Thermal Units (MMBtu) of natural gas represents a separate performance obligation. Payment terms for these contracts require payment within 25 days of the end of the calendar month in which the hydrocarbons are gathered. Transaction price allocated to remaining performance obligations We are required to disclose the aggregate amount of transaction price that is allocated to performance obligations that have not yet been satisfied. However, the guidance provides certain practical expedients that limit this requirement. Substantially all of our revenues are derived from contracts that have terms of greater than one year. Under these contracts, the interruptible gathering of each unit of natural gas represents a separate performance obligation. For revenue associated with the Shirley-Penns System, for which we have remaining contractual performance obligations, the aggregate amount of the transaction price allocated to those remaining performance obligations was $375.6 million at September 30, 2019. See Note 4–Related Party Transactions for a detailed breakout of the minimum revenue by year. The amount of revenue associated with this contract up to the minimum volume commitment (“MVC”) is fixed in nature, and volumes that we may gather above the MVC will be variable in nature. As of September 30, 2019, no future performance obligations exist relative to volumes to be gathered in excess of the MVC as the related volumes have not yet been nominated for gathering. Therefore, we have not disclosed the value of unsatisfied performance obligations for the variable aspect of this agreement, nor have we disclosed the value of other unsatisfied performance obligations that are variable in nature. Prior-period performance obligations We record revenue when obligations under the terms of the contracts with our shippers are satisfied; generally this occurs on a daily basis when we gather gas at the wellhead. In some cases, we are required to estimate the amount of natural gas that we have gathered during an accounting period and record any differences between our estimates and the actual units of natural gas that we gathered in the following month. We have existing internal controls for our revenue estimation process and related accruals; historically, any identified differences between our revenue estimates and actual revenue received have not been significant. For the three and nine months ended September 30, 2019 and 2018, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material. Disaggregation of revenue See Note 9–Segment Information for additional information. Contract balances We invoice customers once our performance obligations have been satisfied, at which point payment becomes unconditional. Accordingly, our contracts with customers do not give rise to contract assets or liabilities under the new revenue standard. We also have no contract assets recognized from the costs to obtain or fulfill a contract with a customer. Classification The fees we charge our affiliates, including our Sponsor, are recorded in gathering revenue — related party in our consolidated statements of operations. Fees from midstream services we perform for third party shippers are 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, such as customer bankruptcies. 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 reserve as necessary using the specific identification method. Account balances are charged off against the reserve after all means of collection have been exhausted and the potential for recovery is considered remote. There were no reserves for uncollectable amounts at September 30, 2019 or December 31, 2018 . Fair Value Measurement The Financial Accounting Standards Board (the “FASB”) Accounting Standards Codification (“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 sheets of our current assets, current liabilities and revolving credit facility approximate fair values due to their short maturities. We estimate the fair value of our long-term debt, which is not actively traded, using an income approach model that utilizes a discount rate based on market rates for other debt with similar remaining time to maturity and credit risk (Level 2). The estimated fair value of our long-term debt was approximately $ 390.8 million on September 30, 2019 . Property and Equipment Property and equipment is recorded at cost upon acquisition and is depreciated on a straight-line basis over the assets’ 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 gain or loss on disposition is recognized. The Partnership evaluates whether long-lived assets have been impaired during any given quarter and has processes in place to ensure that we become aware of such indicators. Impairment indicators may 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. Leases In February 2016, the FASB issued ASU 2016-02–Leases (Topic 842), which increases transparency and comparability among organizations by recognizing right-of-use (“ROU”) lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The ASU maintains a distinction between finance leases and operating leases, which is substantially similar to the classification criteria for distinguishing between capital leases and operating leases in the previous lease guidance. Retaining this distinction allows the recognition, measurement and presentation of expenses and cash flows arising from a lease to remain similar to the previous accounting treatment. A lessee is permitted to make an accounting policy election by class of underlying asset to exclude from balance sheet recognition any lease assets and lease liabilities with a term of 12 months or less, and instead to recognize lease expense on a straight-line basis over the lease term. For both financing and operating leases, the ROU asset and lease liability is initially measured at the present value of the lease payments in the consolidated balance sheet. In July 2018, the FASB issued ASU 2018-11 which provides entities with the option to initially apply the new lease standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption, if necessary. As discussed in Note 8, we adopted ASU 2016-02–Leases (Topic 842) effective January 1, 2019 utilizing the transition option provided by ASU 2018-11. We determine if an arrangement is a lease at inception. Operating leases are included in operating lease ROU assets, accrued liabilities, and long-term operating lease liabilities on our consolidated balance sheets. Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at the commencement date. As most of our leases do not provide an implicit rate, we use our incremental borrowing rate based on the information available at the commencement date of the lease in determining the present value of future payments. The operating lease ROU asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term. 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 September 30, 2019 and December 31, 2018 , 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. We are under no legal or contractual obligation to restore or dismantle our gathering system upon abandonment. Therefore, we have not recorded any liabilities for asset retirement obligations at September 30, 2019 or December 31, 2018 . Variable Interest Entities Each of the Anchor and Additional Systems, and our former Growth Systems, is a limited partnership (the “ Limited Partnerships”) and a variable interest entity ( “ VIE”). These VIEs correspond with the manner in which we report our segment information in Note 9–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 CNX Midstream Operating Company LLC (the “ Operating Company”). The Operating Company, through its general partner ownership interest in each of the Limited Partnerships during the period in which any ownership interest exists, 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. 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. 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 ASC 718–Compensation–Stock Compensation. 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 10–Long-Term Incentive Plan for further discussion. Net Income Per Limited Partner Unit and General Partner Interest 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 incentive distribution rights (“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 24,460 and 33,178 phantom units that were not included in the calculation for the three and nine months ended September 30, 2019 , respectively, because the effect would have been antidilutive. There were also 2,865 and 29,356 phantom units that were not included in the calculation for the three and nine months ended September 30, 2018 , respectively, because the effect would have been antidilutive. Recent Accounting Pronouncements In May 2019, the FASB issued ASU 2019-05 - Financial Instruments - Credit Losses (Topic 326), which provides optional targeted transition relief to entities adopting ASU 2016-13. ASU 2016-13 replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses will be based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. ASU 2019-05 provides the option to irrevocably elect the fair value option for certain financial assets previously measured at amortized cost basis. For those entities, the targeted transition relief will increase comparability of financial statement information by providing an option to align measurement methodologies for similar financial assets. The amendments in this ASU will be applied using the modified-retrospective approach and, for public entities, are effective for fiscal years beginning after December 15, 2019 and interim periods within those annual periods. Early adoption is permitted. The adoption of this guidance is not expected to have a material impact on the Partnership's financial statements.

CASH DISTRIBUTIONS

CASH DISTRIBUTIONS	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
CASH DISTRIBUTIONS	CASH DISTRIBUTIONS Our partnership agreement requires that we distribute all of our Available Cash from Operating Surplus, as those terms are defined in the partnership agreement, within 45 days after the end of each quarter to unitholders of record on the applicable record date, in accordance with the terms below. Allocations of Available Cash from Operating Surplus and Incentive Distribution Rights 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.” 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, which may transfer its IDRs separately from its general partner interest. The information set forth below for our general partner includes its 2% general partner interest and assumes that our general partner has contributed any additional capital necessary to maintain its 2% general partner interest, our general partner has not transferred its IDRs and there are no arrearages on common units. In addition, the information below for common unitholders is also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. Marginal Percentage Interest in Distributions Distribution Targets Total Quarterly Distribution Per Unit Target Amount Common 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% Beginning with the distribution that was approved by the Board of Directors of the Partnership’s general partner (the “Board of Directors ”) for the earnings period ended March 31, 2018, each quarterly distribution thereafter has been in excess of the maximum Third Target Distribution, or $0.31875 per common unit. Cash Distributions The Board of Directors declared the following cash distributions to the Partnership’s common unitholders and to the general partner for the periods presented: (in thousands, except per unit information) Quarters Ended Quarterly Distribution Per Unit Total Cash Distribution Date of Distribution March 31, 2018 $ 0.3245 $ 22,700 May 15, 2018 June 30, 2018 $ 0.3361 $ 24,176 August 14, 2018 September 30, 2018 $ 0.3479 $ 25,678 November 13, 2018 December 31, 2018 $ 0.3603 $ 27,268 February 13, 2019 March 31, 2019 $ 0.3732 $ 28,940 May 14, 2019 June 30, 2019 $ 0.3865 $ 30,637 August 14, 2019 See Note 11–Subsequent Events for information regarding the distribution that was approved by the Board of Directors with respect to the quarter ended September 30, 2019 .

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	RELATED PARTY TRANSACTIONS In the ordinary course of business, we engage in related party transactions with CNX Resources (and certain of its subsidiaries) and CNX Gathering, which include the fees we charge and revenues we receive under a fixed fee gathering agreement (including fees associated with electrically-powered compression that CNX Resources reimburses to us) and our reimbursement of certain expenses to CNX Resources under several agreements, discussed below. In addition, we may waive or modify certain terms under these arrangements in the ordinary course of business, including the provisions of the fixed fee gathering agreement, when we determine it is in the best interests of the Partnership to do so. Any such transactions are reviewed by the Board of Directors, as deemed necessary, with oversight by our conflicts committee. During the nine months ended September 30, 2018, the Partnership closed on the Shirley-Penns Acquisition for $265.0 million in cash consideration. See Note 1–Description of Business for additional information. Operating expense – related party consisted of the following: Three Months Ended Nine Months Ended (in thousands) 2019 2018 2019 2018 Operational services $ 3,850 $ 3,266 $ 11,334 $ 9,358 Electrical compression 2,255 1,865 6,833 5,287 Total Operating Expense — Related Party $ 6,105 $ 5,131 $ 18,167 $ 14,645 Related party payables consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Expense reimbursements $ 1,232 $ 1,143 Capital expenditures reimbursements — 182 General and administrative services 2,556 3,655 Total Accounts Payable — Related Party $ 3,788 $ 4,980 Operational Services Agreement Upon the closing of the initial public offering of our common units (our “IPO”), we entered into an operational services agreement with CNX Resources, which was amended and restated on December 1, 2016. Under the agreement, CNX Resources provides 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 CNX Resources may mutually agree upon from time to time. CNX Resources prepares and submits for our approval a maintenance, operating and capital budget on an annual basis. CNX Resources submits actual expenditures for reimbursement on a monthly basis, and we reimburse CNX Resources for any direct third-party costs incurred by CNX Resources in providing these services. Omnibus Agreement We are party to an omnibus agreement with CNX Resources, CNX Gathering and our general partner that addresses the following matters: • our payment of an annually-determined administrative support fee (approximately $7.9 million for the year ending December 31, 2019 and $1.9 million for the year ended December 31, 2018) for the provision of certain services by CNX Resources and its affiliates, including executive costs. Such costs may not necessarily reflect the actual expenses that the Partnership would incur on a stand-alone basis, and we are unable to estimate what those expenses would be on a stand-alone basis; • our obligation to reimburse CNX Resources for all other direct or allocated costs and expenses incurred by CNX Resources 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) CNX Gathering’s retained interests in our Additional Systems, (ii) CNX Gathering’s other ancillary midstream assets and (iii) any additional midstream assets that CNX Gathering develops; and • our obligation to indemnify CNX 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. The omnibus agreement will remain in full force and effect throughout the period in which CNX Gathering controls our general partner. If CNX 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 On January 3, 2018, we entered into the Second Amended and Restated GGA with CNX Gas, which is a 20 -year, fixed-fee gathering agreement. Under the Second Amended and Restated GGA, we continue to 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 CNX Gas’ dedicated condensate on a first-priority basis. Under this agreement, during the year ending December 31, 2019, we will 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 will receive a fee of $0.442 per MMBtu. • For the services we provide with respect to natural gas from the Marcellus Shale formation that requires downstream processing, or wet gas, we will receive: ◦ a fee of $0.304 per MMBtu in the Pittsburgh International Airport area; and ◦ a fee of $0.607 per MMBtu for all other areas in the dedication area. • Our fees for condensate services will be $5.52 per Bbl in the Majorsville area and in the Shirley-Penns area. Each of the foregoing fees escalates by 2.5% on January 1 each year through the end of the initial term. Commencing on January 1, 2035, and as of January 1 thereafter, each of the applicable fees will be adjusted pursuant to the percentage change in CPI-U, but such fees will never escalate or decrease by more than 3% per year. The Second Amended and Restated GGA also dedicated an additional 63,000 acres in the Utica Shale in and around the McQuay and Wadestown areas and introduced the following gas gathering and compression rates: • Gas Gathering: ◦ McQuay area Utica - a fee of $0.225 per MMBtu; and ◦ Wadestown Marcellus and Utica - a fee of $0.35 per MMBtu. • Compression: ◦ For areas not benefitting from system expansion pursuant to the Second Amended and Restated GGA, compression services are included in the base fees; and ◦ In the McQuay and Wadestown areas, for wells turned in line beginning January 1, 2018 and beyond, we will receive additional fees of $0.065 per MMBtu for Tier 1 pressure services (maximum receipt point of pressure of 600 psi) and $0.130 per MMBtu for Tier 2 pressure services (maximum receipt point of pressure of 300 psi). In addition, the Second Amended and Restated GGA committed CNX Gas to drill and complete 140 total wells in the McQuay area within the Anchor Systems, provided that if 125 wells have been drilled and completed in the Marcellus Shale, then the remainder of such planned wells must be drilled in the Utica Shale. To the extent the requisite number of wells are not drilled and completed by CNX Gas in a given period, we will be entitled to a deficiency payment per shortfall well as set forth below: • January 1, 2018 to December 31, 2018 - 30 wells (CNX Gas exceeded this requirement by eight wells) • January 1, 2019 to April 30, 2020 - 40 wells (deficiency payment of $3.5 million per well) • May 1, 2020 to April 30, 2021 - 40 wells (deficiency payment of $2.0 million per well) • May 1, 2021 to April 30, 2022 - 30 wells (deficiency payment of $2.0 million per well) In the event that CNX Gas drills wells and completes a number of wells in excess of the number of wells required to be drilled and completed in such period, (i) the number of excess wells drilled and completed during such period will be applied to the minimum well requirement in the succeeding period or (ii) to the extent CNX Gas was required to make deficiency payments for shortfalls in the preceding period, CNX Gas may elect to cause the Partnership to pay a refund in an amount equal to (x) the number of excess wells drilled and completed during the period, multiplied by (y) the deficiency payment paid per well during the period in which the shortfall occurred. On March 16, 2018, in connection with the Shirley-Penns Acquisition, we entered into the First Amendment to the Second Amended and Restated GGA, which added the MVC on volumes associated with the Shirley-Penns System through December 31, 2031. The MVC commits CNX Gas to pay the Partnership the wet gas fee under the GGA for all natural gas we gather up to a specified amount per day through December 31, 2031. We will recognize minimum revenue on volumes throughout the term of the GGA, as set forth below: (in millions) Minimum Revenue per MVC Remainder of year ending December 31, 2019* $ — Year ending December 31, 2020 31.0 Year ending December 31, 2021 40.7 Year ending December 31, 2022 47.7 Year ending December 31, 2023 42.8 Remainder of term 213.4 Total minimum revenue to be recognized pursuant to Shirley-Penns MVC $ 375.6 *For 2019, the minimum revenue per the MVC has been met. For all natural gas the Partnership gathers in excess of the MVC, the Partnership will receive a fee of $0.3588 per MMBtu in 2019, which escalates by 2.5% on January 1 of each year. Since the Shirley-Penns Acquisition, CNX Gas has exceeded the required MVC each quarter. On May 2, 2018, we completed the CNX Transaction, pursuant to which we entered into the Second Amendment to the Second Amended and Restated GGA, which committed CNX Gas to drill and complete an additional 40 wells in the Majorsville/Mamont area within the Anchor Systems by the end of 2023. To the extent the requisite number of wells are not drilled and completed by CNX Gas in a given period, we will be entitled to a deficiency payment per shortfall well as set forth below: • July 1, 2018 to December 31, 2020 - 15 wells (As of September 30, 2019 , CNX Gas has exceeded the minimum well commitment) • January 1, 2021 to December 31, 2023 - 25 wells (deficiency payment of $2.8 million per well) CNX Gas provides us with quarterly updates on its drilling and development operations, which include detailed descriptions of the drilling plans, production details and well locations for periods that range from up to 24 - 48 months, as well as more general development plans that may extend as far as ten years . In addition, we regularly meet with CNX Gas to discuss our current 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 and indemnification from us. There are no restrictions under our gathering agreements with CNX Gas 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. Upon completion of its 20 -year term in 2037, our gathering agreement with CNX Gas will continue in effect from year to year until such time as the agreement is terminated by either us or CNX Gas on or before 180 days prior written notice.

PROPERTY AND EQUIPMENT

PROPERTY AND EQUIPMENT	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
PROPERTY AND EQUIPMENT	PROPERTY AND EQUIPMENT Property and equipment consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Estimated Useful Lives in Years Land $ 77,846 $ 67,624 N/A Gathering equipment 680,808 605,722 25 — 40 Compression equipment 255,992 199,728 30 — 40 Processing equipment 30,979 30,979 40 Assets under construction 198,847 70,341 N/A Total Property and Equipment $ 1,244,472 $ 974,394 Less: Accumulated depreciation Gathering equipment $ 71,287 $ 58,561 Compression equipment 22,429 18,099 Processing equipment 6,579 5,959 Total Accumulated Depreciation $ 100,295 $ 82,619 Property and Equipment — Net $ 1,144,177 $ 891,775 The Partnership capitalized approximately $1.6 million and $3.7 million of interest related to assets under construction during the three and nine months ended September 30, 2019. No interest was capitalized in the corresponding 2018 period. During the nine months ended September 30, 2019, the Partnership abandoned the construction of a compressor station that was designed to support additional production within certain areas of the Anchor Systems, incurring a loss of $7.2 million .

REVOLVING CREDIT FACILITY

REVOLVING CREDIT FACILITY	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
REVOLVING CREDIT FACILITY	REVOLVING CREDIT FACILITY On March 8, 2018, we entered into a five-year $600.0 million secured revolving credit facility with an accordion feature that allows, subject to certain terms and conditions, the Partnership to increase the available borrowings under the revolving credit facility by up to an additional $250.0 million . The revolving credit facility includes the ability to issue letters of credit up to $100.0 million in the aggregate. The available borrowing capacity is limited by certain financial covenants pertaining to leverage and interest coverage ratios as defined in the revolving credit facility agreement. On April 24, 2019, the Partnership amended its revolving credit facility and extended its maturity to April 2024. Among other things, we received an annual interest rate reduction of 0.25% on borrowings compared to the original agreement. Under the terms of the amended agreement, borrowings under the revolving credit facility will bear interest at our option at either: • the base rate, which is the highest of (i) the federal funds open rate plus 0.50% , (ii) PNC Bank, N.A.’s prime rate, or (iii) the one-month LIBOR rate plus 1.0% , in each case, plus a margin ranging from 0.50% to 1.50% ; or • the LIBOR rate plus a margin ranging from 1.50% to 2.50% . Following the amendment, the revolving credit facility now includes (i) the addition of a restricted payment basket permitting cash repurchases of IDRs subject to a pro forma secured leverage ratio of 3.00 to 1.00, a pro forma total leverage ratio of 4.00 to 1.00 and pro forma availability of 20% of commitments and (ii) a restricted payment basket for the repurchase of limited partner units not to exceed Available Cash (as defined in the partnership agreement) in any quarter of up to $150.0 million per year and up to $200.0 million during the life of the facility. Interest on base rate loans is payable on the first business day of each calendar quarter. 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 0.375% to 0.500% per annum depending on our most recent consolidated leverage ratio. The revolving credit facility contains a number of affirmative and negative covenants that include, among others, covenants that restrict the ability of the Partnership, its subsidiary guarantors and certain of its non-guarantor, non-wholly-owned subsidiaries, except in certain circumstances, to: (i) create, incur, assume or suffer to exist indebtedness; (ii) create or permit to exist liens on their properties; (iii) prepay certain indebtedness unless there is no default or event of default under the revolving credit facility; (iv) make or pay any dividends or distributions in excess of certain amounts; (v) merge with or into another person, liquidate or dissolve; or acquire all or substantially all of the assets of any going concern or going line of business or acquire all or a substantial portion of another person’s assets; (vi) make particular investments and loans; (vii) sell, transfer, convey, assign or dispose of its assets or properties other than in the ordinary course of business and other select instances; (viii) deal with any affiliate except in the ordinary course of business on terms no less favorable to the Partnership than it would otherwise receive in an arm’s length transaction; and (ix) amend in any material manner its certificate of incorporation, bylaws, or other organizational documents without giving prior notice to the lenders and, in some cases, obtaining the consent of the lenders. The agreement also contains customary events of default, including, but not limited to, a cross-default to certain other debt, breaches of representations and warranties, change of control events and breaches of covenants. The obligations under the revolving credit facility agreement are secured by substantially all of assets of the Partnership and its wholly owned subsidiaries. In addition, the Partnership is obligated to maintain at the end of each fiscal quarter: • for as long as at least $150.0 million of the Senior Notes are outstanding (Note 7), a maximum total leverage ratio of no greater than 5.25 to 1.00 (which increases to no greater than 5.50 to 1.00 during qualifying acquisition periods); • if less than $150.0 million of the Senior Notes are outstanding (Note 7), a maximum total leverage ratio of no greater than 4.75 to 1.00 (which increases to no greater than 5.25 to 1.00 during qualifying acquisition periods); • a maximum secured leverage ratio of no greater than 3.50 to 1.00; and • a minimum interest coverage ratio of no less than 2.50 to 1.00. The Partnership was in compliance with all financial covenants at September 30, 2019 . On September 30, 2019 , the outstanding balance on the revolving credit facility was $246.0 million at an interest rate of 3.52% . The Partnership had the maximum amount of remaining revolving credit available for borrowing at September 30, 2019 , or $354.0 million . At December 31, 2018 , the outstanding balance on the revolving credit facility was $84.0 million at an interest rate of 4.21% On March 16, 2018, the Partnership, together with its wholly owned subsidiary CNX Midstream Finance Corp (“Finance Corp”) and (collectively, the “Issuers”), completed a private offering of the Senior Notes, with related guarantees (the “Guarantees”) and received net proceeds of approximately $394.0 million , after deducting the initial purchasers’ discount. In connection with the issuance of the Senior Notes, the Partnership capitalized related offering expenses, which are recorded in our consolidated balance sheet as a reduction to the principal amount. Net proceeds from the Senior Notes offering were primarily used to fund the Shirley-Penns Acquisition and repay existing indebtedness under our prior $250.0 million unsecured revolving credit facility. The Senior Notes mature on March 15, 2026 and accrue interest at a rate of 6.5% per year, which is payable semi-annually in arrears on March 15 and September 15. There are no principal payment requirements on the Senior Notes prior to maturity. The Senior Notes and Guarantees were issued pursuant to an indenture (the “Indenture”), dated March 16, 2018, among the Partnership, Finance Corp, the guarantors party thereto (the “Guarantors”) and UMB Bank, N.A., as trustee (the “Trustee”). The Senior Notes rank equally in right of payment with all of the Issuers’ existing and future senior indebtedness and senior to any subordinated indebtedness that the Issuers’ may incur. The Guarantees rank equally in right of payment to all of the Guarantors’ existing and future senior indebtedness. The Issuers may redeem all or part of the Senior Notes at redemption prices ranging from 104.875% beginning March 15, 2021 to 100.0% beginning March 15, 2024. Prior to March 15, 2021, the Issuers may on one or more occasions redeem up to 35.0% of the principal amount of the Senior Notes with an amount of cash not greater than the amount of the net cash proceeds from one or more equity offerings at a redemption price of 106.50% . At any time or from time to time prior to March 15, 2021, the Issuers may also redeem all or a part of the Senior Notes, at a redemption price equal to 100.0% of the principal amount thereof plus the Applicable Premium, as defined in the Indenture, plus accrued and unpaid interest. If the Partnership experiences certain kinds of changes of control, holders of the Senior Notes will be entitled to require the Partnership to repurchase all or any part of that holder’s Senior Notes pursuant to an offer on the terms set forth in the Indenture. The Partnership will offer to make a cash payment equal to 101.0% of the aggregate principal amount of the Senior Notes repurchased plus accrued and unpaid interest on the Senior Notes repurchased to, but not including, the date of purchase, subject to the rights of holders of the Senior Notes on the relevant record date to receive interest due on the relevant interest payment date. The Partnership’s long-term debt consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Senior Notes due March 2026 at 6.5% $ 400,000 $ 400,000 Less: Unamortized debt issuance costs 1,262 1,410 Less: Unamortized bond discount 4,813 5,375 Total Long-Term Debt $ 393,925 $ 393,215

LONG-TERM DEBT

LONG-TERM DEBT	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
LONG-TERM DEBT	REVOLVING CREDIT FACILITY On March 8, 2018, we entered into a five-year $600.0 million secured revolving credit facility with an accordion feature that allows, subject to certain terms and conditions, the Partnership to increase the available borrowings under the revolving credit facility by up to an additional $250.0 million . The revolving credit facility includes the ability to issue letters of credit up to $100.0 million in the aggregate. The available borrowing capacity is limited by certain financial covenants pertaining to leverage and interest coverage ratios as defined in the revolving credit facility agreement. On April 24, 2019, the Partnership amended its revolving credit facility and extended its maturity to April 2024. Among other things, we received an annual interest rate reduction of 0.25% on borrowings compared to the original agreement. Under the terms of the amended agreement, borrowings under the revolving credit facility will bear interest at our option at either: • the base rate, which is the highest of (i) the federal funds open rate plus 0.50% , (ii) PNC Bank, N.A.’s prime rate, or (iii) the one-month LIBOR rate plus 1.0% , in each case, plus a margin ranging from 0.50% to 1.50% ; or • the LIBOR rate plus a margin ranging from 1.50% to 2.50% . Following the amendment, the revolving credit facility now includes (i) the addition of a restricted payment basket permitting cash repurchases of IDRs subject to a pro forma secured leverage ratio of 3.00 to 1.00, a pro forma total leverage ratio of 4.00 to 1.00 and pro forma availability of 20% of commitments and (ii) a restricted payment basket for the repurchase of limited partner units not to exceed Available Cash (as defined in the partnership agreement) in any quarter of up to $150.0 million per year and up to $200.0 million during the life of the facility. Interest on base rate loans is payable on the first business day of each calendar quarter. 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 0.375% to 0.500% per annum depending on our most recent consolidated leverage ratio. The revolving credit facility contains a number of affirmative and negative covenants that include, among others, covenants that restrict the ability of the Partnership, its subsidiary guarantors and certain of its non-guarantor, non-wholly-owned subsidiaries, except in certain circumstances, to: (i) create, incur, assume or suffer to exist indebtedness; (ii) create or permit to exist liens on their properties; (iii) prepay certain indebtedness unless there is no default or event of default under the revolving credit facility; (iv) make or pay any dividends or distributions in excess of certain amounts; (v) merge with or into another person, liquidate or dissolve; or acquire all or substantially all of the assets of any going concern or going line of business or acquire all or a substantial portion of another person’s assets; (vi) make particular investments and loans; (vii) sell, transfer, convey, assign or dispose of its assets or properties other than in the ordinary course of business and other select instances; (viii) deal with any affiliate except in the ordinary course of business on terms no less favorable to the Partnership than it would otherwise receive in an arm’s length transaction; and (ix) amend in any material manner its certificate of incorporation, bylaws, or other organizational documents without giving prior notice to the lenders and, in some cases, obtaining the consent of the lenders. The agreement also contains customary events of default, including, but not limited to, a cross-default to certain other debt, breaches of representations and warranties, change of control events and breaches of covenants. The obligations under the revolving credit facility agreement are secured by substantially all of assets of the Partnership and its wholly owned subsidiaries. In addition, the Partnership is obligated to maintain at the end of each fiscal quarter: • for as long as at least $150.0 million of the Senior Notes are outstanding (Note 7), a maximum total leverage ratio of no greater than 5.25 to 1.00 (which increases to no greater than 5.50 to 1.00 during qualifying acquisition periods); • if less than $150.0 million of the Senior Notes are outstanding (Note 7), a maximum total leverage ratio of no greater than 4.75 to 1.00 (which increases to no greater than 5.25 to 1.00 during qualifying acquisition periods); • a maximum secured leverage ratio of no greater than 3.50 to 1.00; and • a minimum interest coverage ratio of no less than 2.50 to 1.00. The Partnership was in compliance with all financial covenants at September 30, 2019 . On September 30, 2019 , the outstanding balance on the revolving credit facility was $246.0 million at an interest rate of 3.52% . The Partnership had the maximum amount of remaining revolving credit available for borrowing at September 30, 2019 , or $354.0 million . At December 31, 2018 , the outstanding balance on the revolving credit facility was $84.0 million at an interest rate of 4.21% On March 16, 2018, the Partnership, together with its wholly owned subsidiary CNX Midstream Finance Corp (“Finance Corp”) and (collectively, the “Issuers”), completed a private offering of the Senior Notes, with related guarantees (the “Guarantees”) and received net proceeds of approximately $394.0 million , after deducting the initial purchasers’ discount. In connection with the issuance of the Senior Notes, the Partnership capitalized related offering expenses, which are recorded in our consolidated balance sheet as a reduction to the principal amount. Net proceeds from the Senior Notes offering were primarily used to fund the Shirley-Penns Acquisition and repay existing indebtedness under our prior $250.0 million unsecured revolving credit facility. The Senior Notes mature on March 15, 2026 and accrue interest at a rate of 6.5% per year, which is payable semi-annually in arrears on March 15 and September 15. There are no principal payment requirements on the Senior Notes prior to maturity. The Senior Notes and Guarantees were issued pursuant to an indenture (the “Indenture”), dated March 16, 2018, among the Partnership, Finance Corp, the guarantors party thereto (the “Guarantors”) and UMB Bank, N.A., as trustee (the “Trustee”). The Senior Notes rank equally in right of payment with all of the Issuers’ existing and future senior indebtedness and senior to any subordinated indebtedness that the Issuers’ may incur. The Guarantees rank equally in right of payment to all of the Guarantors’ existing and future senior indebtedness. The Issuers may redeem all or part of the Senior Notes at redemption prices ranging from 104.875% beginning March 15, 2021 to 100.0% beginning March 15, 2024. Prior to March 15, 2021, the Issuers may on one or more occasions redeem up to 35.0% of the principal amount of the Senior Notes with an amount of cash not greater than the amount of the net cash proceeds from one or more equity offerings at a redemption price of 106.50% . At any time or from time to time prior to March 15, 2021, the Issuers may also redeem all or a part of the Senior Notes, at a redemption price equal to 100.0% of the principal amount thereof plus the Applicable Premium, as defined in the Indenture, plus accrued and unpaid interest. If the Partnership experiences certain kinds of changes of control, holders of the Senior Notes will be entitled to require the Partnership to repurchase all or any part of that holder’s Senior Notes pursuant to an offer on the terms set forth in the Indenture. The Partnership will offer to make a cash payment equal to 101.0% of the aggregate principal amount of the Senior Notes repurchased plus accrued and unpaid interest on the Senior Notes repurchased to, but not including, the date of purchase, subject to the rights of holders of the Senior Notes on the relevant record date to receive interest due on the relevant interest payment date. The Partnership’s long-term debt consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Senior Notes due March 2026 at 6.5% $ 400,000 $ 400,000 Less: Unamortized debt issuance costs 1,262 1,410 Less: Unamortized bond discount 4,813 5,375 Total Long-Term Debt $ 393,925 $ 393,215

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	COMMITMENTS AND CONTINGENCIES Litigation The Partnership may become involved in certain legal proceedings from time to time, and where appropriate, we have accrued our estimate of the probable costs for the resolution of these claims. The Partnership believes that the ultimate outcome of any matter currently pending against the Partnership will not materially affect the Partnership’s business, financial condition, results of operations, liquidity or ability to make distributions. Leases On January 1, 2019, we adopted ASC 2016-02, and all the related amendments, using the transition method which allows a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption, if applicable. In connection with the adoption, we elected the transition relief package of practical expedients by applying previous accounting conclusions under ASC 840 to all leases that existed prior to the transition date. As a result, we did not reassess whether existing or expired contracts contain leases, the lease classification for any existing or expired leases, or whether lease origination costs qualified as initial direct costs. In addition, we elected the short-term practical expedient for all asset classes by establishing an accounting policy to exclude leases with a term of 12 months or less. Prospectively, we will not separate lease components from non-lease components for any asset classes. Lastly, we adopted the easement practical expedient, which allows us to apply ASC 842 prospectively to land easements after January 1, 2019. Easements that existed or expired prior to January 1, 2019 that were not previously assessed under ASC 840 will not be reassessed. The Partnership’s non-cancelable operating leases, the longest of which run through December 31, 2020, consist primarily of compression equipment. As of September 30, 2019, right-of-use (“ROU”) assets recorded under operating leases were $10.9 million (which includes $0.5 million of prepaid assets); accumulated amortization associated with those leases was $4.6 million . Corresponding lease liabilities associated with obligations on our ROU assets were $5.7 million , which were calculated using a weighted average incremental borrowing rate of 4.8% as of September 30, 2019. Cash paid for amounts included in the measurement of lease liabilities was $5.6 million in operating cash flows from operating leases for the nine months ended September 30, 2019 . Maturities of operating lease liabilities are as follows: (in thousands) Twelve months ended September 30, October 1, 2019 - September 30, 2020 $ 5,732 October 1, 2020 - September 30, 2021 36 Total lease payments 5,768 Less: imputed interest 115 Present value of operating lease liabilities $ 5,653 Total operating lease expense, which includes short-term leases, was $2.0 million and $1.8 million for the three months ended September 30, 2019 and 2018 and $6.1 million and $5.8 million for the nine months ended September 30, 2019 and 2018 , respectively. These expenses are included within operating expense - third party in our consolidated statements of operations.

SEGMENT INFORMATION

SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2019
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. Prior to the CNX and HG Energy Transactions, the Partnership had three operating segments, which also represented 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 additional information. During the first quarter of 2018, the Partnership, through its 100% interest in the Anchor Systems, completed the Shirley-Penns Acquisition. Prior to March 16, 2018, the Partnership held a 5% controlling interest in the earnings and throughput related to the Shirley-Penns System. Accordingly, until March 16, 2018, results attributable to limited and general partners of the Partnership reflect a 5% interest in the Shirley-Penns System, and results net to the Partnership include activity related to the Shirley-Penns Acquisition beginning March 16, 2018. However, in accordance with ASC 280 - Segment Reporting, information is reported in the tables below, for comparability purposes, as if the Shirley-Penns Acquisition occurred on January 1, 2018. In connection with the CNX Transaction and HG Energy Transaction, the Partnership distributed its 5% interest in the Growth Systems and related assets as well as its 5% interest in the Moundsville area midstream assets, which were previously a part of the Additional Systems, to CNX Gathering, which transferred these assets to HG Energy. Because the transferred assets had activity for the period from January 1, 2018 through May 2, 2018, we will continue to present historical segment information with regards to this transaction. Segment results for the periods presented were as follows: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2019 2018 2019 2018 Gathering Revenue: Anchor Systems $ 72,329 $ 58,457 $ 218,798 $ 171,231 Growth Systems — — — 2,572 Additional Systems 1,647 2,511 5,498 12,048 Total Gathering Revenue $ 73,976 $ 60,968 $ 224,296 $ 185,851 Net Income (Loss): Anchor Systems $ 43,978 $ 33,643 $ 125,852 $ 96,777 Growth Systems — — — 379 Additional Systems (313 ) (68 ) (748 ) 406 Total Net Income $ 43,665 $ 33,575 $ 125,104 $ 97,562 Depreciation Expense: Anchor Systems $ 5,770 $ 4,889 $ 16,450 $ 14,092 Growth Systems — — — 748 Additional Systems 414 417 1,244 1,765 Total Depreciation Expense $ 6,184 $ 5,306 $ 17,694 $ 16,605 Capital Expenditures for Segment Assets: Anchor Systems $ 63,616 $ 42,247 $ 242,737 $ 80,537 Growth Systems — — — 120 Additional Systems 4,673 1,994 8,419 5,171 Total Capital Expenditures $ 68,289 $ 44,241 $ 251,156 $ 85,828 Segment assets as of the dates presented were as follows: (in thousands) September 30, 2019 December 31, 2018 Segment Assets Anchor Systems $ 1,074,952 $ 832,885 Additional Systems 106,314 92,543 Total Segment Assets $ 1,181,266 $ 925,428

LONG-TERM INCENTIVE PLAN

LONG-TERM INCENTIVE PLAN	9 Months Ended
	Sep. 30, 2019
Share-based Payment Arrangement [Abstract]
LONG-TERM INCENTIVE PLAN	LONG-TERM INCENTIVE PLAN Under the Partnership’s 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 5.8 million 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. The following table presents phantom unit activity during the nine months ended September 30, 2019 : Number of Units Weighted Average Grant Date Fair Value Total awarded and unvested at December 31, 2018 178,629 $ 18.35 Granted 153,710 15.86 Vested (137,179) 17.53 Forfeited (23,819) 17.44 Total awarded and unvested at September 30, 2019 171,341 $ 16.90 The Partnership accounts for phantom units as equity awards and records compensation expense on a straight-line basis over the vesting period based on the fair value of the awards on their grant dates. 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 Partnership recognized $ 0.3 million and $0.5 million of compensation expense related to phantom units for the three months ended September 30, 2019 and 2018 , respectively, and $1.5 million and $1.8 million for the nine months ended September 30, 2019 and 2018 , respectively, which was included in general and administrative expense - related party in the consolidated statements of operations. At September 30, 2019 , the unrecognized compensation related to all outstanding awards was $ 1.8 million

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	SUBSEQUENT EVENTS On October 16, 2019 , the Board of Directors of the Partnership’s general partner declared a cash distribution to the Partnership’s unitholders with respect to the third quarter of 2019 of $0.4001 per common unit. The cash distribution will be paid on November 12, 2019 to unitholders of record at the close of business on November 5, 2019 .

SIGNIFICANT ACCOUNTING POLICI_2

SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2019
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 ( “
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 in the applicable periods presented within this Quarterly Report on Form 10-Q. Although the Partnership has less than a 100% economic interest in the Additional Systems and, for the period prior to May 3, 2018, had less than a 100% economic interest in the Growth Systems, each has been consolidated fully with the results of the Partnership in the applicable periods. 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. For example, net income attributable to general and limited partner ownership interests in the Partnership includes 100% of the results of the Shirley-Penns Systems for the period subsequent to the closing date of the Shirley-Penns Acquisition. Transactions between the Partnership and CNX Resources have been identified in the consolidated financial statements as transactions between related parties and are disclosed in Note 4–Related Party Transactions.
Revenue Recognition	On January 1, 2018, the Partnership adopted Accounting Standards Update (“ASU”) No. 2014-09, Revenue from Contracts with Customers and all the related amendments (“new revenue standard”) using the modified retrospective method. We did not have a transition adjustment as a result of the adoption of the new revenue standard. Revenues from contracts with customers We record revenue when obligations under the terms of the contracts with our shippers are satisfied; generally, this occurs on a daily basis as we gather natural gas at the wellhead. Revenue is measured as the amount of consideration we expect to receive in exchange for providing the natural gas gathering services. Nature of performance obligations At contract inception, we assess the services promised in our contracts with customers and identify a performance obligation for each promised service that is distinct. To identify the performance obligations, we consider all of the services promised in the contract, regardless of whether they are explicitly stated or are implied by customary business practices. Our revenue is generated from natural gas gathering activities. The gas gathering services are interruptible in nature and include charges for the volume of gas actually gathered and do not guarantee access to the system. Volumetric-based fees relate to actual volumes gathered. In general, the interruptible gathering of each unit one million British Thermal Units (MMBtu) of natural gas represents a separate performance obligation. Payment terms for these contracts require payment within 25 days of the end of the calendar month in which the hydrocarbons are gathered. Transaction price allocated to remaining performance obligations We are required to disclose the aggregate amount of transaction price that is allocated to performance obligations that have not yet been satisfied. However, the guidance provides certain practical expedients that limit this requirement. Substantially all of our revenues are derived from contracts that have terms of greater than one year. Under these contracts, the interruptible gathering of each unit of natural gas represents a separate performance obligation. For revenue associated with the Shirley-Penns System, for which we have remaining contractual performance obligations, the aggregate amount of the transaction price allocated to those remaining performance obligations was $375.6 million at September 30, 2019. See Note 4–Related Party Transactions for a detailed breakout of the minimum revenue by year. The amount of revenue associated with this contract up to the minimum volume commitment (“MVC”) is fixed in nature, and volumes that we may gather above the MVC will be variable in nature. As of September 30, 2019, no future performance obligations exist relative to volumes to be gathered in excess of the MVC as the related volumes have not yet been nominated for gathering. Therefore, we have not disclosed the value of unsatisfied performance obligations for the variable aspect of this agreement, nor have we disclosed the value of other unsatisfied performance obligations that are variable in nature. Prior-period performance obligations We record revenue when obligations under the terms of the contracts with our shippers are satisfied; generally this occurs on a daily basis when we gather gas at the wellhead. In some cases, we are required to estimate the amount of natural gas that we have gathered during an accounting period and record any differences between our estimates and the actual units of natural gas that we gathered in the following month. We have existing internal controls for our revenue estimation process and related accruals; historically, any identified differences between our revenue estimates and actual revenue received have not been significant. For the three and nine months ended September 30, 2019 and 2018, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material. Disaggregation of revenue See Note 9–Segment Information for additional information. Contract balances We invoice customers once our performance obligations have been satisfied, at which point payment becomes unconditional. Accordingly, our contracts with customers do not give rise to contract assets or liabilities under the new revenue standard. We also have no contract assets recognized from the costs to obtain or fulfill a contract with a customer. Classification The fees we charge our affiliates, including our Sponsor, are recorded in gathering revenue — related party in our consolidated statements of operations. Fees from midstream services we perform for third party shippers are 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, such as customer bankruptcies. 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 reserve as necessary using the specific identification method. Account balances are charged off against the reserve 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”) Accounting Standards Codification (“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.
Property and Equipment	Property and equipment is recorded at cost upon acquisition and is depreciated on a straight-line basis over the assets’ 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 gain or loss on disposition is recognized. The Partnership evaluates whether long-lived assets have been impaired during any given quarter and has processes in place to ensure that we become aware of such indicators. Impairment indicators may 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.
Leases	In February 2016, the FASB issued ASU 2016-02–Leases (Topic 842), which increases transparency and comparability among organizations by recognizing right-of-use (“ROU”) lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The ASU maintains a distinction between finance leases and operating leases, which is substantially similar to the classification criteria for distinguishing between capital leases and operating leases in the previous lease guidance. Retaining this distinction allows the recognition, measurement and presentation of expenses and cash flows arising from a lease to remain similar to the previous accounting treatment. A lessee is permitted to make an accounting policy election by class of underlying asset to exclude from balance sheet recognition any lease assets and lease liabilities with a term of 12 months or less, and instead to recognize lease expense on a straight-line basis over the lease term. For both financing and operating leases, the ROU asset and lease liability is initially measured at the present value of the lease payments in the consolidated balance sheet. In July 2018, the FASB issued ASU 2018-11 which provides entities with the option to initially apply the new lease standard at the adoption date and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption, if necessary. As discussed in Note 8, we adopted ASU 2016-02–Leases (Topic 842) effective January 1, 2019 utilizing the transition option provided by ASU 2018-11. We determine if an arrangement is a lease at inception. Operating leases are included in operating lease ROU assets, accrued liabilities, and long-term operating lease liabilities on our consolidated balance sheets. Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at the commencement date. As most of our leases do not provide an implicit rate, we use our incremental borrowing rate based on the information available at the commencement date of the lease in determining the present value of future payments. The operating lease ROU asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Our lease terms may include options to extend or terminate the lease when it is reasonably certain that we will exercise that option. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term.
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. We are under no legal or contractual obligation to restore or dismantle our gathering system upon abandonment.
Variable Interest Entities	Each of the Anchor and Additional Systems, and our former Growth Systems, is a limited partnership (the “ Limited Partnerships”) and a variable interest entity ( “ VIE”). These VIEs correspond with the manner in which we report our segment information in Note 9–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 CNX Midstream Operating Company LLC (the “ Operating Company”). The Operating Company, through its general partner ownership interest in each of the Limited Partnerships during the period in which any ownership interest exists, 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.
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.
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 ASC 718–Compensation–Stock Compensation. 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 10–Long-Term Incentive Plan for further discussion.
Net Income Per Limited Partner Unit and General Partner Interest	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 incentive distribution rights (“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.
Recent Accounting Pronouncements	In May 2019, the FASB issued ASU 2019-05 - Financial Instruments - Credit Losses (Topic 326), which provides optional targeted transition relief to entities adopting ASU 2016-13. ASU 2016-13 replaces the incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. The measurement of expected credit losses will be based on relevant information about past events, including historical experience, current conditions, and reasonable and supportable forecasts that affect the collectability of the reported amount. ASU 2019-05 provides the option to irrevocably elect the fair value option for certain financial assets previously measured at amortized cost basis. For those entities, the targeted transition relief will increase comparability of financial statement information by providing an option to align measurement methodologies for similar financial assets. The amendments in this ASU will be applied using the modified-retrospective approach and, for public entities, are effective for fiscal years beginning after December 15, 2019 and interim periods within those annual periods. Early adoption is permitted. The adoption of this guidance is not expected to have a material impact on the Partnership's financial statements.

CASH DISTRIBUTIONS (Tables)

CASH DISTRIBUTIONS (Tables)	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Schedule of Target Distributions	The information set forth below for our general partner includes its 2% general partner interest and assumes that our general partner has contributed any additional capital necessary to maintain its 2% general partner interest, our general partner has not transferred its IDRs and there are no arrearages on common units. In addition, the information below for common unitholders is also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. Marginal Percentage Interest in Distributions Distribution Targets Total Quarterly Distribution Per Unit Target Amount Common 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%
Cash Distributions	The Board of Directors declared the following cash distributions to the Partnership’s common unitholders and to the general partner for the periods presented: (in thousands, except per unit information) Quarters Ended Quarterly Distribution Per Unit Total Cash Distribution Date of Distribution March 31, 2018 $ 0.3245 $ 22,700 May 15, 2018 June 30, 2018 $ 0.3361 $ 24,176 August 14, 2018 September 30, 2018 $ 0.3479 $ 25,678 November 13, 2018 December 31, 2018 $ 0.3603 $ 27,268 February 13, 2019 March 31, 2019 $ 0.3732 $ 28,940 May 14, 2019 June 30, 2019 $ 0.3865 $ 30,637 August 14, 2019

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	Operating expense – related party consisted of the following: Three Months Ended Nine Months Ended (in thousands) 2019 2018 2019 2018 Operational services $ 3,850 $ 3,266 $ 11,334 $ 9,358 Electrical compression 2,255 1,865 6,833 5,287 Total Operating Expense — Related Party $ 6,105 $ 5,131 $ 18,167 $ 14,645 Related party payables consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Expense reimbursements $ 1,232 $ 1,143 Capital expenditures reimbursements — 182 General and administrative services 2,556 3,655 Total Accounts Payable — Related Party $ 3,788 $ 4,980
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	We will recognize minimum revenue on volumes throughout the term of the GGA, as set forth below: (in millions) Minimum Revenue per MVC Remainder of year ending December 31, 2019* $ — Year ending December 31, 2020 31.0 Year ending December 31, 2021 40.7 Year ending December 31, 2022 47.7 Year ending December 31, 2023 42.8 Remainder of term 213.4 Total minimum revenue to be recognized pursuant to Shirley-Penns MVC $ 375.6 *For 2019, the minimum revenue per the MVC has been met.

PROPERTY AND EQUIPMENT (Tables)

PROPERTY AND EQUIPMENT (Tables)	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Property and Equipment	Property and equipment consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Estimated Useful Lives in Years Land $ 77,846 $ 67,624 N/A Gathering equipment 680,808 605,722 25 — 40 Compression equipment 255,992 199,728 30 — 40 Processing equipment 30,979 30,979 40 Assets under construction 198,847 70,341 N/A Total Property and Equipment $ 1,244,472 $ 974,394 Less: Accumulated depreciation Gathering equipment $ 71,287 $ 58,561 Compression equipment 22,429 18,099 Processing equipment 6,579 5,959 Total Accumulated Depreciation $ 100,295 $ 82,619 Property and Equipment — Net $ 1,144,177 $ 891,775

LONG-TERM DEBT (Tables)

LONG-TERM DEBT (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of Debt	The Partnership’s long-term debt consisted of the following: (in thousands) September 30, 2019 December 31, 2018 Senior Notes due March 2026 at 6.5% $ 400,000 $ 400,000 Less: Unamortized debt issuance costs 1,262 1,410 Less: Unamortized bond discount 4,813 5,375 Total Long-Term Debt $ 393,925 $ 393,215

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Future minimum lease payments	Maturities of operating lease liabilities are as follows: (in thousands) Twelve months ended September 30, October 1, 2019 - September 30, 2020 $ 5,732 October 1, 2020 - September 30, 2021 36 Total lease payments 5,768 Less: imputed interest 115 Present value of operating lease liabilities $ 5,653

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Schedule of Operating Revenues and Income from Operations	Segment results for the periods presented were as follows: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2019 2018 2019 2018 Gathering Revenue: Anchor Systems $ 72,329 $ 58,457 $ 218,798 $ 171,231 Growth Systems — — — 2,572 Additional Systems 1,647 2,511 5,498 12,048 Total Gathering Revenue $ 73,976 $ 60,968 $ 224,296 $ 185,851 Net Income (Loss): Anchor Systems $ 43,978 $ 33,643 $ 125,852 $ 96,777 Growth Systems — — — 379 Additional Systems (313 ) (68 ) (748 ) 406 Total Net Income $ 43,665 $ 33,575 $ 125,104 $ 97,562 Depreciation Expense: Anchor Systems $ 5,770 $ 4,889 $ 16,450 $ 14,092 Growth Systems — — — 748 Additional Systems 414 417 1,244 1,765 Total Depreciation Expense $ 6,184 $ 5,306 $ 17,694 $ 16,605 Capital Expenditures for Segment Assets: Anchor Systems $ 63,616 $ 42,247 $ 242,737 $ 80,537 Growth Systems — — — 120 Additional Systems 4,673 1,994 8,419 5,171 Total Capital Expenditures $ 68,289 $ 44,241 $ 251,156 $ 85,828
Reconciliation of Assets from Segment to Consolidated	Segment assets as of the dates presented were as follows: (in thousands) September 30, 2019 December 31, 2018 Segment Assets Anchor Systems $ 1,074,952 $ 832,885 Additional Systems 106,314 92,543 Total Segment Assets $ 1,181,266 $ 925,428

LONG-TERM INCENTIVE PLAN (Table

LONG-TERM INCENTIVE PLAN (Tables)	9 Months Ended
	Sep. 30, 2019
Share-based Payment Arrangement [Abstract]
Schedule of Nonvested Performance-based Units Activity	The following table presents phantom unit activity during the nine months ended September 30, 2019 : Number of Units Weighted Average Grant Date Fair Value Total awarded and unvested at December 31, 2018 178,629 $ 18.35 Granted 153,710 15.86 Vested (137,179) 17.53 Forfeited (23,819) 17.44 Total awarded and unvested at September 30, 2019 171,341 $ 16.90

DESCRIPTION OF BUSINESS (Detail

DESCRIPTION OF BUSINESS (Details) $ in Millions	May 03, 2018USD ($)awell	May 02, 2018well	Mar. 16, 2018USD ($)	May 02, 2018segment	Jun. 30, 2018USD ($)	Sep. 30, 2019segmentsystem	Mar. 15, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Number of operating segments | segment				3		2
Number of primary midstream systems | system						5
Anchor Systems | Shirley-Penns System
Schedule of Equity Method Investments [Line Items]
Ownership interest			100.00%
Additional Systems | Shirley-Penns System
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent			95.00%
Cash consideration transferred to purchase limited partner controlling interest | $			$ 265		$ 265
Additional Systems | CONE Gathering
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent						95.00%
Additional Systems | Devco III LP - Shirley Pennsboro
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent								95.00%
Additional Systems | CNX Gathering LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage (as a percent)						5.00%		5.00%
Shirley-Penns System | Anchor Systems
Schedule of Equity Method Investments [Line Items]
Ownership interest						100.00%
Shirley-Penns System | Additional Systems
Schedule of Equity Method Investments [Line Items]
Ownership interest						5.00%
Ownership percentage (as a percent)							5.00%
Shirley-Penns System | CNX Gas
Schedule of Equity Method Investments [Line Items]
Ownership interest						100.00%
Senior Notes
Schedule of Equity Method Investments [Line Items]
Stated rate			6.50%			6.50%
Exchange Transaction | CNX Gas
Schedule of Equity Method Investments [Line Items]
Cash contribution to be received | $	$ 2
Exchange Transaction | Anchor Systems
Schedule of Equity Method Investments [Line Items]
Acres divested (in acres)	4,200
Exchange Transaction | Anchor Systems | CNX Gas
Schedule of Equity Method Investments [Line Items]
Number of wells committed | well	40
Exchange Transaction | Growth Systems
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent	5.00%
Exchange Transaction | Growth and Additional Systems
Schedule of Equity Method Investments [Line Items]
Acres divested (in acres)	275,000
Utica Shale formation | Exchange Transaction | Anchor Systems | CNX Gas
Schedule of Equity Method Investments [Line Items]
Additional acres dedicated (in acres)	16,100
Moundsville | Exchange Transaction
Schedule of Equity Method Investments [Line Items]
Noncontrolling interest, percent	5.00%
Affiliated Entity
Schedule of Equity Method Investments [Line Items]
Number of wells committed | well	192	140
Affiliated Entity | Exchange Transaction
Schedule of Equity Method Investments [Line Items]
Acres divested (in acres)	18,000
Affiliated Entity | Exchange Transaction | Anchor Systems
Schedule of Equity Method Investments [Line Items]
Number of wells committed | well	12
Affiliated Entity | Exchange Transaction | Growth and Additional Systems
Schedule of Equity Method Investments [Line Items]
Acres divested (in acres)	14,000

SIGNIFICANT ACCOUNTING POLICI_3

SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Accounting Policies [Abstract]
Payment terms			25 days
Contract term			Substantially all of our revenues are derived from contracts that have terms of greater than one year.
Performance obligations expected to be satisfied	$ 375,600,000		$ 375,600,000
Reserves for uncollectible amounts	0		0		$ 0
Fair value of long-term debt	390,800,000		390,800,000
Property and equipment impairments	0	$ 0	0	$ 0
Provision for federal or state income taxes	0	$ 0	0	$ 0
Asset retirement obligation	$ 0		$ 0		$ 0
Antidilutive securities excluded from computation of earnings per share (in units)	24,460	2,865	33,178	29,356

CASH DISTRIBUTIONS - Narrative

CASH DISTRIBUTIONS - Narrative (Details)	9 Months Ended
	Sep. 30, 2019$ / shares
Distribution Made to Limited Partner [Line Items]
Period to distribute available cash (in days)	45 days
General partner's ownership interest (as a percent)	2.00%
Maximum
Distribution Made to Limited Partner [Line Items]
Incentive distribution, rate (as a percent)	48.00%
Third Target Distribution | Maximum
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	$ 0.31875

CASH DISTRIBUTIONS - Allocation

CASH DISTRIBUTIONS - Allocations of Available Cash from Operating Surplus and Incentive Distribution Rights (Details)	9 Months Ended
	Sep. 30, 2019$ / shares
Minimum Quarterly Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	$ 0.2125
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
Distribution Made to Limited Partner [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%
Second Target Distribution
Distribution Made to Limited Partner [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%
Third Target Distribution
Distribution Made to Limited Partner [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%
Thereafter Distributions
Distribution Made to Limited Partner [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%
Minimum | First Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	$ 0.2125
Minimum | Second Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	0.24438
Minimum | Third Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	0.26563
Minimum | Thereafter Distributions
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	0.31875
Maximum | First Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	0.24438
Maximum | Second Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	0.26563
Maximum | Third Target Distribution
Distribution Made to Limited Partner [Line Items]
Intended quarterly distribution to limited partner (in dollars per unit)	$ 0.31875

CASH DISTRIBUTIONS - Schedule o

CASH DISTRIBUTIONS - Schedule of Cash Distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 14, 2019	May 14, 2019	Feb. 13, 2019	Nov. 13, 2018	Aug. 14, 2018	May 15, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Equity [Abstract]
Total Quarterly Distribution Per Unit (in dollars per share)	$ 0.3865	$ 0.3732	$ 0.3603	$ 0.3479	$ 0.3361	$ 0.3245
Total Quarterly Cash Distribution	$ 30,637	$ 28,940	$ 27,268	$ 25,678	$ 24,176	$ 22,700	$ 30,637	$ 24,176	$ 86,845	$ 68,365

RELATED PARTY TRANSACTIONS - Re

RELATED PARTY TRANSACTIONS - Related Party Transactions (Details) - USD ($) $ in Millions	Mar. 16, 2018	Jun. 30, 2018
Additional Systems | Shirley-Penns System
Related Party Transaction [Line Items]
Cash consideration transferred to purchase limited partner controlling interest	$ 265	$ 265

RELATED PARTY TRANSACTIONS - Sc

RELATED PARTY TRANSACTIONS - Schedule of Related Party Transactions (Details) - Operating Expense - Affiliated Entity - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Related Party Transaction [Line Items]
Charges for services	$ 6,105	$ 5,131	$ 18,167	$ 14,645
CNX | Shared Service Agreement
Related Party Transaction [Line Items]
Charges for services	3,850	3,266	11,334	9,358
CNX and Noble | Electrically-Powered Compression Reimbursement
Related Party Transaction [Line Items]
Charges for services	$ 2,255	$ 1,865	$ 6,833	$ 5,287

RELATED PARTY TRANSACTIONS - Pa

RELATED PARTY TRANSACTIONS - Payables (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
Due to related party (Note 4)	$ 3,788	$ 4,980
CNX Resources Corporation
Related Party Transaction [Line Items]
Due to related party (Note 4)	3,788	4,980
Expense reimbursements | CNX Resources Corporation
Related Party Transaction [Line Items]
Due to related party (Note 4)	1,232	1,143
Capital expenditures reimbursements | CNX Resources Corporation
Related Party Transaction [Line Items]
Due to related party (Note 4)	0	182
General and administrative services | CNX Resources Corporation
Related Party Transaction [Line Items]
Due to related party (Note 4)	$ 2,556	$ 3,655

RELATED PARTY TRANSACTIONS - Om

RELATED PARTY TRANSACTIONS - Omnibus Agreement (Details) - CNX - Affiliated Entity - Administrative Services - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Related Party Transaction [Line Items]
General and administrative expenses		$ 1.9
Scenario, Forecast
Related Party Transaction [Line Items]
General and administrative expenses	$ 7.9

RELATED PARTY TRANSACTIONS - Ga

RELATED PARTY TRANSACTIONS - Gathering Agreements (Details) a in Thousands, $ in Millions	May 02, 2018well	Jan. 03, 2018well	Sep. 30, 2019awell$ / bbl$ / MMBTU	Apr. 30, 2022USD ($)well	Apr. 30, 2021USD ($)well	Dec. 31, 2018well	Apr. 30, 2020USD ($)well	Dec. 31, 2020well	Dec. 31, 2023USD ($)well	Jan. 01, 2018$ / MMBTU
Related Party Transaction [Line Items]
Downstream fees receivable (in dollars per MMBtu)			0.607
Conditional increase, percent			2.50%
Maximum change in fees, commencing January 1, 2035, percent			3.00%
MVC, gas gathering fee (in dollars per MMBtu)			0.3588
CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Term of agreement			20 years
Additional acres dedicated (in acres) | a			63
Termination period to either party			180 days
Marcellus Shale formation
Related Party Transaction [Line Items]
Fees receivable, excluding downstream (in dollars per MMBtu)			0.442
Marcellus Shale formation | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Number of wells drilled and completed (in wells) | well		125	140			30
Pittsburgh International Airport Areas
Related Party Transaction [Line Items]
Downstream fees receivable (in dollars per MMBtu)			0.304
Majorsville area
Related Party Transaction [Line Items]
Condensate fees receivable (in dollars per Bbl) | $ / bbl			5.52
Utica Shale, McQuay Area | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Gas gathering fee (in dollars per MMBtu)			0.225
Marcellus and Utical Shale, Wadestown Area | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Gas gathering fee (in dollars per MMBtu)			0.35
McQuay And Wadestown Areas | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Compression fee, tier 1 pressure services, maximum of 600 psi (in dollars per MMBtu)										0.065
Compression fee, tier 2 pressure services, maximum of 300 psi (in dollars per MMBtu)										0.130
Majorsville And Mamont Areas | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Number of wells drilled and completed (in wells) | well	40
Shirley-Penns area
Related Party Transaction [Line Items]
Condensate fees receivable (in dollars per Bbl) | $ / bbl			5.52
Subsequent Event | Marcellus Shale formation | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Number of wells drilled and completed (in wells) | well				30	40		40
Deficiency payment, per well | $				$ 2	$ 2		$ 3.5
Subsequent Event | Majorsville And Mamont Areas | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Number of wells drilled and completed (in wells) | well								15	25
Deficiency payment, per well | $									$ 2.8
Minimum | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Quarterly update, historical period			24 months
Maximum | CNX Gas | Affiliated Entity | Gas Gathering Agreements
Related Party Transaction [Line Items]
Quarterly update, historical period			48 months
Quarterly update, future outlook period			10 years

RELATED PARTY TRANSACTIONS - _2

RELATED PARTY TRANSACTIONS - Schedule of MVC per Gathering Agreements (Details) $ in Millions	Sep. 30, 2019USD ($)
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 375.6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 31
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 40.7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 47.7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 42.8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Related Party Transactions [Abstract]
Performance obligations expected to be satisfied	$ 213.4
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligations expected to be satisfied, expected timing

PROPERTY AND EQUIPMENT (Details

PROPERTY AND EQUIPMENT (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 1,244,472	$ 974,394
Less — accumulated depreciation	100,295	82,619
Property and Equipment — Net	1,144,177	891,775
Land
Property, Plant and Equipment [Line Items]
Total Property and Equipment	77,846	67,624
Gathering equipment
Property, Plant and Equipment [Line Items]
Total Property and Equipment	680,808	605,722
Less — accumulated depreciation	$ 71,287	58,561
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	$ 255,992	199,728
Less — accumulated depreciation	$ 22,429	18,099
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	$ 6,579	5,959
Estimated useful life	40 years
Assets under construction
Property, Plant and Equipment [Line Items]
Total Property and Equipment	$ 198,847	$ 70,341

PROPERTY AND EQUIPMENT - Narrat

PROPERTY AND EQUIPMENT - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Property, Plant and Equipment [Line Items]
Gain (loss) on asset sales and abandonments	$ 0	$ 0	$ (7,229,000)	$ (2,501,000)
Assets under construction
Property, Plant and Equipment [Line Items]
Interest costs capitalized	$ 1,600,000	$ 0	3,700,000	$ 0
Anchor Systems
Property, Plant and Equipment [Line Items]
Gain (loss) on asset sales and abandonments			$ (7,200,000)

REVOLVING CREDIT FACILITY - Nar

REVOLVING CREDIT FACILITY - Narrative (Details)	Apr. 24, 2019USD ($)	Mar. 08, 2018USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Interest rate decrease	0.25%
Debt covenant, maximum secured leverage ratio	3
Deb covenant, maximum total leverage ratio	4
Pro forma commitment percentage	20.00%
Maximum borrowing capacity, per year	$ 150,000,000
Maximum borrowing capacity, per life of facility	$ 200,000,000
Credit Facility
Debt Instrument [Line Items]
Debt term		5 years
Revolving credit facility		$ 600,000,000
Additional borrowing capacity available		250,000,000
Debt covenant, maximum secured leverage ratio			3.50
Debt covenant, minimum interest coverage ratio			2.50
Long term line of credit			$ 246,000,000	$ 84,000,000
Credit facility interest rate			3.52%	4.21%
Remaining borrowing capacity			$ 354,000,000
Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Credit Facility | Base Rate, London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Basis spread on variable rate	1.00%
Letter of Credit
Debt Instrument [Line Items]
Revolving credit facility		$ 100,000,000
Leverage Ratio 1 | Credit Facility
Debt Instrument [Line Items]
Deb covenant, maximum total leverage ratio			5.25
Debt covenant, maximum, aggregate unsecured notes			$ 150,000,000
Debt covenant, maximum total leverage ratio during qualifying acquisition periods			5.50
Leverage Ratio 2 | Credit Facility
Debt Instrument [Line Items]
Deb covenant, maximum total leverage ratio			4.75
Debt covenant, maximum, aggregate unsecured notes			$ 150,000,000
Debt covenant, maximum total leverage ratio during qualifying acquisition periods			5.25
Minimum | Credit Facility
Debt Instrument [Line Items]
Commitment fee percentage			0.375%
Minimum | Credit Facility | LIBOR plus 1%
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Minimum | Credit Facility | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate	1.50%
Maximum | Credit Facility
Debt Instrument [Line Items]
Commitment fee percentage			0.50%
Maximum | Credit Facility | LIBOR plus 1%
Debt Instrument [Line Items]
Basis spread on variable rate	1.50%
Maximum | Credit Facility | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate	2.50%

LONG-TERM DEBT - Narrative (Det

LONG-TERM DEBT - Narrative (Details) - USD ($) $ in Thousands	Mar. 15, 2024	Mar. 15, 2021	Mar. 16, 2018	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term debt				$ 393,925	$ 393,215
Senior Notes
Debt Instrument [Line Items]
Long-term debt			$ 394,000	$ 393,925	$ 393,215
Stated rate			6.50%	6.50%
Redemption price including premium, percent			106.50%
Percent of principal amount able to be redeemed			35.00%
Redemption price of principal, percent			100.00%
Change of control, cash payment of aggregate principal amount repurchased, percentage			101.00%
Scenario, Forecast | Senior Notes
Debt Instrument [Line Items]
Redemption price including premium, percent	100.00%	104.875%
Credit Facility
Debt Instrument [Line Items]
Repayments of debt			$ 250,000

LONG-TERM DEBT - Schedule of De

LONG-TERM DEBT - Schedule of Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018	Mar. 16, 2018
Debt Instrument [Line Items]
Long-term debt	$ 393,925	$ 393,215
Senior Notes
Debt Instrument [Line Items]
Stated rate	6.50%		6.50%
Long-term debt, gross	$ 400,000	400,000
Less: Unamortized debt issuance costs	1,262	1,410
Less: Unamortized bond discount	4,813	5,375
Long-term debt	$ 393,925	$ 393,215	$ 394,000

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - Narrative, Leases (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Lessee, Lease, Description [Line Items]
Operating lease, right-of-use, gross	$ 10,900		$ 10,900
Operating lease right of use asset, accumulated depreciation	4,600		4,600
Operating lease, liability	5,653		5,653
Operating lease, liability, noncurrent	$ 40		$ 40
Weighted average discount rate, percent	4.80%		4.80%
Cash paid in operating cash clows from operating leases			$ 5,600
Operating lease expense	$ 2,000	$ 1,800	6,100	$ 5,800
Prepaid Assets
Lessee, Lease, Description [Line Items]
Operating lease, right-of-use, gross	$ 500		$ 500

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - Maturities of Operating Lease Liabilities (Details) $ in Thousands	Sep. 30, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
October 1, 2019 - September 30, 2020	$ 5,732
October 1, 2020 - September 30, 2021	36
Total lease payments	5,768
Less: imputed interest	115
Present value of operating lease liabilities	$ 5,653

SEGMENT INFORMATION - Narrative

SEGMENT INFORMATION - Narrative (Details) - segment	Mar. 16, 2018	May 02, 2018	Sep. 30, 2019	May 03, 2018	Mar. 15, 2018
Segment Reporting Information [Line Items]
Number of operating segments		3	2
Shirley-Penns System | Anchor Systems
Segment Reporting Information [Line Items]
Ownership interest	100.00%
Shirley-Penns System | Additional Systems
Segment Reporting Information [Line Items]
Noncontrolling interest, percent	95.00%
Exchange Transaction | Growth Systems
Segment Reporting Information [Line Items]
Noncontrolling interest, percent				5.00%
Moundsville | Exchange Transaction
Segment Reporting Information [Line Items]
Noncontrolling interest, percent				5.00%
Shirley-Penns System | Anchor Systems
Segment Reporting Information [Line Items]
Ownership interest			100.00%
Shirley-Penns System | Additional Systems
Segment Reporting Information [Line Items]
Ownership interest			5.00%
Ownership percentage (as a percent)					5.00%

SEGMENT INFORMATION - Schedule

SEGMENT INFORMATION - Schedule of Segment Results (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Gathering Revenue	$ 73,976	$ 60,968	$ 224,296	$ 185,851
Net Income (Loss)	43,665	33,575	125,104	97,562
Depreciation Expense	6,184	5,306	17,694	16,605
Capital Expenditures for Segment Assets	68,289	44,241	251,156	85,828
Segment Assets	1,181,266		1,181,266		$ 925,428
Anchor Systems
Segment Reporting Information [Line Items]
Gathering Revenue	72,329	58,457	218,798	171,231
Net Income (Loss)	43,978	33,643	125,852	96,777
Depreciation Expense	5,770	4,889	16,450	14,092
Capital Expenditures for Segment Assets	63,616	42,247	242,737	80,537
Segment Assets	1,074,952		1,074,952		832,885
Growth Systems
Segment Reporting Information [Line Items]
Gathering Revenue	0	0	0	2,572
Net Income (Loss)	0	0	0	379
Depreciation Expense	0	0	0	748
Capital Expenditures for Segment Assets	0	0	0	120
Additional Systems
Segment Reporting Information [Line Items]
Gathering Revenue	1,647	2,511	5,498	12,048
Net Income (Loss)	(313)	(68)	(748)	406
Depreciation Expense	414	417	1,244	1,765
Capital Expenditures for Segment Assets	4,673	$ 1,994	8,419	$ 5,171
Segment Assets	$ 106,314		$ 106,314		$ 92,543

LONG-TERM INCENTIVE PLAN - Narr

LONG-TERM INCENTIVE PLAN - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation costs	$ 1.8		$ 1.8
Common Units | 2014 LTIP | 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
Common Units | 2014 LTIP | Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unit based compensation	$ 0.3	$ 0.5	$ 1.5	$ 1.8
Director | 2014 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			1 year
Officer | 2014 LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period			3 years
Annual award vesting percentage			33.00%

LONG-TERM INCENTIVE PLAN - Sche

LONG-TERM INCENTIVE PLAN - Schedule of Nonvested Performance-based Units Activity (Details) - Phantom Share Units (PSUs)	9 Months Ended
	Sep. 30, 2019$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Total awarded and unvested, beginning balance (in shares) | shares	178,629
Granted (in shares) | shares	153,710
Vested (in shares) | shares	(137,179)
Forfeited (in shares) | shares	(23,819)
Total awarded and unvested, ending balance (in shares) | shares	171,341
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) | $ / shares	$ 18.35
Granted (in dollars per share) | $ / shares	15.86
Vested (in dollars per share) | $ / shares	17.53
Forfeited (in dollars per share) | $ / shares	17.44
Total awarded and unvested, ending balance (in shares) | $ / shares	$ 16.90

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - $ / shares		Nov. 12, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Subsequent Event [Line Items]
Cash distributions declared per unit (in dollars per share)	[1]		$ 0.4001	$ 0.3479	$ 1.1598	$ 1.0085
Subsequent Event
Subsequent Event [Line Items]
Cash distributions declared per unit (in dollars per share)		$ 0.4001
[1]	Represents the cash distributions declared during the month following the end of each respective quarterly period. See Note 11.