Summit Midstream Partners (SMLP) 10-Q 8 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Oct. 31, 2019
Cover [Abstract]
Entity Registrant Name	Summit Midstream Partners, LP
Entity Central Index Key	0001549922
Document Type	10-Q
Document Period End Date	Sep. 30, 2019
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		82,749,521
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Title of 12(b) Security	Common Units
Trading Symbol	SMLP
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Shell Company	false
Entity File Number	001-35666
Entity Tax Identification Number	45-5200503
Entity Address, Address Line One	1790 Hughes Landing Blvd
Entity Address, Address Line Two	Suite 500
Entity Address, City or Town	The Woodlands
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77380
City Area Code	832
Local Phone Number	413-4770
Document Quarterly Report	true
Entity Interactive Data Current	Yes
Document Transition Report	false
Entity Incorporation, State or Country Code	DE

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 5,050	$ 4,345
Accounts receivable	88,889	97,936
Other current assets	5,525	3,971
Total current assets	99,464	106,252
Property, plant and equipment, net	1,899,281	1,963,713
Intangible assets, net	243,773	273,416
Goodwill		16,211
Investment in equity method investees	648,748	649,250
Other noncurrent assets	10,190	11,720
Total assets	2,901,456	3,020,562
Current liabilities:
Trade accounts payable	27,651	38,414
Accrued expenses	9,616	21,963
Due to affiliate	142	240
Deferred revenue	12,595	11,467
Ad valorem taxes payable	7,941	10,550
Accrued interest	15,367	12,286
Accrued environmental remediation	1,674	2,487
Other current liabilities	12,422	12,645
Deferred Purchase Price Obligation	295,834
Total current liabilities	383,242	110,052
Long-term debt	1,392,986	1,257,731
Noncurrent Deferred Purchase Price Obligation		383,934
Noncurrent deferred revenue	39,834	39,504
Noncurrent accrued environmental remediation	2,704	3,149
Other noncurrent liabilities	8,491	4,968
Total liabilities	1,827,257	1,799,338
Commitments and contingencies (Note 16)
Series A Preferred Units (300,000 units issued and outstanding at September 30, 2019 and December 31, 2018)	300,741	293,616
Common limited partner capital (82,748,345 units issued and outstanding at September 30, 2019 and 73,390,853 units issued and outstanding at December 31, 2018)	773,458	902,358
General Partner interests (zero units issued and outstanding at September 30, 2019 and 1,490,999 units issued and outstanding at December 31, 2018)		25,250
Total partners' capital	1,074,199	1,221,224
Total liabilities and partners' capital	$ 2,901,456	$ 3,020,562

UNAUDITED CONDENSED CONSOLIDA_2

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - shares	Sep. 30, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Series A preferred unitholders, issued	300,000	300,000
Series A preferred unitholders, outstanding	300,000	300,000
Common limited partner capital (in shares), issued	82,748,345	73,390,853
Common limited partner capital (in shares), outstanding	82,748,345	73,390,853
General partner interests (in shares), issued	0	1,490,999
General partner interests (in shares), outstanding	0	1,490,999

UNAUDITED CONDENSED CONSOLIDA_3

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenues:
Total revenues	$ 100,187	$ 127,479	$ 331,281	$ 372,982
Costs and expenses:
Cost of natural gas and NGLs	$ 7,472	$ 26,879	$ 50,802	$ 71,549
Type of Cost, Good or Service [Extensible List]	us-gaap:OilAndGasPurchasedMember	us-gaap:OilAndGasPurchasedMember	us-gaap:OilAndGasPurchasedMember	us-gaap:OilAndGasPurchasedMember
Operation and maintenance	$ 26,231	$ 24,382	$ 74,171	$ 73,452
General and administrative	9,949	11,740	37,444	39,666
Depreciation and amortization	27,406	26,743	81,933	80,204
Transaction costs	129	0	1,079	0
(Gain) loss on asset sales, net	(347)	6	(1,595)	(6)
Long-lived asset impairment	0	1,540	45,021	2,127
Goodwill impairment	16,211	0	16,211	0
Total costs and expenses	87,051	91,290	305,066	266,992
Other income	12	58	304	78
Interest expense	(19,335)	(14,862)	(54,803)	(44,821)
Deferred Purchase Price Obligation	(3,760)	37,204	(11,899)	(53,759)
(Loss) income before income taxes and loss from equity method investees	(9,947)	58,589	(40,183)	7,488
Income tax (expense) benefit	(21)	35	(1,370)	(88)
Loss from equity method investees	(677)	(1,169)	(1,197)	(3,703)
Net (loss) income	(10,645)	57,455	(42,750)	3,697
Net income attributable to noncontrolling interest	0	25	0	168
Net (loss) income attributable to SMLP	(10,645)	57,430	(42,750)	3,529
Net income attributable to General Partner, including IDRs	0	3,279	12	6,477
Net (loss) income attributable to limited partners	(10,645)	54,151	(42,762)	(2,948)
Series A Preferred Units
Costs and expenses:
Net (loss) income attributable to limited partners	7,125	7,125	21,375	21,375
Common units
Costs and expenses:
Net (loss) income attributable to limited partners	$ (17,770)	$ 47,026	$ (64,137)	$ (24,323)
(Loss) income per limited partner unit:
Basic (in dollars per share)	$ (0.21)	$ 0.64	$ (0.80)	$ (0.33)
Diluted (in dollars per share)	$ (0.21)	$ 0.64	$ (0.80)	$ (0.33)
Weighted-average limited partner units outstanding:
Basic (shares)	82,718	73,356	80,429	73,283
Diluted (shares)	82,718	73,756	80,429	73,283
Gathering Services and Related Fees
Revenues:
Total revenues	$ 80,968	$ 86,427	$ 243,039	$ 260,373
Natural Gas, NGLs and Condensate Sales
Revenues:
Total revenues	12,219	34,017	68,438	92,025
Other Revenues
Revenues:
Total revenues	$ 7,000	$ 7,035	$ 19,804	$ 20,584

UNAUDITED CONDENSED CONSOLIDA_4

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL - USD ($) $ in Thousands	Total	Adjustment	Noncontrolling interest	Noncontrolling interestAdjustment	Limited partners, Series A Preferred Units	Limited partners, Series A Preferred UnitsAdjustment	Common	CommonAdjustment	General Partner	General PartnerAdjustment
January 1, 2018 impact of Topic 606 day 1 adoption	$ 4,214		$ 0		$ 0		$ 4,130		$ 84
Beginning balance at Dec. 31, 2017	1,389,669	$ 1,393,883	10,813	$ 10,813	294,426	$ 294,426	1,056,510	$ 1,060,640	27,920	$ 28,004
Net income (loss)	(3,845)		85		7,125		(13,113)		2,058
Distributions to unitholders	(45,053)		0		0		(42,024)		(3,029)
Unit-based compensation	1,979		0		0		1,979		0
Tax withholdings on vested SMLP LTIP awards	(1,943)		0		0		(1,943)		0
Other	(940)		0		(810)		(130)		0
Ending balance at Mar. 31, 2018	1,344,081		10,898		300,741		1,005,409		27,033
Beginning balance at Dec. 31, 2017	1,389,669	$ 1,393,883	10,813	$ 10,813	294,426	$ 294,426	1,056,510	$ 1,060,640	27,920	$ 28,004
Net income (loss)	3,697
Ending balance at Sep. 30, 2018	1,251,015		10,981		300,741		913,913		25,380
Beginning balance at Mar. 31, 2018	1,344,081		10,898		300,741		1,005,409		27,033
Net income (loss)	(49,913)		58		7,125		(58,236)		1,140
Distributions to unitholders	(59,466)		0		(14,250)		(42,180)		(3,036)
Unit-based compensation	2,004		0		0		2,004		0
Tax withholdings on vested SMLP LTIP awards	103		0		0		103		0
Other	(1)		0		0		(1)		0
Ending balance at Jun. 30, 2018	1,236,808		10,956		293,616		907,099		25,137
Net income (loss)	57,455		25		7,125		47,026		3,279
Distributions to unitholders	(45,215)		0		0		(42,179)		(3,036)
Unit-based compensation	1,965		0		0		1,965		0
Tax withholdings on vested SMLP LTIP awards	0		0		0		0		0
Other	2		0		0		2		0
Ending balance at Sep. 30, 2018	1,251,015		$ 10,981		300,741		913,913		25,380
Beginning balance at Dec. 31, 2018	1,221,224				293,616		902,358		25,250
Net income (loss)	(36,914)				7,125		(44,051)		12
Conversion of General Partner economic interests	0				0		22,222		(22,222)
Distributions to unitholders	(45,281)				0		(42,241)		(3,040)
Unit-based compensation	2,526				0		2,526		0
Tax withholdings on vested SMLP LTIP awards	(2,522)				0		(2,522)		0
Ending balance at Mar. 31, 2019	1,139,033				300,741		838,292		0
Beginning balance at Dec. 31, 2018	1,221,224				293,616		902,358		25,250
Net income (loss)	(42,750)
Ending balance at Sep. 30, 2019	1,074,199				300,741		773,458		0
Beginning balance at Mar. 31, 2019	1,139,033				300,741		838,292		0
Net income (loss)	4,809				7,125		(2,316)		0
Distributions to unitholders	(38,025)				(14,250)		(23,775)		0
Unit-based compensation	1,393				0		1,393		0
Tax withholdings on vested SMLP LTIP awards	(95)				0		(95)		0
Ending balance at Jun. 30, 2019	1,107,115				293,616		813,499		0
Net income (loss)	(10,645)				7,125		(17,770)		0
Distributions to unitholders	(23,777)				0		(23,777)		0
Unit-based compensation	1,451				0		1,451		0
Tax withholdings on vested SMLP LTIP awards	55				0		55		0
Ending balance at Sep. 30, 2019	$ 1,074,199				$ 300,741		$ 773,458		$ 0

UNAUDITED CONDENSED CONSOLIDA_5

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash flows from operating activities:
Net (loss) income	$ (42,750)	$ 3,697
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation and amortization	82,919	79,752
Noncash lease expense	2,299	0
Amortization of debt issuance costs	3,296	3,184
Deferred Purchase Price Obligation	11,899	53,759
Unit-based and noncash compensation	5,370	6,188
Loss from equity method investees	1,197	3,703
Distributions from equity method investees	28,008	26,528
Gain on asset sales, net	(1,595)	(6)
Long-lived asset impairment	45,021	2,127
Goodwill impairment	16,211	0
Changes in operating assets and liabilities:
Accounts receivable	8,363	(11,557)
Trade accounts payable	821	(2,991)
Accrued expenses	(12,193)	5,848
Due to affiliate	(98)	(1,075)
Deferred revenue, net	1,910	5,160
Ad valorem taxes payable	(2,061)	(106)
Accrued interest	3,081	2,975
Accrued environmental remediation, net	(2,025)	(3,060)
Other, net	(6,254)	(7,634)
Net cash provided by operating activities	143,419	166,492
Cash flows from investing activities:
Capital expenditures	(151,663)	(137,033)
Proceeds from asset sale (net of cash of $1,475 for the nine months ended September 30, 2019)	90,111	496
Distributions from equity method investment	7,252	0
Investment in equity method investee	(11,330)	0
Other, net	343	(209)
Net cash used in investing activities	(65,287)	(136,746)
Cash flows from financing activities:
Distributions to unitholders	(92,833)	(135,484)
Borrowings under Revolving Credit Facility	265,000	202,000
Repayments under Revolving Credit Facility	(131,000)	(79,000)
Repayment of Deferred Purchase Price Obligation	(100,000)	0
Debt issuance costs	(413)	(334)
Other, net	(3,931)	(3,738)
Net cash used in financing activities	(77,427)	(30,806)
Net change in cash and cash equivalents	705	(1,060)
Cash and cash equivalents, beginning of period	4,345	1,430
Cash and cash equivalents, end of period	5,050	370
Supplemental cash flow disclosures:
Cash interest paid	54,100	44,126
Less capitalized interest	5,752	5,536
Interest paid (net of capitalized interest)	48,348	38,590
Cash paid for taxes	150	175
Noncash investing and financing activities
Capital expenditures in trade accounts payable (period-end accruals)	22,166	20,977
Asset contribution to an equity method investment	23,643	0
Series A Preferred Units
Cash flows from financing activities:
Distributions to unitholders	(14,250)	(14,250)
Topic 606
Noncash investing and financing activities
Capital expenditures relating to contributions in aid of construction for day 1 adoption	0	33,123
Topic 842
Noncash investing and financing activities
Right-of-use assets relating to Topic 842	$ 5,448	$ 0

UNAUDITED CONDENSED CONSOLIDA_6

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Statement Of Cash Flows [Abstract]
Net of cash	$ 1,475

ORGANIZATION, BUSINESS OPERATIO

ORGANIZATION, BUSINESS OPERATIONS AND PRESENTATION AND CONSOLIDATION	9 Months Ended
	Sep. 30, 2019
Organization Consolidation And Presentation Of Financial Statements [Abstract]
ORGANIZATION, BUSINESS OPERATIONS AND PRESENTATION AND CONSOLIDATION	1. ORGANIZATION, BUSINESS OPERATIONS AND PRESENTATION AND CONSOLIDATION Organization. SMLP, a Delaware limited partnership, was formed in May 2012 and began operations in October 2012. SMLP is a growth-oriented limited partnership focused on developing, owning and operating midstream energy infrastructure assets that are strategically located in the core producing areas of unconventional resource basins, primarily shale formations, in the continental United States. Our business activities are conducted through various operating subsidiaries, each of which is owned or controlled by our wholly owned subsidiary holding company, Summit Holdings, a Delaware limited liability company. References to the "Partnership," "we," or "our" refer collectively to SMLP and its subsidiaries. The General Partner, a Delaware limited liability company, manages our operations and activities. Summit Investments, a Delaware limited liability company, is the ultimate owner of our General Partner and has the right to appoint the entire Board of Directors. Summit Investments is controlled by Energy Capital Partners. Summit Investments owned an approximate Neither SMLP nor its subsidiaries have any employees. All of the personnel that conduct our business are employed by Summit Investments, but these individuals are sometimes referred to as our employees. Business Operations. We provide natural gas gathering, compression, treating and processing services as well as crude oil and produced water gathering services pursuant to primarily long-term, fee-based agreements with our customers. Our results are primarily driven by the volumes of natural gas that we gather, compress, treat and/or process as well as by the volumes of crude oil and produced water that we gather. We are the owner-operator of, or have significant ownership interests in, the following gathering systems: • Summit Utica, a natural gas gathering system operating in the Appalachian Basin, which includes the Utica and Point Pleasant shale formations in southeastern Ohio; • Ohio Gathering, a natural gas gathering system and a condensate stabilization facility operating in the Appalachian Basin, which includes the Utica and Point Pleasant shale formations in southeastern Ohio; • Polar and Divide, a crude oil and produced water gathering system and transmission pipeline operating in the Williston Basin, which includes the Bakken and Three Forks shale formations in northwestern North Dakota; • Bison Midstream, an associated natural gas gathering system operating in the Williston Basin, which includes the Bakken and Three Forks shale formations in northwestern North Dakota; • Niobrara G&P, an associated natural gas gathering and processing system operating in the DJ Basin, which includes the Niobrara and Codell shale formations in northeastern Colorado and southeastern Wyoming; • Summit Permian, an associated natural gas gathering and processing system operating in the northern Delaware Basin, which includes the Wolfcamp and Bone Spring formations, in southeastern New Mexico; • Grand River, a natural gas gathering and processing system operating in the Piceance Basin, which includes the Mesaverde formation and the Mancos and Niobrara shale formations in western Colorado and eastern Utah; • DFW Midstream, a natural gas gathering system operating in the Fort Worth Basin, which includes the Barnett Shale formation in north-central Texas; and • Mountaineer Midstream, a natural gas gathering system operating in the Appalachian Basin, which includes the Marcellus Shale formation in northern West Virginia . Additionally, until March 22, 2019, we owned Tioga Midstream, a crude oil, produced water and associated natural gas gathering system operating in the Williston Basin, which includes the Bakken and Three Forks shale formations in northwestern North Dakota. Refer to Note 17 for details on the sale of Tioga Midstream. In June 2019, in conjunction with the Project, Summit Permian Transmission entered into a definitive joint venture agreement (the “Agreement”) with an affiliate of Double E’s foundation shipper (the “JV Partner”) to fund the capital expenditures associated with the Project. Refer to Note 8 for additional details. Other than our investments in Double E and Ohio Gathering, all of our business activities are conducted through wholly owned operating subsidiaries. Presentation and Consolidation. We prepare our unaudited condensed consolidated financial statements in accordance with GAAP as established by the FASB. We make estimates and assumptions that affect the reported amounts of assets and liabilities at the balance sheet dates, including fair value measurements, the reported amounts of revenues and expenses and the disclosure of commitments and contingencies. Although management believes these estimates are reasonable, actual results could differ from its estimates. These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and the regulations of the SEC. Certain information and note disclosures normally included in the annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to those rules and regulations. We believe that the disclosures made are adequate to make the information not misleading. In the opinion of management, the unaudited condensed consolidated financial statements contain all adjustments which are necessary to fairly present the unaudited condensed consolidated balance sheet as of September 30, 2019, the unaudited condensed consolidated statements of operations and statements of partners’ capital for the three and nine months ended September 30, 2019 and 2018 and the unaudited condensed consolidated statements of cash flows for the nine months ended September 30, 2019 and 2018. The balance sheet at December 31, 2018 included herein was derived from our audited financial statements, but does not include all disclosures required by GAAP. See Note 2 for the impact relating to the adoption of the new lease standard. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto that are included in our annual report on Form 10-K for the year ended December 31, 2018, as filed with the SEC on February 26, 2019 (the "2018 Annual Report"). The results of operations for an interim period are not necessarily indicative of results expected for a full year.

SUMMARY OF SIGNIFICANT ACCOUNTI

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Except for the changes below, there have been no changes to our significant accounting policies since December 31, 2018. Recent Accounting Pronouncements. Accounting standard setters frequently issue new or revised accounting rules. We review new pronouncements to determine the impact, if any, on our financial statements. Accounting standards that have or could possibly have a material effect on our financial statements are discussed below. Recently Adopted Accounting Pronouncements • ASU No. 2016-02 Leases (“Topic 842"). We adopted Topic 842 with a date of initial application of January 1, 2019. We applied Topic 842 by recognizing (i) a $5.4 million right-of-use (“ROU”) asset which represents the right to use, or to control the use of, specified assets for a lease term. The ROU asset is included in the Property, plant and equipment, net caption on the unaudited condensed consolidated balance sheet; and (ii) a $5.4 million lease liability for the obligation to make lease payments arising from the leases. The lease liability is included in the Other current liabilities and Other noncurrent liabilities captions on the unaudited condensed consolidated balance sheet. The comparative information has not been adjusted and is reported under the accounting standards in effect for those periods. Refer to Note 16 for additional information. Accounting Pronouncements Pending Adoption . We have not yet adopted the following accounting pronouncement as of September 3 0 , 201 9 : • ASU No. 2018-13 Fair Value Measurement (“ASU 2018-13”). ASU 2018-13 updates the disclosure requirements on fair value measurements including new disclosures for the changes in unrealized gains and losses for the period included in other comprehensive income for recurring Level 3 fair value measurements held at the end of the reporting period and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. ASU 2018-13 modifies existing disclosures including clarifying the measurement uncertainty disclosure. ASU 2018-13 removes certain existing disclosure requirements including the amount and reasons for transfers between Level 1 and Level 2 fair value measurements and the policy for the timing of transfer between levels. We are currently evaluating the provisions of ASU 2018-13 and expect the adoption will not have a material impact on our financial statements and related disclosures. We will adopt its provisions effective January 1, 2020.

REVENUE

REVENUE	9 Months Ended
	Sep. 30, 2019
Revenue From Contract With Customer [Abstract]
REVENUE	3. REVENUE The majority of our revenue is derived from long-term, fee-based contracts with our customers, which include original terms of up to 25 years. We recognize revenue earned from fee-based gathering, compression, treating and processing services in gathering services and related fees. We also earn revenue in the Williston Basin and Permian Basin reporting segments from the sale of physical natural gas purchased from our customers under certain percent-of-proceeds arrangements. Under ASC Topic 606, these gathering contracts are presented net within cost of natural gas and NGLs. We sell natural gas that we retain from certain customers in the Barnett Shale reporting segment to offset the power expenses of the electric-driven compression on the DFW Midstream system. We also sell condensate and NGLs retained from certain of our gathering services in the Piceance Basin and Permian Basin reporting segments. Revenues from the sale of natural gas and condensate are recognized in natural gas, NGLs and condensate sales; the associated expense is included in operation and maintenance expense. Certain customers reimburse us for costs we incur on their behalf. We record costs incurred and reimbursed by our customers on a gross basis, with the revenue component recognized in Other revenues. The transaction price in our contracts is primarily based on the volume of natural gas, crude oil or produced water transferred by our gathering systems to the customer’s agreed upon delivery point multiplied by the contractual rate. For contracts that include MVCs, variable consideration up to the MVC will be included in the transaction price. For contracts that do not include MVCs, we do not estimate variable consideration because the performance obligations are completed and settled on a daily basis. For contracts containing noncash consideration such as fuel received in-kind, we measure the transaction price at the point of sale when the volume, mix and market price of the commodities are known. We have contracts with MVCs that are variable and constrained. Contracts with greater than monthly MVCs are reviewed on a quarterly basis and adjustments to those estimates are made during each respective reporting period, if necessary. The transaction price is allocated if the contract contains more than one performance obligation such as contracts that include MVCs. The transaction price allocated is based on the MVC for the applicable measurement period . Performance obligations. The majority of our contracts have a single performance obligation which is either to provide gathering services (an integrated service) or sell natural gas, NGLs and condensate, which are both satisfied when the related natural gas, crude oil and produced water are received and transferred to an agreed upon delivery point. We also have certain contracts with multiple performance obligations. They include an option for the customer to acquire additional services such as contracts containing MVCs. These performance obligations would also be satisfied when the related natural gas, crude oil and produced water are received and transferred to an agreed upon delivery point. In these instances, we allocate the contract’s transaction price to each performance obligation using our best estimate of the standalone selling price of each service in the contract. Performance obligations for gathering services are generally satisfied over time. We utilize either an output method (i.e., measure of progress) for guaranteed, stand-ready service contracts or an asset/system delivery time estimate for non-guaranteed, as-available service contracts. Performance obligations for the sale of natural gas, NGLs and condensate are satisfied at a point in time. There are no significant judgments for these transactions because the customer obtains control based on an agreed upon delivery point. Certain of our gathering and/or processing agreements provide for monthly, annual or multi-year MVCs. Under these MVCs, our customers agree to ship and/or process a minimum volume of production on our gathering systems or to pay a minimum monetary amount over certain periods during the term of the MVC. A customer must make a shortfall payment to us at the end of the contracted measurement period if its actual throughput volumes are less than its contractual MVC for that period. Certain customers are entitled to utilize shortfall payments to offset gathering fees in one or more subsequent contracted measurement periods to the extent that such customer's throughput volumes in a subsequent contracted measurement period exceed its MVC for that contracted measurement period. We recognize customer obligations under their MVCs as revenue and contract assets when (i) we consider it remote that the customer will utilize shortfall payments to offset gathering or processing fees in excess of its MVCs in subsequent periods; (ii) the customer incurs a shortfall in a contract with no banking mechanism or claw back provision; (iii) the customer’s banking mechanism has expired; or (iv) it is remote that the customer will use its unexercised right. Our services are typically billed on a monthly basis and we do not offer extended payment terms. We do not have contracts with financing components. The following table presents estimated revenue expected to be recognized during the remainder of 2019 and over the remaining contract period related to performance obligations that are unsatisfied and are comprised of estimated MVC shortfall payments. We applied the practical expedient in paragraph 606-10-50-14 of Topic 606 for certain arrangements that we consider optional purchases (i.e., there is no enforceable obligation for the customer to make purchases) and those amounts are therefore excluded from the table. 2019 2020 2021 2022 2023 Thereafter (In thousands) Gathering services and related fees $ 31,349 $ 120,941 $ 100,117 $ 83,673 $ 70,971 $ 113,577 Revenue by Category. In the following table, revenue is disaggregated by geographic area and major products and services. Ohio Gathering is excluded from the tables below due to equity method accounting. For more detailed information about reportable segments, see Note 4. Reportable Segments Three months ended September 30, 2019 Utica Shale Williston Basin DJ Basin Permian Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 8,865 $ 16,685 $ 7,039 $ 986 $ 30,120 $ 11,286 $ 5,987 $ 80,968 $ - $ 80,968 Natural gas, NGLs and condensate sales — 1,878 93 3,797 1,733 4,828 — 12,329 (110 ) 12,219 Other revenues — 2,555 735 102 1,258 1,706 — 6,356 644 7,000 Total $ 8,865 $ 21,118 $ 7,867 $ 4,885 $ 33,111 $ 17,820 $ 5,987 $ 99,653 $ 534 $ 100,187 Reportable Segments Nine months ended September 30, 2019 Utica Shale Williston Basin DJ Basin Permian Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 23,951 $ 58,076 $ 14,784 $ 1,938 $ 92,515 $ 35,739 $ 18,081 $ 245,084 $ (2,045 ) $ 243,039 Natural gas, NGLs and condensate sales — 11,231 279 10,424 6,139 11,705 — 39,778 28,660 68,438 Other revenues — 8,133 2,776 183 3,341 5,008 — 19,441 363 19,804 Total $ 23,951 $ 77,440 $ 17,839 $ 12,545 $ 101,995 $ 52,452 $ 18,081 $ 304,303 $ 26,978 $ 331,281 Reportable Segments Three months ended September 30, 2018 Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 7,974 $ 18,020 $ 2,708 $ 34,035 $ 18,318 $ 7,150 $ 88,205 $ (1,778 ) $ 86,427 Natural gas, NGLs and condensate sales — 7,953 112 3,538 789 — 12,392 21,625 34,017 Other revenues — 3,037 962 1,110 1,913 — 7,022 13 7,035 Total $ 7,974 $ 29,010 $ 3,782 $ 38,683 $ 21,020 $ 7,150 $ 107,619 $ 19,860 $ 127,479 Reportable Segments Nine months ended September 30, 2018 Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 28,437 $ 58,792 $ 7,395 $ 100,812 $ 46,035 $ 23,025 $ 264,496 $ (4,123 ) $ 260,373 Natural gas, NGLs and condensate sales — 23,149 271 12,379 1,715 — 37,514 54,511 92,025 Other revenues — 8,909 2,689 3,498 5,595 — 20,691 (107 ) 20,584 Total $ 28,437 $ 90,850 $ 10,355 $ 116,689 $ 53,345 $ 23,025 $ 322,701 $ 50,281 $ 372,982 Contract balances. Contract assets relate to our rights to consideration for work completed but not billed at the reporting date and consist of the estimated MVC shortfall payments expected from our customers and unbilled activity associated with contributions in aid of construction. Contract assets are transferred to trade receivables when the rights become unconditional. The following table provides information about contract assets from contracts with customers: September 30, 2019 December 31, 2018 (In thousands) Contract assets, beginning of period $ 8,755 $ — Additions 15,127 26,403 Transfers out (5,836 ) (17,648 ) Contract assets, end of period $ 18,046 $ 8,755 As of September 30, 2019, receivables with customers totaled $63.5 million and contract assets totaled $18.0 million which were included in the Accounts receivable caption on the unaudited condensed consolidated balance sheet. As of December 31, 2018, receivables with customers totaled $82.9 million and contract assets totaled $8.8 million which were included in the Accounts receivable caption on the unaudited condensed consolidated balance sheet. Contract liabilities (deferred revenue) relate to the advance consideration received from customers primarily for contributions in aid of construction. We recognize contract liabilities under these arrangements in revenue over the contract period. For the three months ended September 30, 2019 and 2018, we recognized $2.4 million and $2.8 million of gathering services and related fees which was included in the contract liability balance as of the beginning of the period. For the nine months ended September 30, 2019 and 2018, we recognized $7.8 million and $7.8 million of gathering services and related fees which was included in the contract liability balance as of the beginning of the period. See Note 9 for additional details.

SEGMENT INFORMATION

SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
SEGMENT INFORMATION	4. SEGMENT INFORMATION As of September 30, 2019, our reportable segments are: • the Utica Shale, which is served by Summit Utica; • Ohio Gathering, which includes our ownership interest in OGC and OCC; • the Williston Basin, which is served by Polar and Divide and Bison Midstream; • the DJ Basin, which is served by Niobrara G&P; • the Permian Basin, which is served by Summit Permian; • the Piceance Basin, which is served by Grand River; • the Barnett Shale, which is served by DFW Midstream; and • the Marcellus Shale, which is served by Mountaineer Midstream. Additionally, until March 22, 2019, we owned Tioga Midstream, a crude oil, produced water and associated natural gas gathering system operating in the Williston Basin, which includes the Bakken and Three Forks shale formations in northwestern North Dakota. Refer to Note 17 to the unaudited condensed consolidated financial statements for details on the sale of Tioga Midstream. Each of our reportable segments provides midstream services in a specific geographic area. Our reportable segments reflect the way in which we internally report the financial information used to make decisions and allocate resources in connection with our operations. The Ohio Gathering reportable segment includes our investment in OGC and OCC. Income or loss from equity method investees, as reflected on the statements of operations, relates to Ohio Gathering and is recognized and disclosed on a one-month lag (see Note 8). For the three and nine months ended September 30, 2019, other than the investment activity described in Note 8, Double E did not have any results of operations given that the Project is currently under development. The Project is expected to be operational in the third quarter of 2021. Corporate and Other represents those results that are: (i) not specifically attributable to a reportable segment; (ii) not individually reportable (such as Double E); or (iii) that have not been allocated to our reportable segments for the purpose of evaluating their performance, including certain general and administrative expense items, natural gas and crude oil marketing services and transaction costs. Assets by reportable segment follow. September 30,2019 December 31, 2018 (In thousands) Assets (1): Utica Shale $ 207,850 $ 207,357 Ohio Gathering 620,496 649,250 Williston Basin 445,838 526,819 DJ Basin 187,542 166,580 Permian Basin 184,386 145,702 Piceance Basin 665,489 699,638 Barnett Shale 354,173 376,564 Marcellus Shale 186,899 208,790 Total reportable segment assets 2,852,673 2,980,700 Corporate and Other 48,783 44,181 Eliminations — (4,319 ) Total assets $ 2,901,456 $ 3,020,562 (1) At September 30, 2019, Corporate and Other included $28.3 million relating to our investment in Double E (included in the Investment in equity method investees caption of the unaudited condensed consolidated balance sheet). At December 31, 2018, Corporate and Other included $9.6 million of capital expenditures relating to the Project. Revenues by reportable segment follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Revenues (1): Utica Shale $ 8,865 $ 7,974 $ 23,951 $ 28,437 Williston Basin 21,118 29,010 77,440 90,850 DJ Basin 7,867 3,782 17,839 10,355 Permian Basin 4,885 — 12,545 — Piceance Basin 33,111 38,683 101,995 116,689 Barnett Shale 17,820 21,020 52,452 53,345 Marcellus Shale 5,987 7,150 18,081 23,025 Total reportable segments revenue 99,653 107,619 304,303 322,701 Corporate and Other 534 23,636 31,196 57,234 Eliminations — (3,776 ) (4,218 ) (6,953 ) Total revenues $ 100,187 $ 127,479 $ 331,281 $ 372,982 (1) Excludes revenues earned by Ohio Gathering due to equity method accounting. Counterparties accounting for more than 10% of total revenues were as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Percentage of total revenues (1): Counterparty A - Piceance Basin 12 % 11 % 11 % 11 % Counterparty B - Williston Basin 10 % * 10 % * Counterparty C - Barnett Shale * 12 % * 10 % (1) Excludes revenues earned by Ohio Gathering due to equity method accounting. * Less than 10% Depreciation and amortization, including the amortization expense associated with our favorable and unfavorable (for 2018) gas gathering contracts as reported in Other revenues, by reportable segment follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Depreciation and amortization (1): Utica Shale $ 1,913 $ 1,887 $ 5,744 $ 5,773 Williston Basin 4,788 5,672 14,958 16,903 DJ Basin 775 783 2,038 2,349 Permian Basin 1,312 — 3,547 — Piceance Basin 11,798 11,729 35,399 35,168 Barnett Shale (2) 4,045 3,760 12,542 11,276 Marcellus Shale 2,286 2,273 6,855 6,819 Total reportable segment depreciation and amortization 26,917 26,104 81,083 78,288 Corporate and Other 723 488 1,836 1,464 Total depreciation and amortization $ 27,640 $ 26,592 $ 82,919 $ 79,752 (1) Excludes depreciation and amortization recognized by Ohio Gathering due to equity method accounting. (2) Includes the amortization expense associated with our favorable and unfavorable (for 2018) gas gathering contracts as reported in Other revenues . Cash paid for capital expenditures by reportable segment follow. Nine months ended September 30, 2019 2018 (In thousands) Cash paid for capital expenditures (1): Utica Shale $ 2,473 $ 3,922 Williston Basin 20,288 18,463 DJ Basin 66,775 38,864 Permian Basin 43,422 67,640 Piceance Basin 1,919 5,302 Barnett Shale (2) 317 914 Marcellus Shale 347 557 Total reportable segment capital expenditures 135,541 135,662 Corporate and Other 16,122 1,371 Total cash paid for capital expenditures $ 151,663 $ 137,033 (1) Excludes cash paid for capital expenditures by Ohio Gathering due to equity method accounting. (2) For the nine months ended September 30, 2019, the amount includes sales tax reimbursements of $1.1 million. During the nine months ended September 30, 2019, Corporate and Other included cash paid of $0.7 million for corporate purposes; the remainder represents capital expenditures relating to the Project. We assess the performance of our reportable segments based on segment adjusted EBITDA. We define segment adjusted EBITDA as total revenues less total costs and expenses; plus (i) other income excluding interest income, (ii) our proportional adjusted EBITDA for equity method investees, (iii) depreciation and amortization, (iv) adjustments related to MVC shortfall payments, (v) adjustments related to capital reimbursement activity, (vi) unit-based and noncash compensation, (vii) change in the Deferred Purchase Price Obligation fair value, (viii) impairments and (ix) other noncash expenses or losses, less other noncash income or gains. We define proportional adjusted EBITDA for our equity method investees as the product of (i) total revenues less total expenses, excluding impairments and other noncash income or expense items, and amortization for deferred contract costs; and (ii) our ownership interest in Ohio Gathering during the respective period. For the purpose of evaluating segment performance, we exclude the effect of Corporate and Other revenues and expenses, such as certain general and administrative expenses (including compensation-related expenses and professional services fees), natural gas and crude oil marketing services, transaction costs, interest expense, change in the Deferred Purchase Price Obligation fair value and income tax expense or benefit from segment adjusted EBITDA. Segment adjusted EBITDA by reportable segment follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Reportable segment adjusted EBITDA Utica Shale $ 7,864 $ 6,521 $ 20,697 $ 24,459 Ohio Gathering 10,435 10,171 29,584 29,583 Williston Basin 13,840 19,849 49,224 54,849 DJ Basin 6,554 2,248 12,043 4,528 Permian Basin 210 — (996 ) — Piceance Basin 24,044 27,583 74,627 82,211 Barnett Shale 10,901 10,818 33,483 31,770 Marcellus Shale 4,958 5,550 14,735 18,769 Total of reportable segments' measures of profit $ 78,806 $ 82,740 $ 233,397 $ 246,169 A reconciliation of income or loss before income taxes and income or loss from equity method investees to total of reportable segments' measures of profit or loss follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Reconciliation of (loss) income before income taxes and loss from equity method investees to total of reportable segments' measures of profit: (Loss) income before income taxes and loss from equity method investees $ (9,947 ) $ 58,589 $ (40,183 ) $ 7,488 Add: Corporate and Other expense 7,039 9,324 28,406 28,949 Interest expense 19,335 14,862 54,803 44,821 Deferred Purchase Price Obligation 3,760 (37,204 ) 11,899 53,759 Depreciation and amortization 27,640 26,592 82,919 79,752 Proportional adjusted EBITDA for equity method investees 10,435 10,171 29,584 29,583 Adjustments related to MVC shortfall payments 3,534 (2,999 ) 2,868 (6,541 ) Adjustments related to capital reimbursement activity (145 ) (106 ) (1,906 ) 49 Unit-based and noncash compensation 1,291 1,965 5,370 6,188 (Gain) loss on asset sales, net (347 ) 6 (1,595 ) (6 ) Long-lived asset impairment — 1,540 45,021 2,127 Goodwill impairment 16,211 — 16,211 — Total of reportable segments' measures of profit $ 78,806 $ 82,740 $ 233,397 $ 246,169 Adjustments related to MVC shortfall payments recognize the earnings from MVC shortfall payments ratably over the term of the associated MVC (see Note 3). Contributions in aid of construction are recognized over the remaining term of the respective contract. We include adjustments related to capital reimbursement activity in our calculation of segment adjusted EBITDA to account for revenue recognized from contributions in aid of construction. Adjustments related to MVC shortfall payments by reportable segment follow. Three months ended September 30, 2019 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ 2,081 $ — $ 1,453 $ 3,534 Three months ended September 30, 2018 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ 2,032 $ — $ (5,031 ) $ (2,999 ) Nine months ended September 30, 2019 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ (1,387 ) $ (103 ) $ 4,358 $ 2,868 Nine months ended September 30, 2018 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ (1,354 ) $ (93 ) $ (5,094 ) $ (6,541 )

PROPERTY, PLANT, AND EQUIPMENT,

PROPERTY, PLANT, AND EQUIPMENT, NET	9 Months Ended
	Sep. 30, 2019
Property Plant And Equipment [Abstract]
PROPERTY, PLANT, AND EQUIPMENT, NET	5. PROPERTY, PLANT AND EQUIPMENT, NET Details on property, plant and equipment follow. September 30, 2019 December 31, 2018 (In thousands) Gathering and processing systems and related equipment $ 2,161,764 $ 2,155,325 Construction in progress 98,926 137,920 Land and line fill 9,823 11,748 Other 53,283 45,853 Total 2,323,796 2,350,846 Less accumulated depreciation 424,515 387,133 Property, plant and equipment, net $ 1,899,281 $ 1,963,713 In March 2019, certain events occurred which indicated that certain long-lived assets in the DJ Basin and Barnett Shale reporting segments could be impaired. Consequently, in the first quarter of 2019, we performed a recoverability assessment of certain assets within these reporting segments. In the DJ Basin, we determined that certain processing plant assets related to our existing 20 MMcf/d plant would no longer be utilized due to our expansion plans for the Niobrara G&P system. Based on the results of the recoverability assessment and the conclusion that the carrying value was not fully recoverable, we recorded an impairment charge of $34.7 million related to these assets in the first quarter of 2019. In the Barnett Shale, we determined, in the first quarter of 2019, that certain compressor station assets would be shut down and decommissioned. As a result, we recorded an impairment charge of $9.7 million related to these assets in the first quarter of 2019. See Note 6 for additional details. Depreciation expense and capitalized interest follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Depreciation expense $ 19,437 $ 18,567 $ 58,049 $ 55,781 Capitalized interest 1,391 2,451 5,752 5,536

AMORTIZING INTANGIBLE ASSETS

AMORTIZING INTANGIBLE ASSETS	9 Months Ended
	Sep. 30, 2019
Goodwill And Intangible Assets Disclosure [Abstract]
AMORTIZING INTANGIBLE ASSETS	6. AMORTIZING INTANGIBLE ASSETS Details regarding our intangible assets, all of which are subject to amortization, follow: September 30, 2019 Gross carrying amount Accumulated amortization Net (In thousands) Favorable gas gathering contracts $ 24,195 $ (14,891 ) $ 9,304 Contract intangibles 278,448 (163,152 ) 115,296 Rights-of-way 160,460 (41,287 ) 119,173 Total intangible assets $ 463,103 $ (219,330 ) $ 243,773 December 31, 2018 Gross carrying amount Accumulated amortization Net (In thousands) Favorable gas gathering contracts $ 24,195 $ (13,905 ) $ 10,290 Contract intangibles 278,448 (143,962 ) 134,486 Rights-of-way 166,209 (37,569 ) 128,640 Total intangible assets $ 468,852 $ (195,436 ) $ 273,416 In March 2019, certain events occurred which indicated that certain long-lived assets relating to the Barnett Shale reporting segment could be impaired (see Note 5). In connection with this evaluation, we evaluated the related intangible assets associated therewith for impairment consisting of rights-of-way intangible assets. We concluded the rights-of-way intangible assets were also impaired and, as a result, we recorded an impairment charge of $0.5 million in the first quarter of 2019. We recognized amortization expense in Other revenues as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Amortization expense – favorable gas gathering contracts $ (234 ) $ (389 ) $ (986 ) $ (1,166 ) We recognized amortization expense in costs and expenses as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Amortization expense – contract intangibles $ 6,396 $ 6,535 $ 19,190 $ 19,605 Amortization expense – rights-of-way 1,573 1,641 4,694 4,818 The estimated aggregate annual amortization expected to be recognized for the remainder of 2019 and each of the four succeeding fiscal years follows. Intangible assets (In thousands) 2019 $ 8,003 2020 32,073 2021 28,381 2022 25,314 2023 25,260

GOODWILL

GOODWILL	9 Months Ended
	Sep. 30, 2019
Goodwill And Intangible Assets Disclosure [Abstract]
GOODWILL	7. GOODWILL We evaluate goodwill for impairment annually on September 30. We also evaluate goodwill whenever events or circumstances indicate that it is more likely than not that the fair value of a reporting unit is less than its carrying value, including goodwill. If the reporting unit’s fair value exceeds its carrying value, including goodwill, we conclude that the goodwill of the reporting unit has not been impaired and no further work is performed. If we determine that the reporting unit’s carrying value, including goodwill, exceeds its fair value, we recognize the excess of the carrying value over the fair value as a goodwill impairment loss. We performed our annual goodwill impairment testing for the Mountaineer Midstream reporting unit as of September 30, 2019 using a combination of the income and market approaches. We determined that the fair value of the Mountaineer Midstream reporting unit did not exceed its carrying value, including goodwill. As a result, we recognized a goodwill impairment charge of $16.2 million for the three and nine months ended September 30, 2019. Fair Value Measurement. Our impairment determinations, in the context of (i) our annual impairment evaluations and (ii) our other-than-annual impairment evaluations involved significant assumptions and judgments, as discussed in the 2018 Annual Report. Differing assumptions regarding any of these inputs could have a significant effect on the valuations. As such, the fair value measurements utilized within these models are classified as non-recurring Level 3 measurements in the fair value hierarchy because they are not observable from objective sources.

EQUITY METHOD INVESTMENTS

EQUITY METHOD INVESTMENTS	9 Months Ended
	Sep. 30, 2019
Equity Method Investments And Joint Ventures [Abstract]
EQUITY METHOD INVESTMENTS	8. EQUITY METHOD INVESTMENTS Double E In June 2019, we formed Double E in connection with the Project. Effective June 26, 2019, Summit Permian Transmission, a wholly owned and consolidated subsidiary of the Partnership, and our JV Partner executed the Agreement whereby Double E will provide natural gas transportation services from multiple receipt points in the Delaware Basin to various delivery points in and around the Waha Hub in Texas. In connection with the Agreement and the related Project, the Partnership contributed total assets of approximately $23.6 million in exchange for a 70% ownership interest in Double E and our JV Partner contributed $7.3 million of cash in exchange for a 30% ownership interest in Double E. Concurrent with these contributions, and in accordance with the Agreement, Double E distributed $ 7.3 million to the Partnership. Subsequent to the formation of Double E, we also made additional cash investments of $ million through September 2019. Double E is deemed to be a variable interest entity as defined in GAAP. As of the date of the Agreement, Summit Permian Transmission is not deemed to be the primary beneficiary due to the JV Partner’s voting rights on significant matters. We account for our ownership interest in Double E as an equity method investment because we have significant influence over Double E. Our portion of Double E’s net assets, which was $28.3 million at September 30, 2019, is reported under the caption Investment in equity method investees on the unaudited condensed consolidated balance sheet. For the three and nine months ended September 30, 2019, other than the investment activity noted above, Double E did not have any results of operations given that the Project is currently under development. Ohio Gathering Ohio Gathering owns, operates and is currently developing midstream infrastructure consisting of a liquids-rich natural gas gathering system, a dry natural gas gathering system and a condensate stabilization facility in the Utica Shale in southeastern Ohio. Ohio Gathering provides gathering services pursuant to primarily long-term, fee-based gathering agreements, which include acreage dedications. In September 2019, an impairment loss was recognized by Ohio Gathering. Although we recognize activity for Ohio Gathering on a one-month lag, we recorded the impairment loss in our results of operations for the third quarter of 2019 because the information was available to us. We recorded our proportionate share of the impairment loss, or $0.8 million, in September 2019 in Loss from equity method investees in the unaudited condensed consolidated statements of operations. As a result of our joint venture partner funding a disproportionate amount of the capital calls during the nine months ended September 30, 2019, our ownership interest in Ohio Gathering decreased from 40.0% at December 31, 2018, to 38.8% at September 30, 2019. A reconciliation of our Investment in Ohio Gathering, September 30, 2019 $ 620,496 September cash distributions 3,478 Impairment loss 757 Basis difference (106,818 ) Investment in Ohio Gathering, net of basis difference, August 31, 2019 $ 517,913 Summarized statements of operations information for OGC and OCC follow (amounts represent 100% of investee financial information). Three months ended August 31, 2019 Three months ended August 31, 2018 OGC OCC OGC OCC (In thousands) Total revenues $ 38,097 $ 2,267 $ 37,180 $ 2,465 Total operating expenses 29,828 2,536 31,751 2,323 Net income (loss) 8,269 (268 ) 5,429 (5 ) Nine months ended August 31, 2019 Nine months ended August 31, 2018 OGC OCC OGC OCC (In thousands) Total revenues $ 106,825 $ 6,606 $ 106,263 $ 7,024 Total operating expenses 81,651 8,200 94,044 6,422 Net income (loss) 25,167 (1,594 ) 12,213 116

DEFERRED REVENUE

DEFERRED REVENUE	9 Months Ended
	Sep. 30, 2019
Revenue From Contract With Customer [Abstract]
DEFERRED REVENUE	9. DEFERRED REVENUE A rollforward of current deferred revenue follows. Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total current (In thousands) Current deferred revenue, January 1, 2019 $ 18 $ 1,414 $ 739 $ 7,616 $ 1,642 $ 38 $ 11,467 Additions 14 1,779 3,020 14,650 1,235 28 20,726 Less revenue recognized 14 1,259 1,745 15,324 1,228 28 19,598 Current deferred revenue, September 30, 2019 $ 18 $ 1,934 $ 2,014 $ 6,942 $ 1,649 $ 38 $ 12,595 A rollforward of noncurrent deferred revenue follows. Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total noncurrent (In thousands) Noncurrent deferred revenue, January 1, 2019 $ 21 $ 4,393 $ 7,284 $ 17,942 $ 9,628 $ 236 $ 39,504 Additions — 1,940 3,637 4,857 1,193 — 11,627 Less reclassification to current deferred revenue 14 2,225 3,020 4,775 1,235 28 11,297 Noncurrent deferred revenue, September 30, 2019 $ 7 $ 4,108 $ 7,901 $ 18,024 $ 9,586 $ 208 $ 39,834

DEBT

DEBT	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
DEBT	10. DEBT Debt consisted of the following: September 30, 2019 December 31, 2018 (In thousands) Summit Holdings' variable rate senior secured Revolving Credit Facility (4.80% at September 30, 2019 and 5.03% at December 31, 2018) due May 2022 $ 600,000 $ 466,000 Summit Holdings' 5.5% senior unsecured notes due August 2022 300,000 300,000 Less unamortized debt issuance costs (1) (1,801 ) (2,362 ) Summit Holdings' 5.75% senior unsecured notes due April 2025 500,000 500,000 Less unamortized debt issuance costs (1) (5,213 ) (5,907 ) Total long-term debt $ 1,392,986 $ 1,257,731 (1) Issuance costs are being amortized over the life of the notes. Revolving Credit Facility. Summit Holdings has a senior secured revolving credit facility which allows for revolving loans, letters of credit and swing line loans. The Revolving Credit Facility has a $1.25 billion borrowing capacity, matures in May 2022, and includes a $250.0 million accordion feature. As of September 30, 2019, SMLP and the Guarantor Subsidiaries fully and unconditionally and jointly and severally guarantee, and pledge substantially all of their assets in support of, the indebtedness outstanding under the Revolving Credit Facility. Borrowings under the Revolving Credit Facility bear interest, at the election of Summit Holdings, at a rate based on the alternate base rate (as defined in the credit agreement) plus an applicable margin ranging from 0.75% to 1.75% or the adjusted Eurodollar rate (the LIBOR rate), as defined in the credit agreement, plus an applicable margin ranging from 1.75% to 2.75%, with the commitment fee ranging from 0.30% to 0.50% in each case based on our relative leverage at the time of determination. At September 30, 2019, the applicable margin under LIBOR borrowings was 2.75% and the interest rate was 4.80%. The unused portion of the Revolving Credit Facility totaled $640.9 million, subject to a commitment fee of 0.50%, after giving effect to the issuance thereunder of a $9.1 million outstanding but undrawn irrevocable standby letter of credit. See Note 16 for additional information on our letter of credit. As of September 30, 2019, we had As of and during the nine months ended September 30, 2019, we were in compliance with the Revolving Credit Facility's financial covenants. There were Senior Notes. In July 2014, Summit Holdings and its 100 owned finance subsidiary, Finance Corp. (together with Summit Holdings, the "Co-Issuers") co-issued $300.0 million of 5.5 senior unsecured notes maturing August 15, 2022 (the "5.5% Senior Notes" and, together with the 5.75 Senior Notes (defined below), the “Senior Notes”). In February 2017, the Co-Issuers completed a public offering of T he Guarantor Subsidiaries are 100% owned by a subsidiary of SMLP. The Guarantor Subsidiaries and SMLP fully and unconditionally and jointly and severally guarantee the 5.5% Senior Notes and the 5.75% Senior Notes. There are no significant restrictions on the ability of SMLP or Summit Holdings to obtain funds from its subsidiaries by dividend or loan. Finance Corp. has had no assets or operations since inception in 2013. We have no other independent assets or operations. At no time have the Senior Notes been guaranteed by the Co-Issuers. As of and during the nine months ended September 30, 2019, we were in compliance with the covenants governing our Senior Notes. There were no defaults or events of default during the nine months ended September 30, 2019.

FINANCIAL INSTRUMENTS

FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
FINANCIAL INSTRUMENTS	11. FINANCIAL INSTRUMENTS Concentrations of Credit Risk. Financial instruments that potentially subject us to concentrations of credit risk consist of cash and cash equivalents and accounts receivable. We maintain our cash and cash equivalents in bank deposit accounts that frequently exceed federally insured limits. We have not experienced any losses in such accounts and do not believe we are exposed to any significant risk. Accounts receivable primarily comprise amounts due for the gathering, compression, treating and processing services we provide to our customers and also the sale of natural gas liquids resulting from our processing services. This industry concentration has the potential to impact our overall exposure to credit risk, either positively or negatively, in that our customers may be similarly affected by changes in economic, industry or other conditions. We monitor the creditworthiness of our counterparties and can require letters of credit or other forms of credit assurance for receivables from counterparties that are judged to have substandard credit, unless the credit risk can otherwise be mitigated. Our top Fair Value. The carrying amount of cash and cash equivalents, accounts receivable and trade accounts payable reported on the unaudited condensed consolidated balance sheet approximates fair value due to their short-term maturities. The Deferred Purchase Price Obligation's carrying value is its fair value because carrying value represents the present value of the payment expected to be made in 2020. In March 2019, the Partnership amended the Contribution Agreement related to the 2016 Drop Down and fixed the Remaining Consideration at $303.5 million, with such amount to be paid by the Partnership in one or more payments over the period from March 1, 2020 through December 31, 2020, in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, at the discretion of the Partnership. At least 50% of the Remaining Consideration must be paid on or before June 30, 2020 and interest will accrue at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020 (see Note 17 for additional information). A summary of the estimated fair value of our debt financial instruments follows. September 30, 2019 December 31, 2018 Carrying value Estimated fair value (Level 2) Carrying value Estimated fair value (Level 2) (In thousands) Summit Holdings 5.5% Senior Notes ($300.0 million principal) $ 298,199 $ 274,750 $ 297,638 $ 286,625 Summit Holdings 5.75% Senior Notes ($500.0 million principal) 494,787 423,750 494,093 455,208 The carrying value on the balance sheet of the Revolving Credit Facility is its fair value due to its floating interest rate. The estimated fair value for the Senior Notes is based on an average of nonbinding broker quotes as of September 3 0 , 201 9 and December 31, 201 8 . The use of different market assumptions or valuation methodologies may have a material effect on the estimated fair value of the Senior Notes.

PARTNERS' CAPITAL

PARTNERS' CAPITAL	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
PARTNERS' CAPITAL	12. PARTNERS' CAPITAL A rollforward of the number of preferred limited partner, common limited partner and General Partner units follows. Limited partners Series A Preferred Units Common General Partner Units, January 1, 2019 300,000 73,390,853 1,490,999 Conversion of General Partner economic interests — 8,750,000 (1,490,999 ) Net units issued under the SMLP LTIP — 607,492 — Units, September 30, 2019 300,000 82,748,345 — GP/IDR Exchange. On March 22, 2019, we cancelled our IDRs and converted our 2% economic GP interest to a non-economic GP interest in exchange for 8,750,000 SMLP common units which were issued to SMP Holdings in the Equity Restructuring. These units had a fair value of $84.5 million as of the transaction date (March 22, 2019). As a result of the Equity Restructuring, the general partner units and IDRs were eliminated, are no longer outstanding, and no longer participate in distributions of cash from SMLP. Energy Capital Partners continues to control the non-economic GP interest in SMLP. Immediately following the Equity Restructuring, SMP Holdings directly owned a 41.8% limited partner interest in SMLP and an affiliate of Energy Capital Partners II, LLC directly owned a 7.2% limited partner interest in SMLP. For the three and nine months ended September 30, 2018, our General Partner held IDRs that entitled it to receive increasing percentage allocations, up to a maximum of 50%, of the cash we distributed from operating surplus in excess of $0.46 per unit per quarter. Our payment of IDRs as reported in distributions to unitholders – general partner in the statement of partners' capital during the three and nine months ended September 30 follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) IDR payments $ — $ 2,136 $ 2,139 $ 6,400 For the purposes of calculating net income attributable to our General Partner in the statements of operations and partners' capital, the financial impact of IDRs was recognized in respect of the quarter for which the distributions were declared. For the purposes of calculating distributions At-the-market Program. In 2017, we executed an equity distribution agreement and filed a prospectus and a prospectus supplement with the SEC for the issuance and sale from time to time of SMLP common units having an aggregate offering price of up to $150.0 million (the "ATM Program"). These sales will be made (i) pursuant to the terms of the equity distribution agreement between us and the sales agents named therein and (ii) by means of ordinary brokers' transactions at market prices, in block transactions or as otherwise agreed between us and the sales agents. Sales of our common units may be made in negotiated transactions or transactions that are deemed to be at-the-market offerings as defined by SEC rules During the three and nine months ended September 30, 2019, there were no Series A Preferred Units. In 2017, we issued 300,000 Series A Preferred Units representing limited partner interests in the Partnership at a price to the public of $1,000 per unit as described in the 2018 Annual Report. Cash Distributions Paid and Declared. We paid the following per-unit distributions during the three and nine months ended September 3 0 : Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Per-unit distributions to unitholders $ 0.2875 $ 0.575 $ 1.1500 $ 1.725 On October 24, 2019, the Board of Directors of our General Partner declared a distribution of $0.2875

EARNINGS PER UNIT

EARNINGS PER UNIT	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
EARNINGS PER UNIT	13. EARNINGS PER UNIT The following table details the components of EPU. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands, except per-unit amounts) Numerator for basic and diluted EPU: Allocation of net (loss) income among limited partner interests: Net (loss) income attributable to limited partners $ (10,645 ) $ 54,151 $ (42,762 ) $ (2,948 ) Less net income attributable to Series A Preferred Units 7,125 7,125 21,375 21,375 Net (loss) income attributable to common limited partners $ (17,770 ) $ 47,026 $ (64,137 ) $ (24,323 ) Denominator for basic and diluted EPU: Weighted-average common units outstanding – basic 82,718 73,356 80,429 73,283 Effect of nonvested phantom units — 400 — — Weighted-average common units outstanding – diluted 82,718 73,756 80,429 73,283 (Loss) earnings per limited partner unit: Common unit – basic $ (0.21 ) $ 0.64 $ (0.80 ) $ (0.33 ) Common unit – diluted $ (0.21 ) $ 0.64 $ (0.80 ) $ (0.33 ) Nonvested anti-dilutive phantom units excluded from the calculation of diluted EPU 176 1 70 2

UNIT-BASED AND NONCASH COMPENSA

UNIT-BASED AND NONCASH COMPENSATION	9 Months Ended
	Sep. 30, 2019
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
UNIT-BASED AND NONCASH COMPENSATION	14. UNIT-BASED AND NONCASH COMPENSATION SMLP Long-Term Incentive Plan. The SMLP LTIP provides for equity awards to eligible officers, employees, consultants and directors of our General Partner and its affiliates. Items to note: • In March 2019, we granted 639,522 phantom units and associated distribution equivalent rights to employees in connection with our annual incentive compensation award cycle. These awards had a grant date fair value of $9.78 and vest ratably over a three-year • In March 2019, we also issued 16,358 common units to our two independent directors in connection with their annual compensation plan. In May 2019, we issued an additional 9,580 units to an independent director in conjunction with his appointment to our Board of Directors. • In September 2019, we granted 772,200 phantom units and associated distribution equivalent rights to our Chief Executive Officer pursuant to an employment agreement executed in August 2019. These awards had a grant date fair value of $5.18 and vest ratably over a three-year service period. • During the nine months ended September 30, 2019, 572,884 phantom units vested. • As of September 30, 2019, approximately 1.8 common units remained available for future issuance under the SMLP LTIP.

RELATED-PARTY TRANSACTIONS

RELATED-PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
RELATED-PARTY TRANSACTIONS	15. RELATED-PARTY TRANSACTIONS Acquisitions. See Notes 12 and 17 of the 2018 Annual Report. Reimbursement of Expenses from General Partner. Our General Partner and its affiliates do not receive a management fee or other compensation in connection with the management of our business, but will be reimbursed for expenses incurred on our behalf. Under our Partnership Agreement, we reimburse our General Partner and its affiliates for certain expenses incurred on our behalf, including, without limitation, salary, bonus, incentive compensation and other amounts paid to our General Partner's employees and executive officers who perform services necessary to run our business. Our Partnership Agreement provides that our General Partner will determine in good faith the expenses that are allocable to us. The "Due to affiliate" line item on the consolidated balance sheet represents the payables to our General Partner for expenses incurred by it and paid on our behalf. Expenses incurred by the General Partner and reimbursed by us under our Partnership Agreement were as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Operation and maintenance expense $ 7,105 $ 7,161 $ 22,550 $ 21,898 General and administrative expense 5,844 7,220 22,809 22,818

LEASES, COMMITMENTS AND CONTING

LEASES, COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies Disclosure [Abstract]
LEASES, COMMITMENTS AND CONTINGENCIES	16. LEASES, COMMITMENTS AND CONTINGENCIES Leases. We account for leases in accordance with Topic 842, which we adopted on January 1, 2019, using the modified retrospective method. Under the modified retrospective method, the comparative information is not adjusted and is reported under the accounting standards in effect for those periods. See Note 2 for further discussion of the adoption. We and Summit Investments lease certain office space and equipment under operating leases. We lease office space for our corporate headquarters as well as for offices in and around our gathering systems for terms of between 3 and 10 years. We lease the office space to limit exposure to risks related to ownership, such as fluctuations in real estate prices. In addition, we lease equipment primarily to support our operations in response to the needs of our gathering systems for terms of between 3 and 4 years. We and Summit Investments also lease vehicles under finance leases to support our operations in response to the needs of our gathering systems for a term of 3 years. We only lease from reputable companies and our leased assets are not specialized in our industry. Some of our leases are subject to annual escalations relating to the Consumer Price Index (“CPI”). While lease liabilities are not remeasured as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which the obligation for those payments was incurred. We have options to extend the lease term of certain office space in Texas, Colorado and West Virginia. The beginning of the noncancelable lease period for these leases range from 2014 to 2018 and the lease period ends between 2020 and 2028. These lease agreements contain between one and three options to renew the lease for a period of between two and five years. As of September 30, 2019, the exercise of the renewal options for these leases are not reasonably certain and, as a result, the payments associated with these renewals are not included in the measurement of the lease liability and ROU asset. We also have options to extend the lease term of certain compression equipment used at the Summit Utica gathering system. The beginning of the noncancelable lease period for these leases is 2017 and the lease period ends in 2020. Upon expiration of the noncancelable lease period, we have the option to renew the leases on a month-to-month basis; we therefore have not included any amounts attributable to renewals in the measurement. Our leases do not contain residual value guarantees. In accordance with the provisions in our Revolving Credit Facility, our aggregate finance lease obligations cannot exceed $50 million in any period of twelve consecutive calendar months during the life of such leases. In March 2019, we entered into an agreement with a third party vendor to construct a transmission line to deliver electric power to the new 60 MMcf/d processing plant in the DJ Basin. The project is expected to cost approximately $7.8 million and we made an up-front payment of $3.0 million, which is included in the Property, plant and equipment, net caption on the unaudited condensed consolidated balance sheet. During the second quarter of 2019, we exercised an option to increase the capacity of the transmission line for an additional cost of $4.3 million and we issued an irrevocable standby letter of credit payable to the vendor with an initial term of one year totaling $9.1 million, which reflects the expected remaining cost of the project. The letter of credit will automatically renew for successive twelve month periods following the initial term, subject to certain adjustments. Once construction is complete, the letter of credit will be adjusted to reflect the final construction cost. We determined the contract contained a lease based on the right to use the constructed transmission line to power the processing plant in the DJ Basin. The project is expected to be completed and the commencement date of the ROU asset will be on or before January 2021. Our significant assumptions or judgments include the determination of whether a contract contains a lease and the discount rate used in our lease liabilities. The rate implicit in our lease contracts is not readily determinable. In determining the discount rate used in our lease liabilities, we analyzed certain factors in our incremental borrowing rate, including collateral assumptions and the term used. Our incremental borrowing rate on the Revolving Credit Facility was 5.03% at December 31, 2018, which reflects the fixed rate at which we could borrow a similar amount, for a similar term and with similar collateral as in the lease contracts at the commencement date. We adopted the following practical expedients in Topic 842 for all asset classes, which included (i) not being required to reassess whether any expired or existing contracts are or contain leases; (ii) not being required to reassess the lease classification for any expired or existing leases (that is, all existing leases that were classified as operating leases in accordance with Topic 840 will be classified as operating leases, and all existing leases that were classified as capital leases in accordance with Topic 840 will be classified as finance leases); (iii) not being required to reassess initial direct costs for any existing leases; (iv) not recognizing ROU assets and lease liabilities that arise from short-term leases of twelve months or less for any class of underlying asset; (v) not allocating consideration in a contract between lease and nonlease (e.g., maintenance services) components for our leased office space and equipment; and (vi) not evaluating existing or expired land easements that were not previously accounted for as leases under Topic 840. ROU assets (included in the Property, plant and equipment, net caption on our unaudited condensed consolidated balance sheet) and lease liabilities (included in the Other current liabilities and Other noncurrent liabilities captions on our unaudited condensed consolidated balance sheet) follow: September 30, 2019 (In thousands) ROU assets Operating $ 4,367 Finance 3,726 $ 8,093 Lease liabilities, current Operating $ 1,786 Finance 1,500 $ 3,286 Lease liabilities, noncurrent Operating $ 2,753 Finance 927 $ 3,680 Lease cost and Other information follow: Three months ended September 30, Nine months ended September 30, (In thousands) Lease cost Finance lease cost: Amortization of ROU assets (included in depreciation and amortization) $ 406 $ 1,181 Interest on lease liabilities (included in interest expense) 27 80 Operating lease cost (included in general and administrative expense) 789 2,366 $ 1,222 $ 3,627 Nine months ended September 30, 2019 (In thousands) Other information Cash paid for amounts included in the measurement of lease liabilities Operating cash outflows from operating leases $ 2,536 Operating cash outflows from finance leases 80 Financing cash outflows from finance leases 1,368 ROU assets obtained in exchange for new operating lease liabilities 1,218 ROU assets obtained in exchange for new finance lease liabilities 1,350 Weighted-average remaining lease term (years) - operating leases 5.2 Weighted-average remaining lease term (years) - finance leases 2.0 Weighted-average discount rate - operating leases 5 % Weighted-average discount rate - finance leases 4 % We recognize total lease expense incurred or allocated to us in general and administrative expenses. Lease expense related to operating leases, including lease expense incurred on our behalf and allocated to us, was as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Lease expense $ 958 $ 957 $ 2,888 $ 2,935 Future minimum lease payments due under noncancelable leases for the remainder of 2019 and each of the five succeeding fiscal years and thereafter, were as follows: September 30, 2019 (In thousands) Operating Finance 2019 $ 868 $ 433 2020 1,606 1,368 2021 1,001 640 2022 538 79 2023 400 — 2024 240 — Thereafter 895 — Total future minimum lease payments $ 5,548 $ 2,520 Future minimum lease payments due under noncancelable operating leases (under ASC 840) at December 31, 2018, were as follows: December 31, 2018 (In thousands) 2019 $ 3,133 2020 1,018 2021 550 2022 506 2023 373 Thereafter 621 Total future minimum lease payments $ 6,201 Future payments due under finance leases (under ASC 840) at December 31, 2018, were as follows: December 31, 2018 (In thousands) 2019 $ 1,473 2020 902 2021 174 Total finance lease obligations 2,549 Less: Amounts representing interest (104 ) Net present value of finance lease obligations 2,445 Less: Amount representing current portion (included in Other current liabilities) (1,406 ) Finance lease obligations, less current portion (included in Other noncurrent liabilities) $ 1,039 Environmental Matters. Although we believe that we are in material compliance with applicable environmental regulations, the risk of environmental remediation costs and liabilities are inherent in pipeline ownership and operation. Furthermore, we can provide no assurances that significant environmental remediation costs and liabilities will not be incurred by the Partnership in the future. We are currently not aware of any material contingent liabilities that exist with respect to environmental matters, except as noted below. As described in the 2018 Annual Report, in 2015, Summit Investments learned of the rupture of a four-inch produced water gathering pipeline on the Meadowlark Midstream system near Williston, North Dakota. The incident, which was covered by Summit Investments' insurance policies, was subject to maximum coverage of A rollforward of the aggregate accrued environmental remediation liabilities follows. Total (In thousands) Accrued environmental remediation, January 1, 2019 $ 5,636 Payments made (2,025 ) Additional accruals 767 Accrued environmental remediation, September 30, 2019 $ 4,378 As of September 30, 2019, we have recognized (i) a current liability for remediation effort expenditures expected to be incurred within the next 12 months and (ii) a noncurrent liability for estimated remediation expenditures and fines expected to be incurred subsequent to September 30, 2020. Each of these amounts represent our best estimate for costs expected to be incurred. Neither of these amounts has been discounted to its present value. While we cannot predict the ultimate outcome of this matter with certainty for Summit Investments or Meadowlark Midstream, especially as it relates to any material liability as a result of any governmental proceeding related to the incident, we believe at this time that it is unlikely that SMLP or its General Partner will be subject to any material liability as a result of any governmental proceeding related to the rupture. Legal Proceedings. The Partnership is involved in various litigation and administrative proceedings arising in the normal course of business. In the opinion of management, any liabilities that may result from these claims or those arising in the normal course of business would not individually or in the aggregate have a material adverse effect on the Partnership's financial position or results of operations.

DISPOSITIONS, ACQUISITIONS AND

DISPOSITIONS, ACQUISITIONS AND DROP DOWN TRANSACTIONS	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
DISPOSITIONS, ACQUISITIONS AND DROP DOWN TRANSACTIONS	17. DISPOSITIONS, ACQUISITIONS AND DROP DOWN TRANSACTIONS Tioga Midstream Disposition. In February 2019, Tioga Midstream, LLC, a subsidiary of SMLP, and certain affiliates of SMLP (collectively, “Summit”) entered into two Purchase and Sale Agreements (the “Tioga PSAs”) with Hess Infrastructure Partners LP and Hess North Dakota Pipelines LLC (collectively, “Hess Infrastructure”), pursuant to which Summit agreed to sell the Tioga Midstream system to Hess Infrastructure for a combined cash purchase price of $90 million, subject to adjustments as provided in the Tioga PSAs (the “Tioga Midstream Sale”). On March 22, 2019, Summit closed the Tioga Midstream Sale and recorded a gain on sale of $0.9 million based on the difference between the consideration received and the carrying value for Tioga Midstream at closing. The gain is included in the Gain on asset sales, net caption on the unaudited condensed consolidated statement of operations. The financial results of Tioga Midstream (a component of the Williston Basin reportable segment) are included in our unaudited condensed consolidated financial statements and footnotes for the period from January 1, 2019 through March 22, 2019. 2016 Drop Down. In 2016, SMLP acquired a controlling interest in OpCo, the entity which owns the 2016 Drop Down Assets. These assets include certain natural gas, crude oil and produced water gathering systems located in the Utica Shale, the Williston Basin and the DJ Basin, as well as ownership interests in Ohio Gathering. The net consideration paid and recognized in connection with the 2016 Drop Down (i) consisted of a cash payment to SMP Holdings of In March 2019, the Partnership amended the Contribution Agreement related to the 2016 Drop Down and fixed the Remaining Consideration at $303.5 million, with such amount to be paid by the Partnership in one or more payments over the period from March 1, 2020 through December 31, 2020, in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, at the discretion of the Partnership. At least 50% of the Remaining Consideration must be paid on or before June 30, 2020 and interest will accrue at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020. The present value of the Deferred Purchase Price Obligation is reflected as a liability on our balance sheet until paid. As of September 30, 2019, the Remaining Consideration, which reflects the net present value of the $303.5 million Deferred Purchase Price Obligation, was $295.8 million on the unaudited condensed consolidated balance sheet using a discount rate of 5.25%.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	18. SUBSEQUENT EVENTS We have evaluated subsequent events for recognition or disclosure in the unaudited condensed consolidated financial statements and no events have occurred that require recognition or disclosure, except for the following. On November 7, 2019, Summit Midstream Partners, LP (the “Partnership”) and Summit Midstream Partners Holdings, LLC (“SMP Holdings”) entered into a second amendment (the “Second Amendment”) to that certain Contribution Agreement between SMP Holdings and the Partnership dated February 25, 2016, as amended, pursuant to which the Partnership shall, on or before November 15, 2019, make a cash payment of $51.75 million and issue 10,714,285 Common Units to SMP Holdings (the “November 2019 Prepayment”). In addition, the parties have agreed to further reduce by $19.25 million the remaining portion of the consideration due to SMP Holdings under the Contribution Agreement. Following the Second Amendment and the November 2019 Prepayment, the remaining portion of the consideration due to SMP Holdings will be $180.75 million (the “Remaining Consideration”). The parties have also agreed to extend the final date by which the Partnership is obligated to deliver the Remaining Consideration to January 15, 2022. The Remaining Consideration remains payable to SMP Holdings in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, and interest continues to accrue (and is payable quarterly in cash) at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020. The form(s) of Remaining Consideration to be delivered by the Partnership to SMP Holdings continue to be determinable by the Partnership in its sole discretion. The terms of the Second Amendment were approved by the conflicts committee of the board of directors of the general partner of the Partnership, which consists entirely of independent directors . On October 18, 2019, a petition was filed in the District Court of Tarrant County, Texas by Sage Natural Resources, LLC (the “plaintiff”) against us and certain of our affiliates. The plaintiff is a party to a gathering agreement with DFW Midstream and a gas marketing agreement with Summit Midstream Marketing, LLC. In its petition, the plaintiff alleges various claims relating to the fees it was charged pursuant to the terms of these agreements, including breach of contract, fraud, fraudulent inducement, tortious interference, and negligent misrepresentation, as well as certain discriminatory rate claims under Texas law. The plaintiff seeks a rescission of the gas marketing agreement and the gas gathering agreement, as well as actual and exemplary damages and attorney’s fees. While we cannot predict the ultimate outcome of this matter with certainty, we do not believe that it is likely that we or our affiliates will be subject to any material liability as a result of this matter and are defending ourselves vigorously against the plaintiff’s claims.

SUMMARY OF SIGNIFICANT ACCOUN_2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Accounting Pronouncements	Recent Accounting Pronouncements. Accounting standard setters frequently issue new or revised accounting rules. We review new pronouncements to determine the impact, if any, on our financial statements. Accounting standards that have or could possibly have a material effect on our financial statements are discussed below. Recently Adopted Accounting Pronouncements • ASU No. 2016-02 Leases (“Topic 842"). We adopted Topic 842 with a date of initial application of January 1, 2019. We applied Topic 842 by recognizing (i) a $5.4 million right-of-use (“ROU”) asset which represents the right to use, or to control the use of, specified assets for a lease term. The ROU asset is included in the Property, plant and equipment, net caption on the unaudited condensed consolidated balance sheet; and (ii) a $5.4 million lease liability for the obligation to make lease payments arising from the leases. The lease liability is included in the Other current liabilities and Other noncurrent liabilities captions on the unaudited condensed consolidated balance sheet. The comparative information has not been adjusted and is reported under the accounting standards in effect for those periods. Refer to Note 16 for additional information. Accounting Pronouncements Pending Adoption . We have not yet adopted the following accounting pronouncement as of September 3 0 , 201 9 : • ASU No. 2018-13 Fair Value Measurement (“ASU 2018-13”). ASU 2018-13 updates the disclosure requirements on fair value measurements including new disclosures for the changes in unrealized gains and losses for the period included in other comprehensive income for recurring Level 3 fair value measurements held at the end of the reporting period and the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. ASU 2018-13 modifies existing disclosures including clarifying the measurement uncertainty disclosure. ASU 2018-13 removes certain existing disclosure requirements including the amount and reasons for transfers between Level 1 and Level 2 fair value measurements and the policy for the timing of transfer between levels. We are currently evaluating the provisions of ASU 2018-13 and expect the adoption will not have a material impact on our financial statements and related disclosures. We will adopt its provisions effective January 1, 2020.
Basis of Presentation	Presentation and Consolidation. We prepare our unaudited condensed consolidated financial statements in accordance with GAAP as established by the FASB. We make estimates and assumptions that affect the reported amounts of assets and liabilities at the balance sheet dates, including fair value measurements, the reported amounts of revenues and expenses and the disclosure of commitments and contingencies. Although management believes these estimates are reasonable, actual results could differ from its estimates. These unaudited condensed consolidated financial statements have been prepared pursuant to the rules and the regulations of the SEC. Certain information and note disclosures normally included in the annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to those rules and regulations. We believe that the disclosures made are adequate to make the information not misleading. In the opinion of management, the unaudited condensed consolidated financial statements contain all adjustments which are necessary to fairly present the unaudited condensed consolidated balance sheet as of September 30, 2019, the unaudited condensed consolidated statements of operations and statements of partners’ capital for the three and nine months ended September 30, 2019 and 2018 and the unaudited condensed consolidated statements of cash flows for the nine months ended September 30, 2019 and 2018. The balance sheet at December 31, 2018 included herein was derived from our audited financial statements, but does not include all disclosures required by GAAP. See Note 2 for the impact relating to the adoption of the new lease standard. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto that are included in our annual report on Form 10-K for the year ended December 31, 2018, as filed with the SEC on February 26, 2019 (the "2018 Annual Report"). The results of operations for an interim period are not necessarily indicative of results expected for a full year.

REVENUE (Tables)

REVENUE (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue From Contract With Customer [Abstract]
Schedule of Estimated Revenue Expected to be Recognized and MVC Shortfall Payments	The following table presents estimated revenue expected to be recognized during the remainder of 2019 and over the remaining contract period related to performance obligations that are unsatisfied and are comprised of estimated MVC shortfall payments. We applied the practical expedient in paragraph 606-10-50-14 of Topic 606 for certain arrangements that we consider optional purchases (i.e., there is no enforceable obligation for the customer to make purchases) and those amounts are therefore excluded from the table. 2019 2020 2021 2022 2023 Thereafter (In thousands) Gathering services and related fees $ 31,349 $ 120,941 $ 100,117 $ 83,673 $ 70,971 $ 113,577
Schedule of Disaggregated Revenue by Geographic Area and Major Products and Services Reportable Segments	Revenue by Category. In the following table, revenue is disaggregated by geographic area and major products and services. Ohio Gathering is excluded from the tables below due to equity method accounting. For more detailed information about reportable segments, see Note 4. Reportable Segments Three months ended September 30, 2019 Utica Shale Williston Basin DJ Basin Permian Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 8,865 $ 16,685 $ 7,039 $ 986 $ 30,120 $ 11,286 $ 5,987 $ 80,968 $ - $ 80,968 Natural gas, NGLs and condensate sales — 1,878 93 3,797 1,733 4,828 — 12,329 (110 ) 12,219 Other revenues — 2,555 735 102 1,258 1,706 — 6,356 644 7,000 Total $ 8,865 $ 21,118 $ 7,867 $ 4,885 $ 33,111 $ 17,820 $ 5,987 $ 99,653 $ 534 $ 100,187 Reportable Segments Nine months ended September 30, 2019 Utica Shale Williston Basin DJ Basin Permian Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 23,951 $ 58,076 $ 14,784 $ 1,938 $ 92,515 $ 35,739 $ 18,081 $ 245,084 $ (2,045 ) $ 243,039 Natural gas, NGLs and condensate sales — 11,231 279 10,424 6,139 11,705 — 39,778 28,660 68,438 Other revenues — 8,133 2,776 183 3,341 5,008 — 19,441 363 19,804 Total $ 23,951 $ 77,440 $ 17,839 $ 12,545 $ 101,995 $ 52,452 $ 18,081 $ 304,303 $ 26,978 $ 331,281 Reportable Segments Three months ended September 30, 2018 Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 7,974 $ 18,020 $ 2,708 $ 34,035 $ 18,318 $ 7,150 $ 88,205 $ (1,778 ) $ 86,427 Natural gas, NGLs and condensate sales — 7,953 112 3,538 789 — 12,392 21,625 34,017 Other revenues — 3,037 962 1,110 1,913 — 7,022 13 7,035 Total $ 7,974 $ 29,010 $ 3,782 $ 38,683 $ 21,020 $ 7,150 $ 107,619 $ 19,860 $ 127,479 Reportable Segments Nine months ended September 30, 2018 Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total reportable segments All other segments Total (In thousands) Major products / services lines Gathering services and related fees $ 28,437 $ 58,792 $ 7,395 $ 100,812 $ 46,035 $ 23,025 $ 264,496 $ (4,123 ) $ 260,373 Natural gas, NGLs and condensate sales — 23,149 271 12,379 1,715 — 37,514 54,511 92,025 Other revenues — 8,909 2,689 3,498 5,595 — 20,691 (107 ) 20,584 Total $ 28,437 $ 90,850 $ 10,355 $ 116,689 $ 53,345 $ 23,025 $ 322,701 $ 50,281 $ 372,982
Schedule of Information about Contract Assets from Contracts with Customers	The following table provides information about contract assets from contracts with customers: September 30, 2019 December 31, 2018 (In thousands) Contract assets, beginning of period $ 8,755 $ — Additions 15,127 26,403 Transfers out (5,836 ) (17,648 ) Contract assets, end of period $ 18,046 $ 8,755

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Schedule of assets by reportable segment	Assets by reportable segment follow. September 30,2019 December 31, 2018 (In thousands) Assets (1): Utica Shale $ 207,850 $ 207,357 Ohio Gathering 620,496 649,250 Williston Basin 445,838 526,819 DJ Basin 187,542 166,580 Permian Basin 184,386 145,702 Piceance Basin 665,489 699,638 Barnett Shale 354,173 376,564 Marcellus Shale 186,899 208,790 Total reportable segment assets 2,852,673 2,980,700 Corporate and Other 48,783 44,181 Eliminations — (4,319 ) Total assets $ 2,901,456 $ 3,020,562 (1) At September 30, 2019, Corporate and Other included $28.3 million relating to our investment in Double E (included in the Investment in equity method investees caption of the unaudited condensed consolidated balance sheet). At December 31, 2018, Corporate and Other included $9.6 million of capital expenditures relating to the Project.
Schedule of segment reporting information	Revenues by reportable segment follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Revenues (1): Utica Shale $ 8,865 $ 7,974 $ 23,951 $ 28,437 Williston Basin 21,118 29,010 77,440 90,850 DJ Basin 7,867 3,782 17,839 10,355 Permian Basin 4,885 — 12,545 — Piceance Basin 33,111 38,683 101,995 116,689 Barnett Shale 17,820 21,020 52,452 53,345 Marcellus Shale 5,987 7,150 18,081 23,025 Total reportable segments revenue 99,653 107,619 304,303 322,701 Corporate and Other 534 23,636 31,196 57,234 Eliminations — (3,776 ) (4,218 ) (6,953 ) Total revenues $ 100,187 $ 127,479 $ 331,281 $ 372,982 (1) Excludes revenues earned by Ohio Gathering due to equity method accounting. Depreciation and amortization, including the amortization expense associated with our favorable and unfavorable (for 2018) gas gathering contracts as reported in Other revenues, by reportable segment follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Depreciation and amortization (1): Utica Shale $ 1,913 $ 1,887 $ 5,744 $ 5,773 Williston Basin 4,788 5,672 14,958 16,903 DJ Basin 775 783 2,038 2,349 Permian Basin 1,312 — 3,547 — Piceance Basin 11,798 11,729 35,399 35,168 Barnett Shale (2) 4,045 3,760 12,542 11,276 Marcellus Shale 2,286 2,273 6,855 6,819 Total reportable segment depreciation and amortization 26,917 26,104 81,083 78,288 Corporate and Other 723 488 1,836 1,464 Total depreciation and amortization $ 27,640 $ 26,592 $ 82,919 $ 79,752 (1) Excludes depreciation and amortization recognized by Ohio Gathering due to equity method accounting. (2) Includes the amortization expense associated with our favorable and unfavorable (for 2018) gas gathering contracts as reported in Other revenues . Cash paid for capital expenditures by reportable segment follow. Nine months ended September 30, 2019 2018 (In thousands) Cash paid for capital expenditures (1): Utica Shale $ 2,473 $ 3,922 Williston Basin 20,288 18,463 DJ Basin 66,775 38,864 Permian Basin 43,422 67,640 Piceance Basin 1,919 5,302 Barnett Shale (2) 317 914 Marcellus Shale 347 557 Total reportable segment capital expenditures 135,541 135,662 Corporate and Other 16,122 1,371 Total cash paid for capital expenditures $ 151,663 $ 137,033 (1) Excludes cash paid for capital expenditures by Ohio Gathering due to equity method accounting. (2) For the nine months ended September 30, 2019, the amount includes sales tax reimbursements of $1.1 million.
Schedule of counterparties accounting for more than 10% of total revenues	Counterparties accounting for more than 10% of total revenues were as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Percentage of total revenues (1): Counterparty A - Piceance Basin 12 % 11 % 11 % 11 % Counterparty B - Williston Basin 10 % * 10 % * Counterparty C - Barnett Shale * 12 % * 10 % (1) Excludes revenues earned by Ohio Gathering due to equity method accounting. * Less than 10%
Reconciliation of net income to adjusted EBITDA	Segment adjusted EBITDA by reportable segment follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Reportable segment adjusted EBITDA Utica Shale $ 7,864 $ 6,521 $ 20,697 $ 24,459 Ohio Gathering 10,435 10,171 29,584 29,583 Williston Basin 13,840 19,849 49,224 54,849 DJ Basin 6,554 2,248 12,043 4,528 Permian Basin 210 — (996 ) — Piceance Basin 24,044 27,583 74,627 82,211 Barnett Shale 10,901 10,818 33,483 31,770 Marcellus Shale 4,958 5,550 14,735 18,769 Total of reportable segments' measures of profit $ 78,806 $ 82,740 $ 233,397 $ 246,169 A reconciliation of income or loss before income taxes and income or loss from equity method investees to total of reportable segments' measures of profit or loss follows. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Reconciliation of (loss) income before income taxes and loss from equity method investees to total of reportable segments' measures of profit: (Loss) income before income taxes and loss from equity method investees $ (9,947 ) $ 58,589 $ (40,183 ) $ 7,488 Add: Corporate and Other expense 7,039 9,324 28,406 28,949 Interest expense 19,335 14,862 54,803 44,821 Deferred Purchase Price Obligation 3,760 (37,204 ) 11,899 53,759 Depreciation and amortization 27,640 26,592 82,919 79,752 Proportional adjusted EBITDA for equity method investees 10,435 10,171 29,584 29,583 Adjustments related to MVC shortfall payments 3,534 (2,999 ) 2,868 (6,541 ) Adjustments related to capital reimbursement activity (145 ) (106 ) (1,906 ) 49 Unit-based and noncash compensation 1,291 1,965 5,370 6,188 (Gain) loss on asset sales, net (347 ) 6 (1,595 ) (6 ) Long-lived asset impairment — 1,540 45,021 2,127 Goodwill impairment 16,211 — 16,211 — Total of reportable segments' measures of profit $ 78,806 $ 82,740 $ 233,397 $ 246,169
Schedule of Adjustments Related to Minimum Volume Commitments Shortfall Payments	Adjustments related to MVC shortfall payments by reportable segment follow. Three months ended September 30, 2019 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ 2,081 $ — $ 1,453 $ 3,534 Three months ended September 30, 2018 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ 2,032 $ — $ (5,031 ) $ (2,999 ) Nine months ended September 30, 2019 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ (1,387 ) $ (103 ) $ 4,358 $ 2,868 Nine months ended September 30, 2018 Williston Basin Piceance Basin Barnett Shale Total (In thousands) Adjustments related to expected MVC shortfall payments: $ (1,354 ) $ (93 ) $ (5,094 ) $ (6,541 )

PROPERTY, PLANT, AND EQUIPMEN_2

PROPERTY, PLANT, AND EQUIPMENT, NET (Tables)	9 Months Ended
	Sep. 30, 2019
Property Plant And Equipment [Abstract]
Schedule of property, plant, and equipment, net	Details on property, plant and equipment follow. September 30, 2019 December 31, 2018 (In thousands) Gathering and processing systems and related equipment $ 2,161,764 $ 2,155,325 Construction in progress 98,926 137,920 Land and line fill 9,823 11,748 Other 53,283 45,853 Total 2,323,796 2,350,846 Less accumulated depreciation 424,515 387,133 Property, plant and equipment, net $ 1,899,281 $ 1,963,713
Schedule of depreciation expense and capitalized interest costs	Depreciation expense and capitalized interest follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Depreciation expense $ 19,437 $ 18,567 $ 58,049 $ 55,781 Capitalized interest 1,391 2,451 5,752 5,536

AMORTIZING INTANGIBLE ASSETS (T

AMORTIZING INTANGIBLE ASSETS (Tables)	9 Months Ended
	Sep. 30, 2019
Goodwill And Intangible Assets Disclosure [Abstract]
Intangible assets and liabilities subject to amortization	Details regarding our intangible assets, all of which are subject to amortization, follow: September 30, 2019 Gross carrying amount Accumulated amortization Net (In thousands) Favorable gas gathering contracts $ 24,195 $ (14,891 ) $ 9,304 Contract intangibles 278,448 (163,152 ) 115,296 Rights-of-way 160,460 (41,287 ) 119,173 Total intangible assets $ 463,103 $ (219,330 ) $ 243,773 December 31, 2018 Gross carrying amount Accumulated amortization Net (In thousands) Favorable gas gathering contracts $ 24,195 $ (13,905 ) $ 10,290 Contract intangibles 278,448 (143,962 ) 134,486 Rights-of-way 166,209 (37,569 ) 128,640 Total intangible assets $ 468,852 $ (195,436 ) $ 273,416
Recognized amortization expense in other revenues and cost and expenses	We recognized amortization expense in Other revenues as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Amortization expense – favorable gas gathering contracts $ (234 ) $ (389 ) $ (986 ) $ (1,166 ) We recognized amortization expense in costs and expenses as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Amortization expense – contract intangibles $ 6,396 $ 6,535 $ 19,190 $ 19,605 Amortization expense – rights-of-way 1,573 1,641 4,694 4,818
Estimated aggregate annual amortization expected to be recognized	The estimated aggregate annual amortization expected to be recognized for the remainder of 2019 and each of the four succeeding fiscal years follows. Intangible assets (In thousands) 2019 $ 8,003 2020 32,073 2021 28,381 2022 25,314 2023 25,260

EQUITY METHOD INVESTMENTS (Tabl

EQUITY METHOD INVESTMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
Equity Method Investments And Joint Ventures [Abstract]
Equity Method Investments	A reconciliation of our Investment in Ohio Gathering, September 30, 2019 $ 620,496 September cash distributions 3,478 Impairment loss 757 Basis difference (106,818 ) Investment in Ohio Gathering, net of basis difference, August 31, 2019 $ 517,913 Summarized statements of operations information for OGC and OCC follow (amounts represent 100% of investee financial information). Three months ended August 31, 2019 Three months ended August 31, 2018 OGC OCC OGC OCC (In thousands) Total revenues $ 38,097 $ 2,267 $ 37,180 $ 2,465 Total operating expenses 29,828 2,536 31,751 2,323 Net income (loss) 8,269 (268 ) 5,429 (5 ) Nine months ended August 31, 2019 Nine months ended August 31, 2018 OGC OCC OGC OCC (In thousands) Total revenues $ 106,825 $ 6,606 $ 106,263 $ 7,024 Total operating expenses 81,651 8,200 94,044 6,422 Net income (loss) 25,167 (1,594 ) 12,213 116

DEFERRED REVENUE (Tables)

DEFERRED REVENUE (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue From Contract With Customer [Abstract]
Rollforward of deferred revenue	A rollforward of current deferred revenue follows. Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total current (In thousands) Current deferred revenue, January 1, 2019 $ 18 $ 1,414 $ 739 $ 7,616 $ 1,642 $ 38 $ 11,467 Additions 14 1,779 3,020 14,650 1,235 28 20,726 Less revenue recognized 14 1,259 1,745 15,324 1,228 28 19,598 Current deferred revenue, September 30, 2019 $ 18 $ 1,934 $ 2,014 $ 6,942 $ 1,649 $ 38 $ 12,595 A rollforward of noncurrent deferred revenue follows. Utica Shale Williston Basin DJ Basin Piceance Basin Barnett Shale Marcellus Shale Total noncurrent (In thousands) Noncurrent deferred revenue, January 1, 2019 $ 21 $ 4,393 $ 7,284 $ 17,942 $ 9,628 $ 236 $ 39,504 Additions — 1,940 3,637 4,857 1,193 — 11,627 Less reclassification to current deferred revenue 14 2,225 3,020 4,775 1,235 28 11,297 Noncurrent deferred revenue, September 30, 2019 $ 7 $ 4,108 $ 7,901 $ 18,024 $ 9,586 $ 208 $ 39,834

DEBT (Tables)

DEBT (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of debt and capital leases	Debt consisted of the following: September 30, 2019 December 31, 2018 (In thousands) Summit Holdings' variable rate senior secured Revolving Credit Facility (4.80% at September 30, 2019 and 5.03% at December 31, 2018) due May 2022 $ 600,000 $ 466,000 Summit Holdings' 5.5% senior unsecured notes due August 2022 300,000 300,000 Less unamortized debt issuance costs (1) (1,801 ) (2,362 ) Summit Holdings' 5.75% senior unsecured notes due April 2025 500,000 500,000 Less unamortized debt issuance costs (1) (5,213 ) (5,907 ) Total long-term debt $ 1,392,986 $ 1,257,731 (1) Issuance costs are being amortized over the life of the notes.

FINANCIAL INSTRUMENTS (Tables)

FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Summary of the estimated fair value of debt instruments	A summary of the estimated fair value of our debt financial instruments follows. September 30, 2019 December 31, 2018 Carrying value Estimated fair value (Level 2) Carrying value Estimated fair value (Level 2) (In thousands) Summit Holdings 5.5% Senior Notes ($300.0 million principal) $ 298,199 $ 274,750 $ 297,638 $ 286,625 Summit Holdings 5.75% Senior Notes ($500.0 million principal) 494,787 423,750 494,093 455,208

PARTNERS' CAPITAL (Tables)

PARTNERS' CAPITAL (Tables)	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Schedule of partner units activity	A rollforward of the number of preferred limited partner, common limited partner and General Partner units follows. Limited partners Series A Preferred Units Common General Partner Units, January 1, 2019 300,000 73,390,853 1,490,999 Conversion of General Partner economic interests — 8,750,000 (1,490,999 ) Net units issued under the SMLP LTIP — 607,492 — Units, September 30, 2019 300,000 82,748,345 —
Details of cash distributions	Our payment of IDRs as reported in distributions to unitholders – general partner in the statement of partners' capital during the three and nine months ended September 30 follow. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) IDR payments $ — $ 2,136 $ 2,139 $ 6,400 We paid the following per-unit distributions during the three and nine months ended September 3 0 Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Per-unit distributions to unitholders $ 0.2875 $ 0.575 $ 1.1500 $ 1.725

EARNINGS PER UNIT (Tables)

EARNINGS PER UNIT (Tables)	9 Months Ended
	Sep. 30, 2019
Earnings Per Share [Abstract]
Schedule of earnings per limited partner unit	The following table details the components of EPU. Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands, except per-unit amounts) Numerator for basic and diluted EPU: Allocation of net (loss) income among limited partner interests: Net (loss) income attributable to limited partners $ (10,645 ) $ 54,151 $ (42,762 ) $ (2,948 ) Less net income attributable to Series A Preferred Units 7,125 7,125 21,375 21,375 Net (loss) income attributable to common limited partners $ (17,770 ) $ 47,026 $ (64,137 ) $ (24,323 ) Denominator for basic and diluted EPU: Weighted-average common units outstanding – basic 82,718 73,356 80,429 73,283 Effect of nonvested phantom units — 400 — — Weighted-average common units outstanding – diluted 82,718 73,756 80,429 73,283 (Loss) earnings per limited partner unit: Common unit – basic $ (0.21 ) $ 0.64 $ (0.80 ) $ (0.33 ) Common unit – diluted $ (0.21 ) $ 0.64 $ (0.80 ) $ (0.33 ) Nonvested anti-dilutive phantom units excluded from the calculation of diluted EPU 176 1 70 2

RELATED-PARTY TRANSACTIONS (Tab

RELATED-PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Schedule of related party transactions	Expenses incurred by the General Partner and reimbursed by us under our Partnership Agreement were as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Operation and maintenance expense $ 7,105 $ 7,161 $ 22,550 $ 21,898 General and administrative expense 5,844 7,220 22,809 22,818

LEASES, COMMITMENTS AND CONTI_2

LEASES, COMMITMENTS AND CONTINGENCIES (Tables)	9 Months Ended
	Sep. 30, 2019
Commitments And Contingencies Disclosure [Abstract]
Schedule of right-of-use assets and lease liabilities	ROU assets (included in the Property, plant and equipment, net caption on our unaudited condensed consolidated balance sheet) and lease liabilities (included in the Other current liabilities and Other noncurrent liabilities captions on our unaudited condensed consolidated balance sheet) follow: September 30, 2019 (In thousands) ROU assets Operating $ 4,367 Finance 3,726 $ 8,093 Lease liabilities, current Operating $ 1,786 Finance 1,500 $ 3,286 Lease liabilities, noncurrent Operating $ 2,753 Finance 927 $ 3,680
Schedule of lease cost and other information	Lease cost and Other information follow: Three months ended September 30, Nine months ended September 30, (In thousands) Lease cost Finance lease cost: Amortization of ROU assets (included in depreciation and amortization) $ 406 $ 1,181 Interest on lease liabilities (included in interest expense) 27 80 Operating lease cost (included in general and administrative expense) 789 2,366 $ 1,222 $ 3,627 Nine months ended September 30, 2019 (In thousands) Other information Cash paid for amounts included in the measurement of lease liabilities Operating cash outflows from operating leases $ 2,536 Operating cash outflows from finance leases 80 Financing cash outflows from finance leases 1,368 ROU assets obtained in exchange for new operating lease liabilities 1,218 ROU assets obtained in exchange for new finance lease liabilities 1,350 Weighted-average remaining lease term (years) - operating leases 5.2 Weighted-average remaining lease term (years) - finance leases 2.0 Weighted-average discount rate - operating leases 5 % Weighted-average discount rate - finance leases 4 %
Schedule of total rent expense related to operating leases	We recognize total lease expense incurred or allocated to us in general and administrative expenses. Lease expense related to operating leases, including lease expense incurred on our behalf and allocated to us, was as follows: Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 (In thousands) Lease expense $ 958 $ 957 $ 2,888 $ 2,935
Future minimum lease payments due and future minimum rentals to be received under noncancelable leases and subleases	Future minimum lease payments due under noncancelable leases for the remainder of 2019 and each of the five succeeding fiscal years and thereafter, were as follows: September 30, 2019 (In thousands) Operating Finance 2019 $ 868 $ 433 2020 1,606 1,368 2021 1,001 640 2022 538 79 2023 400 — 2024 240 — Thereafter 895 — Total future minimum lease payments $ 5,548 $ 2,520
Future minimum lease payments due under noncancelable operating leases	Future minimum lease payments due under noncancelable operating leases (under ASC 840) at December 31, 2018, were as follows: December 31, 2018 (In thousands) 2019 $ 3,133 2020 1,018 2021 550 2022 506 2023 373 Thereafter 621 Total future minimum lease payments $ 6,201
Schedule of Future Payments Due Under Finance Leases	Future payments due under finance leases (under ASC 840) at December 31, 2018, were as follows: December 31, 2018 (In thousands) 2019 $ 1,473 2020 902 2021 174 Total finance lease obligations 2,549 Less: Amounts representing interest (104 ) Net present value of finance lease obligations 2,445 Less: Amount representing current portion (included in Other current liabilities) (1,406 ) Finance lease obligations, less current portion (included in Other noncurrent liabilities) $ 1,039
Schedule of accrued environmental remediation	A rollforward of the aggregate accrued environmental remediation liabilities follows. Total (In thousands) Accrued environmental remediation, January 1, 2019 $ 5,636 Payments made (2,025 ) Additional accruals 767 Accrued environmental remediation, September 30, 2019 $ 4,378

ORGANIZATION, BUSINESS OPERAT_2

ORGANIZATION, BUSINESS OPERATIONS AND PRESENTATION AND CONSOLIDATION - Narrative (Details) - shares	Mar. 22, 2019	Feb. 26, 2019	Sep. 30, 2019	Dec. 31, 2018
Organization And Business Operations [Line Items]
Common limited partner capital (shares)			82,748,345	73,390,853
General Partner | Summit Midstream Partners, LP
Organization And Business Operations [Line Items]
General partner interest			2.00%
Common units | General Partner
Organization And Business Operations [Line Items]
General partner units converted		8,750,000
SMP Holdings | General Partner | Summit Midstream Partners, LP
Organization And Business Operations [Line Items]
General partner interest			2.00%
SMP Holdings | Common units
Organization And Business Operations [Line Items]
Common limited partner capital (shares)			34,604,581
SMP Holdings | Common units | Summit Midstream Partners, LP
Organization And Business Operations [Line Items]
General partner units converted	8,750,000
Summit Investments | General Partner | Summit Midstream Partners, LP
Organization And Business Operations [Line Items]
General partner interest	2.00%		2.00%
Energy Capital Partners | Common units
Organization And Business Operations [Line Items]
Common limited partner capital (shares)			5,915,827

SUMMARY OF SIGNIFICANT ACCOUN_3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Jan. 01, 2019
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Right-of-use asset	$ 4,367
Topic 842
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Right-of-use asset		$ 5,400
Operating lease liability		$ 5,400

REVENUE - Narrative1 (Details)

REVENUE - Narrative1 (Details)	Sep. 30, 2019
Maximum | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2019-01-01
Revenue From Contract With Customer [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	25 years

REVENUE - Narrative (Details)

REVENUE - Narrative (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	Dec. 31, 2017
Revenue From Contract With Customer [Line Items]
Revenue, performance obligation, description of payment terms			Our services are typically billed on a monthly basis and we do not offer extended payment terms. We do not have contracts with financing components.
Receivables with customers	$ 63,500		$ 63,500		$ 82,900
Contract assets included in accounts receivable	18,046		18,046		$ 8,755	$ 0
Gathering Services and Related Fees
Revenue From Contract With Customer [Line Items]
Contract liabilities, revenue	$ 2,400	$ 2,800	$ 7,800	$ 7,800

REVENUE - Schedule of Estimated

REVENUE - Schedule of Estimated Revenue Expected to be Recognized and MVC Shortfall Payments (Details) - Gathering Services and Related Fees $ in Thousands	Sep. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2019-10-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	3 months
Revenue, remaining performance obligation	$ 31,349
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2020-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	1 year
Revenue, remaining performance obligation	$ 120,941
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2021-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	1 year
Revenue, remaining performance obligation	$ 100,117
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2022-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	1 year
Revenue, remaining performance obligation	$ 83,673
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2023-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period	1 year
Revenue, remaining performance obligation	$ 70,971
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2024-01-01
Revenue Remaining Performance Obligation Expected Timing Of Satisfaction [Line Items]
Revenue, remaining performance obligation, expected timing of satisfaction, Period
Revenue, remaining performance obligation	$ 113,577

REVENUE - Schedule of Disaggreg

REVENUE - Schedule of Disaggregated Revenue by Geographic Area and Major Products and Services Reportable Segments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation Of Revenue [Line Items]
Total revenues	$ 100,187	$ 127,479	$ 331,281	$ 372,982
All Other Segments
Disaggregation Of Revenue [Line Items]
Total revenues	534	19,860	26,978	50,281
Reportable Segments
Disaggregation Of Revenue [Line Items]
Total revenues	99,653	107,619	304,303	322,701
Reportable Segments | Utica Shale
Disaggregation Of Revenue [Line Items]
Total revenues	8,865	7,974	23,951	28,437
Reportable Segments | Williston Basin
Disaggregation Of Revenue [Line Items]
Total revenues	21,118	29,010	77,440	90,850
Reportable Segments | DJ Basin
Disaggregation Of Revenue [Line Items]
Total revenues	7,867	3,782	17,839	10,355
Reportable Segments | Permian Basin
Disaggregation Of Revenue [Line Items]
Total revenues	4,885		12,545
Reportable Segments | Piceance Basin
Disaggregation Of Revenue [Line Items]
Total revenues	33,111	38,683	101,995	116,689
Reportable Segments | Barnett Shale
Disaggregation Of Revenue [Line Items]
Total revenues	17,820	21,020	52,452	53,345
Reportable Segments | Marcellus Shale
Disaggregation Of Revenue [Line Items]
Total revenues	5,987	7,150	18,081	23,025
Gathering Services and Related Fees
Disaggregation Of Revenue [Line Items]
Total revenues	80,968	86,427	243,039	260,373
Gathering Services and Related Fees | All Other Segments
Disaggregation Of Revenue [Line Items]
Total revenues	0	(1,778)	(2,045)	(4,123)
Gathering Services and Related Fees | Reportable Segments
Disaggregation Of Revenue [Line Items]
Total revenues	80,968	88,205	245,084	264,496
Gathering Services and Related Fees | Reportable Segments | Utica Shale
Disaggregation Of Revenue [Line Items]
Total revenues	8,865	7,974	23,951	28,437
Gathering Services and Related Fees | Reportable Segments | Williston Basin
Disaggregation Of Revenue [Line Items]
Total revenues	16,685	18,020	58,076	58,792
Gathering Services and Related Fees | Reportable Segments | DJ Basin
Disaggregation Of Revenue [Line Items]
Total revenues	7,039	2,708	14,784	7,395
Gathering Services and Related Fees | Reportable Segments | Permian Basin
Disaggregation Of Revenue [Line Items]
Total revenues	986		1,938
Gathering Services and Related Fees | Reportable Segments | Piceance Basin
Disaggregation Of Revenue [Line Items]
Total revenues	30,120	34,035	92,515	100,812
Gathering Services and Related Fees | Reportable Segments | Barnett Shale
Disaggregation Of Revenue [Line Items]
Total revenues	11,286	18,318	35,739	46,035
Gathering Services and Related Fees | Reportable Segments | Marcellus Shale
Disaggregation Of Revenue [Line Items]
Total revenues	5,987	7,150	18,081	23,025
Natural Gas, NGLs and Condensate Sales
Disaggregation Of Revenue [Line Items]
Total revenues	12,219	34,017	68,438	92,025
Natural Gas, NGLs and Condensate Sales | All Other Segments
Disaggregation Of Revenue [Line Items]
Total revenues	(110)	21,625	28,660	54,511
Natural Gas, NGLs and Condensate Sales | Reportable Segments
Disaggregation Of Revenue [Line Items]
Total revenues	12,329	12,392	39,778	37,514
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Utica Shale
Disaggregation Of Revenue [Line Items]
Total revenues	0	0	0	0
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Williston Basin
Disaggregation Of Revenue [Line Items]
Total revenues	1,878	7,953	11,231	23,149
Natural Gas, NGLs and Condensate Sales | Reportable Segments | DJ Basin
Disaggregation Of Revenue [Line Items]
Total revenues	93	112	279	271
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Permian Basin
Disaggregation Of Revenue [Line Items]
Total revenues	3,797		10,424
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Piceance Basin
Disaggregation Of Revenue [Line Items]
Total revenues	1,733	3,538	6,139	12,379
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Barnett Shale
Disaggregation Of Revenue [Line Items]
Total revenues	4,828	789	11,705	1,715
Natural Gas, NGLs and Condensate Sales | Reportable Segments | Marcellus Shale
Disaggregation Of Revenue [Line Items]
Total revenues	0	0	0	0
Other Revenues
Disaggregation Of Revenue [Line Items]
Total revenues	7,000	7,035	19,804	20,584
Other Revenues | All Other Segments
Disaggregation Of Revenue [Line Items]
Total revenues	644	13	363	(107)
Other Revenues | Reportable Segments
Disaggregation Of Revenue [Line Items]
Total revenues	6,356	7,022	19,441	20,691
Other Revenues | Reportable Segments | Utica Shale
Disaggregation Of Revenue [Line Items]
Total revenues	0	0	0	0
Other Revenues | Reportable Segments | Williston Basin
Disaggregation Of Revenue [Line Items]
Total revenues	2,555	3,037	8,133	8,909
Other Revenues | Reportable Segments | DJ Basin
Disaggregation Of Revenue [Line Items]
Total revenues	735	962	2,776	2,689
Other Revenues | Reportable Segments | Permian Basin
Disaggregation Of Revenue [Line Items]
Total revenues	102		183
Other Revenues | Reportable Segments | Piceance Basin
Disaggregation Of Revenue [Line Items]
Total revenues	1,258	1,110	3,341	3,498
Other Revenues | Reportable Segments | Barnett Shale
Disaggregation Of Revenue [Line Items]
Total revenues	1,706	1,913	5,008	5,595
Other Revenues | Reportable Segments | Marcellus Shale
Disaggregation Of Revenue [Line Items]
Total revenues	$ 0	$ 0	$ 0	$ 0

REVENUE - Schedule of Informati

REVENUE - Schedule of Information about Contract Assets from Contracts with Customers (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Contract With Customer Asset And Liability [Abstract]
Contract assets, beginning of period	$ 8,755	$ 0
Additions	15,127	26,403
Transfers out	(5,836)	(17,648)
Contract assets, end of period	$ 18,046	$ 8,755

SEGMENT INFORMATION - Assets, R

SEGMENT INFORMATION - Assets, Revenues, Depreciation and Amortization, and Capital Expenditures by Reportable Segment (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]
Assets	$ 2,901,456		$ 2,901,456		$ 3,020,562
Revenues	100,187	$ 127,479	331,281	$ 372,982
Depreciation and amortization	27,640	26,592	82,919	79,752
Capital expenditures			151,663	137,033
Reportable Segments
Segment Reporting Information [Line Items]
Assets	2,852,673		2,852,673		2,980,700
Revenues	99,653	107,619	304,303	322,701
Depreciation and amortization	26,917	26,104	81,083	78,288
Capital expenditures			135,541	135,662
Reportable Segments | Utica Shale
Segment Reporting Information [Line Items]
Assets	207,850		207,850		207,357
Revenues	8,865	7,974	23,951	28,437
Depreciation and amortization	1,913	1,887	5,744	5,773
Capital expenditures			2,473	3,922
Reportable Segments | Ohio Gathering
Segment Reporting Information [Line Items]
Assets	620,496		620,496		649,250
Reportable Segments | Williston Basin
Segment Reporting Information [Line Items]
Assets	445,838		445,838		526,819
Revenues	21,118	29,010	77,440	90,850
Depreciation and amortization	4,788	5,672	14,958	16,903
Capital expenditures			20,288	18,463
Reportable Segments | DJ Basin
Segment Reporting Information [Line Items]
Assets	187,542		187,542		166,580
Revenues	7,867	3,782	17,839	10,355
Depreciation and amortization	775	783	2,038	2,349
Capital expenditures			66,775	38,864
Reportable Segments | Barnett Shale
Segment Reporting Information [Line Items]
Assets	354,173		354,173		376,564
Revenues	17,820	21,020	52,452	53,345
Depreciation and amortization	4,045	3,760	12,542	11,276
Capital expenditures			317	914
Reportable Segments | Permian Basin
Segment Reporting Information [Line Items]
Assets	184,386		184,386		145,702
Revenues	4,885		12,545
Depreciation and amortization	1,312		3,547
Capital expenditures			43,422	67,640
Reportable Segments | Marcellus Shale
Segment Reporting Information [Line Items]
Assets	186,899		186,899		208,790
Revenues	5,987	7,150	18,081	23,025
Depreciation and amortization	2,286	2,273	6,855	6,819
Capital expenditures			347	557
Reportable Segments | Piceance Basin
Segment Reporting Information [Line Items]
Assets	665,489		665,489		699,638
Revenues	33,111	38,683	101,995	116,689
Depreciation and amortization	11,798	11,729	35,399	35,168
Capital expenditures			1,919	5,302
Corporate and Other
Segment Reporting Information [Line Items]
Assets	48,783		48,783		44,181
Revenues	534	23,636	31,196	57,234
Depreciation and amortization	$ 723	488	1,836	1,464
Capital expenditures			16,122	1,371
Eliminations
Segment Reporting Information [Line Items]
Assets					$ (4,319)
Revenues		$ (3,776)	$ (4,218)	$ (6,953)

SEGMENT INFORMATION - Narrative

SEGMENT INFORMATION - Narrative (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Segment Reporting Information [Line Items]
Equity method investment	$ 648,748		$ 649,250
Capital expenditures	151,663	$ 137,033
Corporate
Segment Reporting Information [Line Items]
Capital expenditures	700
Corporate and Other
Segment Reporting Information [Line Items]
Capital expenditures	16,122	1,371
Corporate and Other | Double E
Segment Reporting Information [Line Items]
Capital expenditures			$ 9,600
Equity method investment	28,300
Reportable Segments
Segment Reporting Information [Line Items]
Capital expenditures	135,541	135,662
Reportable Segments | Barnett Shale
Segment Reporting Information [Line Items]
Sales tax reimbursement	1,100
Capital expenditures	$ 317	$ 914

SEGMENT INFORMATION - Concentra

SEGMENT INFORMATION - Concentration Risk (Details) - Sales Revenue, Net - Customer Concentration Risk	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Counterparty A - Piceance Basin
Segment Reporting Information [Line Items]
Concentration risk, percentage	12.00%	11.00%	11.00%	11.00%
Counterparty B - Williston Basin
Segment Reporting Information [Line Items]
Concentration risk, percentage	10.00%		10.00%
Counterparty C - Barnett Shale
Segment Reporting Information [Line Items]
Concentration risk, percentage		12.00%		10.00%

SEGMENT INFORMATION - Adjusted

SEGMENT INFORMATION - Adjusted EBITDA by Reportable Segment (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Adjusted EBITDA	$ 78,806	$ 82,740	$ 233,397	$ 246,169
Utica Shale
Segment Reporting Information [Line Items]
Adjusted EBITDA	7,864	6,521	20,697	24,459
Ohio Gathering
Segment Reporting Information [Line Items]
Adjusted EBITDA	10,435	10,171	29,584	29,583
Williston Basin
Segment Reporting Information [Line Items]
Adjusted EBITDA	13,840	19,849	49,224	54,849
DJ Basin
Segment Reporting Information [Line Items]
Adjusted EBITDA	6,554	2,248	12,043	4,528
Permian Basin
Segment Reporting Information [Line Items]
Adjusted EBITDA	210		(996)
Piceance Basin
Segment Reporting Information [Line Items]
Adjusted EBITDA	24,044	27,583	74,627	82,211
Barnett Shale
Segment Reporting Information [Line Items]
Adjusted EBITDA	10,901	10,818	33,483	31,770
Marcellus Shale
Segment Reporting Information [Line Items]
Adjusted EBITDA	$ 4,958	$ 5,550	$ 14,735	$ 18,769

SEGMENT INFORMATION - Reconcili

SEGMENT INFORMATION - Reconciliation of Net Income (Loss) to Adjusted EBITDA (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting [Abstract]
(Loss) income before income taxes and loss from equity method investees	$ (9,947)	$ 58,589	$ (40,183)	$ 7,488
Add:
Corporate and Other expense	7,039	9,324	28,406	28,949
Interest expense	19,335	14,862	54,803	44,821
Deferred Purchase Price Obligation	3,760	(37,204)	11,899	53,759
Depreciation and amortization	27,640	26,592	82,919	79,752
Proportional adjusted EBITDA for equity method investees	10,435	10,171	29,584	29,583
Adjustments related to MVC shortfall payments	3,534	(2,999)	2,868	(6,541)
Adjustments related to capital reimbursement activity	(145)	(106)	(1,906)	49
Unit-based and noncash compensation	1,291	1,965	5,370	6,188
(Gain) loss on asset sales, net	(347)	6	(1,595)	(6)
Long-lived asset impairment	0	1,540	45,021	2,127
Goodwill impairment	16,211	0	16,211	0
Total of reportable segments' measures of profit	$ 78,806	$ 82,740	$ 233,397	$ 246,169

SEGMENT INFORMATION - Schedule

SEGMENT INFORMATION - Schedule of Adjustments Related to Minimum Volume Commitments Shortfall Payments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Segment Reporting Information [Line Items]
Adjustments related to MVC shortfall payments	$ 3,534	$ (2,999)	$ 2,868	$ (6,541)
Williston Basin
Segment Reporting Information [Line Items]
Adjustments related to MVC shortfall payments	2,081	2,032	(1,387)	(1,354)
Piceance Basin
Segment Reporting Information [Line Items]
Adjustments related to MVC shortfall payments			(103)	(93)
Barnett Shale
Segment Reporting Information [Line Items]
Adjustments related to MVC shortfall payments	$ 1,453	$ (5,031)	$ 4,358	$ (5,094)

PROPERTY, PLANT, AND EQUIPMEN_3

PROPERTY, PLANT, AND EQUIPMENT, NET - Schedule of Property, Plant, and Equipment, Net (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 2,323,796	$ 2,350,846
Less accumulated depreciation	424,515	387,133
Property, plant and equipment, net	1,899,281	1,963,713
Gathering and processing systems and related equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,161,764	2,155,325
Construction in progress
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	98,926	137,920
Land and line fill
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	9,823	11,748
Other
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 53,283	$ 45,853

PROPERTY, PLANT, AND EQUIPMEN_4

PROPERTY, PLANT, AND EQUIPMENT, NET - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
DJ Basin
Property, Plant and Equipment [Line Items]
Asset impairment charges	$ 34.7
Barnett Shale
Property, Plant and Equipment [Line Items]
Asset impairment charges	$ 9.7

PROPERTY, PLANT, AND EQUIPMEN_5

PROPERTY, PLANT, AND EQUIPMENT, NET - Schedule of Depreciation Expense and Capitalized Interest (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Property Plant And Equipment [Abstract]
Depreciation expense	$ 19,437	$ 18,567	$ 58,049	$ 55,781
Capitalized interest	$ 1,391	$ 2,451	$ 5,752	$ 5,536

AMORTIZING INTANGIBLE ASSETS -

AMORTIZING INTANGIBLE ASSETS - Intangible Assets and Liabilities Subject to Amortization (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$ 463,103	$ 468,852
Accumulated amortization	(219,330)	(195,436)
Net	243,773	273,416
Favorable gas gathering contracts
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	24,195	24,195
Accumulated amortization	(14,891)	(13,905)
Net	9,304	10,290
Contract intangibles
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	278,448	278,448
Accumulated amortization	(163,152)	(143,962)
Net	115,296	134,486
Rights-of-way
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	160,460	166,209
Accumulated amortization	(41,287)	(37,569)
Net	$ 119,173	$ 128,640

AMORTIZING INTANGIBLE ASSETS (N

AMORTIZING INTANGIBLE ASSETS (Narrative) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)
Rights-of-way
Finite-Lived Intangible Assets [Line Items]
Impairment charge for intangible assets	$ 0.5

AMORTIZING INTANGIBLE ASSETS _2

AMORTIZING INTANGIBLE ASSETS - Recognized Amortization Expense in Other Revenues and Cost and Expenses (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Other Revenue | Favorable gas gathering contracts
Finite-Lived Intangible Assets [Line Items]
Amortization expense	$ (234)	$ (389)	$ (986)	$ (1,166)
Costs And Expenses | Contract intangibles
Finite-Lived Intangible Assets [Line Items]
Amortization expense	6,396	6,535	19,190	19,605
Costs And Expenses | Rights-of-way
Finite-Lived Intangible Assets [Line Items]
Amortization expense	$ 1,573	$ 1,641	$ 4,694	$ 4,818

AMORTIZING INTANGIBLE ASSETS _3

AMORTIZING INTANGIBLE ASSETS - Estimated Aggregate Annual Amortization Expected to be Recognized (Details) $ in Thousands	Sep. 30, 2019USD ($)
Intangible assets
2019	$ 8,003
2020	32,073
2021	28,381
2022	25,314
2023	$ 25,260

GOODWILL - Narrative (Details)

GOODWILL - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Goodwill [Line Items]
Goodwill impairment	$ 16,211	$ 0	$ 16,211	$ 0
Mountaineer Midstream Reporting Unit [Member]
Goodwill [Line Items]
Goodwill impairment	$ 16,200		$ 16,200

EQUITY METHOD INVESTMENTS - Nar

EQUITY METHOD INVESTMENTS - Narrative (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Schedule Of Equity Method Investments [Line Items]
Asset contribution to an equity method investment				$ 23,643	$ 0
Cash distribution to partnership				7,252	0
Additional cash investments				11,300
Impairment loss		$ 677	$ 1,169	1,197	$ 3,703
Principal Owner
Schedule Of Equity Method Investments [Line Items]
Cash distribution to partnership				7,300
Double E
Schedule Of Equity Method Investments [Line Items]
Net assets	$ 28,300	28,300		28,300
Result of operations		$ 0		0
Double E | Principal Owner
Schedule Of Equity Method Investments [Line Items]
Asset contribution to an equity method investment				$ 23,600
Percentage of ownership interest	70.00%	70.00%		70.00%
Double E | JV Partner
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest	30.00%	30.00%		30.00%
Cash contribution				$ 7,300
OGC | Summit Midstream Partners, LLC
Schedule Of Equity Method Investments [Line Items]
Impairment loss	$ 757
OGC | Principal Owner
Schedule Of Equity Method Investments [Line Items]
Percentage of ownership interest	38.80%	38.80%		38.80%		40.00%

EQUITY METHOD INVESTMENTS - Rol

EQUITY METHOD INVESTMENTS - Rollforward of the Investment in Equity Method Investees (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Equity Method Investment [Roll Forward]
Investment in Ohio Gathering, September 30, 2019	$ 648,748	$ 648,748		$ 648,748
September cash distributions				28,008	$ 26,528
Impairment loss		677	$ 1,169	1,197	$ 3,703
Investment in Ohio Gathering, net of basis difference, August 31, 2019				649,250
OGC | Summit Midstream Partners, LLC
Equity Method Investment [Roll Forward]
Investment in Ohio Gathering, September 30, 2019	620,496	$ 620,496		$ 620,496
September cash distributions	3,478
Impairment loss	757
Basis difference	(106,818)
Investment in Ohio Gathering, net of basis difference, August 31, 2019	$ 517,913

EQUITY METHOD INVESTMENTS - Sta

EQUITY METHOD INVESTMENTS - Statements of Operations Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Aug. 31, 2019	Aug. 31, 2018	Aug. 31, 2019	Aug. 31, 2018
OGC
Schedule Of Equity Method Investments [Line Items]
Total revenues	$ 38,097	$ 37,180	$ 106,825	$ 106,263
Total operating expenses	29,828	31,751	81,651	94,044
Net income (loss)	8,269	5,429	25,167	12,213
OCC
Schedule Of Equity Method Investments [Line Items]
Total revenues	2,267	2,465	6,606	7,024
Total operating expenses	2,536	2,323	8,200	6,422
Net income (loss)	$ (268)	$ (5)	$ (1,594)	$ 116

DEFERRED REVENUE - Rollforward

DEFERRED REVENUE - Rollforward of deferred revenue (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	$ 11,467
Current deferred revenue, Additions	20,726
Current deferred revenue, Less revenue recognized	19,598
Current deferred revenue, ending balance	12,595
Noncurrent deferred revenue, beginning balance	39,504
Noncurrent deferred revenue, Additions	11,627
Noncurrent deferred revenue, Less reclassification to current deferred revenue	11,297
Noncurrent deferred revenue, ending balance	39,834
Utica Shale
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	18
Current deferred revenue, Additions	14
Current deferred revenue, Less revenue recognized	14
Current deferred revenue, ending balance	18
Noncurrent deferred revenue, beginning balance	21
Noncurrent deferred revenue, Additions	0
Noncurrent deferred revenue, Less reclassification to current deferred revenue	14
Noncurrent deferred revenue, ending balance	7
Williston Basin
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	1,414
Current deferred revenue, Additions	1,779
Current deferred revenue, Less revenue recognized	1,259
Current deferred revenue, ending balance	1,934
Noncurrent deferred revenue, beginning balance	4,393
Noncurrent deferred revenue, Additions	1,940
Noncurrent deferred revenue, Less reclassification to current deferred revenue	2,225
Noncurrent deferred revenue, ending balance	4,108
Piceance Basin
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	7,616
Current deferred revenue, Additions	14,650
Current deferred revenue, Less revenue recognized	15,324
Current deferred revenue, ending balance	6,942
Noncurrent deferred revenue, beginning balance	17,942
Noncurrent deferred revenue, Additions	4,857
Noncurrent deferred revenue, Less reclassification to current deferred revenue	4,775
Noncurrent deferred revenue, ending balance	18,024
DJ Basin
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	739
Current deferred revenue, Additions	3,020
Current deferred revenue, Less revenue recognized	1,745
Current deferred revenue, ending balance	2,014
Noncurrent deferred revenue, beginning balance	7,284
Noncurrent deferred revenue, Additions	3,637
Noncurrent deferred revenue, Less reclassification to current deferred revenue	3,020
Noncurrent deferred revenue, ending balance	7,901
Barnett Shale
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	1,642
Current deferred revenue, Additions	1,235
Current deferred revenue, Less revenue recognized	1,228
Current deferred revenue, ending balance	1,649
Noncurrent deferred revenue, beginning balance	9,628
Noncurrent deferred revenue, Additions	1,193
Noncurrent deferred revenue, Less reclassification to current deferred revenue	1,235
Noncurrent deferred revenue, ending balance	9,586
Marcellus Shale
Movement in Deferred Revenue [Roll Forward]
Current deferred revenue, beginning balance	38
Current deferred revenue, Additions	28
Current deferred revenue, Less revenue recognized	28
Current deferred revenue, ending balance	38
Noncurrent deferred revenue, beginning balance	236
Noncurrent deferred revenue, Additions	0
Noncurrent deferred revenue, Less reclassification to current deferred revenue	28
Noncurrent deferred revenue, ending balance	$ 208

DEBT - Components of Long-Term

DEBT - Components of Long-Term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Total long-term debt	$ 1,392,986	$ 1,257,731
SMP Holdings
Line of Credit Facility [Line Items]
Total long-term debt	1,392,986	1,257,731
SMP Holdings | Senior Secured Revolving Credit Facility Due May 2022
Line of Credit Facility [Line Items]
Revolving credit facility	600,000	466,000
SMP Holdings | Senior Notes Due August 2022
Line of Credit Facility [Line Items]
Unsecured notes	300,000	300,000
Less unamortized debt issuance costs	(1,801)	(2,362)
SMP Holdings | Senior Notes Due April 2025
Line of Credit Facility [Line Items]
Unsecured notes	500,000	500,000
Less unamortized debt issuance costs	$ (5,213)	$ (5,907)

DEBT - Components of Long-Ter_2

DEBT - Components of Long-Term Debt (Parenthetical) (Details) - SMP Holdings	Sep. 30, 2019	Dec. 31, 2018
Senior Secured Revolving Credit Facility Due May 2022
Line of Credit Facility [Line Items]
Variable interest rate	4.80%	5.03%
Senior Notes Due August 2022
Line of Credit Facility [Line Items]
Stated interest rate	5.50%	5.50%
Senior Notes Due April 2025
Line of Credit Facility [Line Items]
Stated interest rate	5.75%	5.75%

DEBT - Revolving Credit Facilit

DEBT - Revolving Credit Facility (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2019	Jun. 30, 2019
Line of Credit Facility [Line Items]
Line of credit facility, outstanding amount		$ 9,100,000
Revolving credit facility
Line of Credit Facility [Line Items]
Borrowing capacity	$ 1,250,000,000
Revolving credit facility maturity date	2022-05
Accordion feature	$ 250,000,000
Commitment fee on unused portion of the facility	0.50%
Interest rate at period end	4.80%
Unused portion under the facility	$ 640,900,000
Line of credit facility, outstanding amount	9,100,000
Debt issuance costs	6,900,000
Debt defaults	$ 0
Revolving credit facility | LIBOR
Line of Credit Facility [Line Items]
Applicable margin	2.75%
Revolving credit facility | Minimum
Line of Credit Facility [Line Items]
Commitment fee on unused portion of the facility	0.30%
Revolving credit facility | Minimum | ABR
Line of Credit Facility [Line Items]
Applicable margin	0.75%
Revolving credit facility | Minimum | LIBOR
Line of Credit Facility [Line Items]
Applicable margin	1.75%
Revolving credit facility | Maximum
Line of Credit Facility [Line Items]
Commitment fee on unused portion of the facility	0.50%
Revolving credit facility | Maximum | ABR
Line of Credit Facility [Line Items]
Applicable margin	1.75%
Revolving credit facility | Maximum | LIBOR
Line of Credit Facility [Line Items]
Applicable margin	2.75%

DEBT - Senior Notes (Narrative)

DEBT - Senior Notes (Narrative) (Details) - USD ($)	1 Months Ended
	Nov. 30, 2018	Feb. 28, 2017	Jul. 31, 2014
Guarantor Subsidiaries
Debt Instrument [Line Items]
Cumulative percentage ownership in subsidiary	100.00%
5.75% Senior Notes
Debt Instrument [Line Items]
Stated interest rate		5.75%	5.75%
Maturity date		Apr. 15, 2025
Debt face amount		$ 500,000,000
Summit Holdings and Finance Corporation | Senior Notes Due August 2022
Debt Instrument [Line Items]
Senior unsecured notes			$ 300,000,000
Stated interest rate			5.50%
Maturity date			Aug. 15, 2022
Finance Corp | Summit Holdings
Debt Instrument [Line Items]
Cumulative percentage ownership in subsidiary			100.00%

FINANCIAL INSTRUMENTS - Concent

FINANCIAL INSTRUMENTS - Concentration Risk - Narrative (Details) - Customer	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
CONCENTRATIONS OF RISK
Number of top customers	5
Five Largest Customers | Accounts receivable | Customer Concentration Risk
CONCENTRATIONS OF RISK
Concentration risk, percentage	49.00%	39.00%

FINANCIAL INSTRUMENTS - Fair Va

FINANCIAL INSTRUMENTS - Fair Value - Narrative (Details) - Drop Down Assets 2016 Acquisition - USD ($) $ in Millions	Mar. 31, 2020	Mar. 03, 2016	Jun. 30, 2020	Feb. 26, 2019
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Payments to Acquire Businesses, Gross		$ 360
Remaining cash consideration payable			$ 303.5	$ 303.5
Scenario Forecast
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Annual accrued Interest rate on unpaid consideration	8.00%
Scenario Forecast | Minimum
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Minimum remaining consideration to be paid percentage			50.00%

FINANCIAL INSTRUMENTS - Fair _2

FINANCIAL INSTRUMENTS - Fair value of Debt Instruments (Details) - Summit Holdings - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Carrying value | 5.5% Senior Notes
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Senior notes	$ 298,199	$ 297,638
Carrying value | 5.75% Senior Notes
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Senior notes	494,787	494,093
Fair Value | 5.5% Senior Notes | Estimated fair value (Level 2)
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Senior notes	274,750	286,625
Fair Value | 5.75% Senior Notes | Estimated fair value (Level 2)
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Senior notes	$ 423,750	$ 455,208

FINANCIAL INSTRUMENTS - Fair _3

FINANCIAL INSTRUMENTS - Fair value of Debt Instruments (Parenthetical) (Details) - Summit Holdings - USD ($)	Sep. 30, 2019	Dec. 31, 2018
5.5% Senior Notes
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Stated interest rate	5.50%	5.50%
Debt face amount	$ 300,000,000	$ 300,000,000
5.75% Senior Notes
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Stated interest rate	5.75%	5.75%
Debt face amount	$ 500,000,000	$ 500,000,000

PARTNERS' CAPITAL - Partners' C

PARTNERS' CAPITAL - Partners' Capital and Schedule of Units (Details)	9 Months Ended
	Sep. 30, 2019shares
Series A Preferred Units
Rollforwards of the number of partner units
Units, beginning balance (in shares)	300,000
Conversion of General Partner economic interests (in shares)	0
Net units issued under the SMLP LTIP (in shares)	0
Units, ending balance (in shares)	300,000
Common
Rollforwards of the number of partner units
Units, beginning balance (in shares)	73,390,853
Conversion of General Partner economic interests (in shares)	8,750,000
Net units issued under the SMLP LTIP (in shares)	607,492
Units, ending balance (in shares)	82,748,345
General Partner Units
Rollforwards of the number of partner units
Units, beginning balance (in shares)	1,490,999
Conversion of General Partner economic interests (in shares)	(1,490,999)
Net units issued under the SMLP LTIP (in shares)	0
Units, ending balance (in shares)	0

PARTNERS' CAPITAL - Narrative (

PARTNERS' CAPITAL - Narrative (Details) $ / shares in Units, $ in Thousands	Oct. 24, 2019USD ($)$ / shares	Mar. 22, 2019USD ($)shares	Feb. 26, 2019shares	Sep. 30, 2019USD ($)Transaction$ / sharesshares	Mar. 31, 2019USD ($)	Sep. 30, 2018$ / shares	Sep. 30, 2019USD ($)Transaction$ / sharesshares	Sep. 30, 2018$ / shares	Dec. 31, 2018shares	Dec. 31, 2017USD ($)$ / sharesshares
Partners Capital [Line Items]
Fair value					$ 0
Surplus in excess (in dollars per share) | $ / shares						$ 0.46		$ 0.46
Preferred units issued | shares				300,000			300,000		300,000
Per-unit annual distributions to unitholders (in dollars per unit) | $ / shares				$ 0.2875		$ 0.575	$ 1.1500	$ 1.725
Subsequent Event
Partners Capital [Line Items]
Per-unit annual distributions to unitholders (in dollars per unit) | $ / shares	$ 0.2875
Cash paid to unit holders	$ 23,800
Cash distribution date	Nov. 14, 2019
Cash distribution date of record	Nov. 7, 2019
Series A Preferred Units
Partners Capital [Line Items]
Preferred units issued | shares										300,000
Interest in partnership per unit | $ / shares										$ 1,000
Summit Midstream Partners, LP | Common units | SMP Holdings
Partners Capital [Line Items]
General partner units converted | shares		8,750,000
Fair value		$ 84,500
General Partner
Partners Capital [Line Items]
Fair value					(22,222)
Percentage interest in distributions (maximum)						50.00%		50.00%
General Partner | Common units
Partners Capital [Line Items]
General partner units converted | shares			8,750,000
General Partner | Summit Midstream Partners, LP
Partners Capital [Line Items]
General partner interest							2.00%
General Partner | Summit Midstream Partners, LP | SMP Holdings
Partners Capital [Line Items]
General partner interest							2.00%
Limited Partner | Summit Midstream Partners, LP | SMP Holdings
Partners Capital [Line Items]
Limited partner interest ownership percentage							41.80%
Limited Partner | Summit Midstream Partners, LP | Affiliate of Energy Capital Partners II, LLC
Partners Capital [Line Items]
Limited partner interest ownership percentage							7.20%
Common
Partners Capital [Line Items]
General partner units converted | shares							8,750,000
Fair value					$ 22,222
Common | Public Offering
Partners Capital [Line Items]
Aggregate offering price										$ 150,000
Transactions under ATM Program | Transaction				0			0
Aggregate offering price				$ 132,300			$ 132,300

PARTNERS' CAPITAL - Incentive D

PARTNERS' CAPITAL - Incentive Distribution Rights (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Equity [Abstract]
IDR payments	$ 2,136	$ 2,139	$ 6,400

PARTNERS' CAPITAL - Cash Distri

PARTNERS' CAPITAL - Cash Distributions Paid and Declared (Details) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Equity [Abstract]
Per-unit annual distributions to unitholders (in dollars per unit)	$ 0.2875	$ 0.575	$ 1.1500	$ 1.725

EARNINGS PER UNIT (Details)

EARNINGS PER UNIT (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Net (loss) income attributable to limited partners	$ (10,645)	$ 54,151	$ (42,762)	$ (2,948)
Phantom Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Effect of nonvested phantom units		400
(Loss) income per limited partner unit:
Nonvested anti-dilutive phantom units excluded from the calculation of diluted EPU	176	1	70	2
Series A Preferred Units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Net (loss) income attributable to limited partners	$ 7,125	$ 7,125	$ 21,375	$ 21,375
Common units
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Net (loss) income attributable to limited partners	$ (17,770)	$ 47,026	$ (64,137)	$ (24,323)
Weighted-average common units outstanding – basic	82,718	73,356	80,429	73,283
Weighted-average common units outstanding – diluted	82,718	73,756	80,429	73,283
Common unit – basic	$ (0.21)	$ 0.64	$ (0.80)	$ (0.33)
Common unit – diluted	$ (0.21)	$ 0.64	$ (0.80)	$ (0.33)

UNIT-BASED AND NONCASH COMPEN_2

UNIT-BASED AND NONCASH COMPENSATION - Narrative (Details)	1 Months Ended			9 Months Ended
	Sep. 30, 2019$ / sharesshares	May 31, 2019shares	Mar. 31, 2019Director$ / sharesshares	Sep. 30, 2019shares
SMLP LTIP
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted units (in shares)		9,580
Issued units (in shares)			16,358
No. of directors | Director			2
Units remaining available	1,800,000			1,800,000
Phantom Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted units (in shares)	772,200
Grant date fair value (in dollars per share) | $ / shares	$ 5.18
Vesting period	3 years
Phantom Units | SMLP LTIP
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted units (in shares)			639,522
Grant date fair value (in dollars per share) | $ / shares			$ 9.78
Vesting period			3 years
Units vested (in shares)				572,884

RELATED-PARTY TRANSACTIONS - Ex

RELATED-PARTY TRANSACTIONS - Expenses Incurred by the General Partner and Reimbursed (Details) - General Partner - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Operation and maintenance expense
RELATED-PARTY TRANSACTIONS
Expenses from transactions with related party	$ 7,105	$ 7,161	$ 22,550	$ 21,898
General and administrative expense
RELATED-PARTY TRANSACTIONS
Expenses from transactions with related party	$ 5,844	$ 7,220	$ 22,809	$ 22,818

LEASES, COMMITMENTS AND CONTI_3

LEASES, COMMITMENTS AND CONTINGENCIES - Narrative (Details)	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Mar. 31, 2019USD ($)MMcf	Jun. 30, 2019USD ($)	Sep. 30, 2019USD ($)Agreement	Dec. 31, 2015USD ($)
Loss Contingencies [Line Items]
Finance leases, term of contract			3 years
Lessee, operating lease, existence of residual value guarantee [true false]			false
Lessee, operating lease, residual value guarantee, Description			Our leases do not contain residual value guarantees.
Lessee, operating lease, assumptions and judgments, whether contract is or contains lease			Our significant assumptions or judgments include the determination of whether a contract contains a lease and the discount rate used in our lease liabilities.
Lessee, operating lease, assumptions and judgments, discount rate, description			The rate implicit in our lease contracts is not readily determinable. In determining the discount rate used in our lease liabilities, we analyzed certain factors in our incremental borrowing rate, including collateral assumptions and the term used. Our incremental borrowing rate on the Revolving Credit Facility was 5.03% at December 31, 2018, which reflects the fixed rate at which we could borrow a similar amount, for a similar term and with similar collateral as in the lease contracts at the commencement date.
Electric power | MMcf	60
Cost of project	$ 7,800,000
Up front payment included in property, plant and equipment	$ 3,000,000
Letter of credit initial term		1 year
Irrevocable letter of credit payable		$ 9,100,000
Letter of credit renew term		12 months
Transmission Line
Loss Contingencies [Line Items]
Additional cost to increase transmission line capacity		$ 4,300,000
Revolving credit facility
Loss Contingencies [Line Items]
Finance operating Lease obligations not exceed consolidated total assets			$ 50,000,000
Percentage of operating lease incremental borrowing rate			5.03%
Irrevocable letter of credit payable			$ 9,100,000
Office Space
Loss Contingencies [Line Items]
Lessee, operating lease, existence of option to extend [true false]			true
Lessee, operating lease, option to extend			We have options to extend the lease term of certain office space in Texas, Colorado and West Virginia. The beginning of the noncancelable lease period for these leases range from 2014 to 2018 and the lease period ends between 2020 and 2028. These lease agreements contain between one and three options to renew the lease for a period of between two and five years. As of September 30, 2019, the exercise of the renewal options for these leases are not reasonably certain and, as a result, the payments associated with these renewals are not included in the measurement of the lease liability and ROU asset.
Equipment
Loss Contingencies [Line Items]
Lessee, operating lease, option to extend			We also have options to extend the lease term of certain compression equipment used at the Summit Utica gathering system. The beginning of the noncancelable lease period for these leases is 2017 and the lease period ends in 2020. Upon expiration of the noncancelable lease period, we have the option to renew the leases on a month-to-month basis; we therefore have not included any amounts attributable to renewals in the measurement.
Minimum | Office Space
Loss Contingencies [Line Items]
Operating leases, term of contract			3 years
Operating lease, number of renewal terms | Agreement			1
Lease agreements renewal periods			2 years
Minimum | Equipment
Loss Contingencies [Line Items]
Operating leases, term of contract			3 years
Maximum | Meadowlark Midstream Gathering System | Principal Owner
Loss Contingencies [Line Items]
Coverage from pollution liability insurance policy			$ 25,000,000	$ 25,000,000
Coverage from property and business interruption insurance policy			$ 200,000,000
Maximum | Office Space
Loss Contingencies [Line Items]
Operating leases, term of contract			10 years
Operating lease, number of renewal terms | Agreement			3
Lease agreements renewal periods			5 years
Maximum | Equipment
Loss Contingencies [Line Items]
Operating leases, term of contract			4 years

LEASES, COMMITMENTS AND CONTI_4

LEASES, COMMITMENTS AND CONTINGENCIES - Schedule of Right of Use Assets and Lease Liabilities (Details) $ in Thousands	Sep. 30, 2019USD ($)
Commitments And Contingencies Disclosure [Abstract]
Right-of-use asset	$ 4,367
Finance	3,726
Total	8,093
Lease liabilities, current
Operating	1,786
Finance	1,500
Total	3,286
Lease liabilities, noncurrent
Operating	2,753
Finance	927
Total	$ 3,680

LEASES, COMMITMENTS AND CONTI_5

LEASES, COMMITMENTS AND CONTINGENCIES - Schedule of Lease Cost and Other Information (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Lease cost
Amortization of ROU assets (included in depreciation and amortization)	$ 406	$ 1,181
Interest on lease liabilities (included in interest expense)	27	80
Operating lease cost (included in general and administrative expense)	789	2,366
Total lease cost	$ 1,222	3,627
Other information
Operating cash outflows from operating leases		2,536
Operating cash outflows from finance leases		80
Financing cash outflows from finance leases		1,368
ROU assets obtained in exchange for new operating lease liabilities		1,218
ROU assets obtained in exchange for new finance lease liabilities		$ 1,350
Weighted-average remaining lease term (years) - operating leases	5 years 2 months 12 days	5 years 2 months 12 days
Weighted-average remaining lease term (years) - finance leases	2 years	2 years
Weighted-average discount rate - operating leases	5.00%	5.00%
Weighted-average discount rate - finance leases	4.00%	4.00%

LEASES, COMMITMENTS AND CONTI_6

LEASES, COMMITMENTS AND CONTINGENCIES - Rent Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Commitments And Contingencies Disclosure [Abstract]
Lease expense	$ 958	$ 957	$ 2,888	$ 2,935

LEASES, COMMITMENTS AND CONTI_7

LEASES, COMMITMENTS AND CONTINGENCIES - Future Minimum Lease Payments Due and Future Minimum Rentals to be Received under Noncancelable Leases (Details) $ in Thousands	Sep. 30, 2019USD ($)
Commitments And Contingencies Disclosure [Abstract]
Operating lease, Future minimum lease payments, 2019	$ 868
Operating lease, Future minimum lease payments, 2020	1,606
Operating lease, Future minimum lease payments, 2021	1,001
Operating lease, Future minimum lease payments, 2022	538
Operating lease, Future minimum lease payments, 2023	400
Operating lease, Future minimum lease payments, 2024	240
Operating lease, Future minimum lease payments, Thereafter	895
Operating lease, Total future minimum lease payments	5,548
Finance lease, Future minimum lease payments, 2019	433
Finance lease, Future minimum lease payments, 2020	1,368
Finance lease, Future minimum lease payments, 2021	640
Finance lease, Future minimum lease payments, 2022	79
Finance lease, Future minimum lease payments, 2023	0
Finance lease, Future minimum lease payments, 2024	0
Finance lease, Future minimum lease payments, Thereafter	0
Finance lease, Total future minimum lease payments	$ 2,520

LEASES, COMMITMENTS AND CONTI_8

LEASES, COMMITMENTS AND CONTINGENCIES - Schedule of Future Minimum Rental Payments for Operating Leases (Details) $ in Thousands	Dec. 31, 2018USD ($)
Commitments And Contingencies Disclosure [Abstract]
2019	$ 3,133
2020	1,018
2021	550
2022	506
2023	373
Thereafter	621
Total future minimum lease payments	$ 6,201

LEASES, COMMITMENTS AND CONTI_9

LEASES, COMMITMENTS AND CONTINGENCIES - Schedule of Future Payments Due Under Finance Leases (Details) $ in Thousands	Dec. 31, 2018USD ($)
Commitments And Contingencies Disclosure [Abstract]
2019	$ 1,473
2020	902
2021	174
Total finance lease obligations	2,549
Less: Amounts representing interest	(104)
Net present value of finance lease obligations	2,445
Less: Amount representing current portion (included in Other current liabilities)	(1,406)
Finance lease obligations, less current portion (included in Other noncurrent liabilities)	$ 1,039

LEASES, COMMITMENTS AND CONT_10

LEASES, COMMITMENTS AND CONTINGENCIES - Environmental Matters (Details) - Meadowlark Midstream Gathering System $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)
Accrual for Environmental Loss Contingencies [Roll Forward]
Accrued environmental remediation, beginning balance	$ 5,636
Payments made	(2,025)
Additional accruals	767
Accrued environmental remediation, ending balance	$ 4,378

DISPOSITIONS, ACQUISITIONS AN_2

DISPOSITIONS, ACQUISITIONS AND DROP DOWN TRANSACTIONS - Tioga Midstream Disposition (Details) - Tioga Midstream, LLC - Disposal, not discontinued operations $ in Millions	1 Months Ended
	Feb. 28, 2019USD ($)Agreement
Business Acquisition [Line Items]
Number of purchase and sale agreements | Agreement	2
Combined cash purchase price of disposals	$ 90
Gain on sale of business	$ 0.9

DISPOSITIONS, ACQUISITIONS AN_3

DISPOSITIONS, ACQUISITIONS AND DROP DOWN TRANSACTIONS - 2016 Drop Down (Details) - Drop Down Assets 2016 Acquisition - USD ($) $ in Millions	Mar. 31, 2020	Mar. 03, 2016	Jun. 30, 2016	Mar. 31, 2019	Sep. 30, 2019	Jun. 30, 2020	Feb. 26, 2019
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross		$ 360
Working capital adjustment			$ 0.6
Remaining cash consideration payable						$ 303.5	$ 303.5
Remaining consideration description				Remaining Consideration at $303.5 million, with such amount to be paid by the Partnership in one or more payments over the period from March 1, 2020 through December 31, 2020, in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, at the discretion of the Partnership. At least 50% of the Remaining Consideration must be paid on or before June 30, 2020 and interest will accrue at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020	the remaining portion of the consideration due to SMP Holdings will be $180.75 million (the “Remaining Consideration”). The parties have also agreed to extend the final date by which the Partnership is obligated to deliver the Remaining Consideration to January 15, 2022. The Remaining Consideration remains payable to SMP Holdings in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, and interest continues to accrue (and is payable quarterly in cash) at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020.
Estimated future payment obligation					$ 295.8
Deferred purchase price obligation					$ 303.5
Discount rate					5.25%
Scenario Forecast
Business Acquisition [Line Items]
Annual accrued Interest rate on unpaid consideration	8.00%
Scenario Forecast | Minimum
Business Acquisition [Line Items]
Minimum remaining consideration to be paid percentage						50.00%

SUBSEQUENT EVENTS - Narrative (

SUBSEQUENT EVENTS - Narrative (Details) - Drop Down Assets 2016 Acquisition - USD ($) $ in Thousands	Mar. 31, 2020	Nov. 07, 2019	Mar. 03, 2016	Mar. 31, 2019	Sep. 30, 2019	Jun. 30, 2020	Feb. 26, 2019
Subsequent Event [Line Items]
Payments to Acquire Businesses, Gross			$ 360,000
Remaining cash consideration payable						$ 303,500	$ 303,500
Remaining consideration description				Remaining Consideration at $303.5 million, with such amount to be paid by the Partnership in one or more payments over the period from March 1, 2020 through December 31, 2020, in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, at the discretion of the Partnership. At least 50% of the Remaining Consideration must be paid on or before June 30, 2020 and interest will accrue at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020	the remaining portion of the consideration due to SMP Holdings will be $180.75 million (the “Remaining Consideration”). The parties have also agreed to extend the final date by which the Partnership is obligated to deliver the Remaining Consideration to January 15, 2022. The Remaining Consideration remains payable to SMP Holdings in (i) cash, (ii) the Partnership’s common units or (iii) a combination of cash and the Partnership’s common units, and interest continues to accrue (and is payable quarterly in cash) at a rate of 8% per annum on any portion of the Remaining Consideration that remains unpaid after March 31, 2020.
Scenario Forecast
Subsequent Event [Line Items]
Annual accrued Interest rate on unpaid consideration	8.00%
Subsequent Event
Subsequent Event [Line Items]
Payments to Acquire Businesses, Gross		$ 51,750
Business acquisition, reduced amount of consideration		19,250
Remaining cash consideration payable		$ 180,750
Subsequent Event | Common units
Subsequent Event [Line Items]
Business acquisition, share issued (shares)		10,714,285