Summit Midstream Partners, LP - Quarter Report: 2022 June (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)


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

For the quarterly period ended June 30, 2022


o			TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number: 001-35666

Summit Midstream Partners, LP

(Exact name of registrant as specified in its charter)

Delaware

(State or other jurisdiction of

incorporation or organization)

910 Louisiana Street, Suite 4200

Houston, TX

(Address of principal executive offices)

45-5200503

(I.R.S. Employer

Identification No.)

77002

(Zip Code)

(832) 413-4770

(Registrant’s telephone number, including area code)

Not applicable

(Former name, former address and former fiscal year, if changed since last report)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Units	SMLP	New York Stock Exchange

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

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).


x			Yes			o			No

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


Large accelerated filer	☐	Accelerated filer	x
Non-accelerated filer	☐	Smaller reporting company	x
Emerging growth company	☐

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

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.


Class						As of July 29, 2022
Common Units						10,166,175 units

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TABLE OF CONTENTS


COMMONLY USED OR DEFINED TERMS		2

PART I	FINANCIAL INFORMATION
Item 1.	Financial Statements.
	Unaudited Condensed Consolidated Balance Sheets.	5
	Unaudited Condensed Consolidated Statements of Operations.	6
	Unaudited Condensed Consolidated Statements of Partners' Capital.	7
	Unaudited Condensed Consolidated Statements of Cash Flows.	8
	Notes to Unaudited Condensed Consolidated Financial Statements.	9
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.	22
Item 3.	Quantitative and Qualitative Disclosures about Market Risk.	41
Item 4.	Controls and Procedures.	41
PART II	OTHER INFORMATION	42
Item 1.	Legal Proceedings.	42
Item 1A.	Risk Factors.	42
Item 5.	Other Information.	42
Item 6.	Exhibits.	42

SIGNATURES		44

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COMMONLY USED OR DEFINED TERMS



2015 Blacktail Release			a 2015 rupture of our four-inch produced water gathering pipeline near Williston, North Dakota
2022 Senior Notes			Summit Holdings' and Finance Corp.’s 5.5% senior unsecured notes due August 2022
2025 Senior Notes			Summit Holdings' and Finance Corp.’s 5.75% senior unsecured notes due April 2025

2026 Secured Notes			Summit Holdings' and Finance Corp.’s 8.500% senior secured second lien notes due 2026

ABL Facility			the asset-based lending credit facility governed by the ABL Agreement
ABL Agreement			Loan and Security Agreement, dated as of November 2, 2021, among Summit Holdings, as borrower, SMLP and certain subsidiaries from time to time party thereto, as guarantors, Bank of America, N.A., as agent, ING Capital LLC, Royal Bank of Canada and Regions Bank, as co-syndication agents, and Bank of America, N.A., ING Capital LLC, RBC Capital Markets and Regions Capital Markets, as joint lead arrangers and joint bookrunners
ASU			Accounting Standards Update
Bison Midstream			Bison Midstream, LLC
Board of Directors			the board of directors of our General Partner

condensate			a natural gas liquid with a low vapor pressure, mainly composed of propane, butane, pentane and heavier hydrocarbon fractions

Co-Issuers			Summit Holdings and Finance Corp.
DFW Midstream			DFW Midstream Services LLC
DJ Basin			Denver-Julesburg Basin
Double E			Double E Pipeline, LLC
Double E Pipeline			a 135 mile, 1.35 Bcf/d, FERC-regulated interstate natural gas transmission pipeline that commenced operations in November 2021 and provides transportation service from receipt points in the Delaware Basin to various delivery points in and around the Waha hub in Texas

Double E Project			the development and construction of the Double E Pipeline
ECP			Energy Capital Partners II, LLC and its parallel and co-investment funds
EPA			Environmental Protection Agency
Epping			Epping Transmission Company, LLC
EPU			earnings or loss per unit
FASB			Financial Accounting Standards Board
Finance Corp.			Summit Midstream Finance Corp.
GAAP			accounting principles generally accepted in the United States of America
General Partner			Summit Midstream GP, LLC
GP			general partner
GP Buy-In Transaction			the transactions contemplated by the Purchase Agreement dated May 3, 2020, between the Partnership and the affiliates of its then private equity sponsor, ECP, to acquire Summit Investments
Grand River			Grand River Gathering, LLC
Guarantor Subsidiaries			Bison Midstream and its subsidiaries, Grand River and its subsidiaries, DFW Midstream, Summit Marketing, Summit Permian, Permian Finance, OpCo, Summit Utica, Meadowlark Midstream, Summit Permian II and Mountaineer Midstream
Hub			geographic location of a storage facility and multiple pipeline interconnections

LIBOR			London Interbank Offered Rate
Mbbl/d			one thousand barrels per day
MD&A			Management's Discussion and Analysis of Financial Condition and Results of Operations
Meadowlark Midstream			Meadowlark Midstream Company, LLC
MMBTU			metric million British thermal units
MMcf/d			one million cubic feet per day
Mountaineer Midstream			Mountaineer Midstream Company, LLC

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MVC			minimum volume commitment
NGLs			natural gas liquids; the combination of ethane, propane, normal butane, iso-butane and natural gasolines that when removed from unprocessed natural gas streams become liquid under various levels of higher pressure and lower temperature

NYSE			New York Stock Exchange


Ohio Gathering			Ohio Gathering Company, L.L.C. and Ohio Condensate Company, L.L.C.
OpCo			Summit Midstream OpCo, LP
play			a proven geological formation that contains commercial amounts of hydrocarbons
Permian Finance			Summit Midstream Permian Finance, LLC
Permian Holdco			Summit Permian Transmission Holdco, LLC
Permian Term Loan Facility			the term loan governed by the Credit Agreement, dated as of March 8, 2021, among Summit Permian Transmission, LLC, as borrower, MUFG Bank Ltd., as administrative agent, Mizuho Bank (USA), as collateral agent, ING Capital LLC, Mizuho Bank, Ltd. and MUFG Union Bank, N.A., as L/C issuers, coordinating lead arrangers and joint bookrunners, and the lenders from time to time party thereto
Permian Transmission Credit Facilities			the credit facilities governed by the Credit Agreement, dated as of March 8, 2021, among Summit Permian Transmission, LLC, as borrower, MUFG Bank Ltd., as administrative agent, Mizuho Bank (USA), as collateral agent, ING Capital LLC, Mizuho Bank, Ltd. and MUFG Union Bank, N.A., as L/C issuers, coordinating lead arrangers and joint bookrunners, and the lenders from time to time party thereto

produced water			water from underground geologic formations that is a by-product of natural gas and crude oil production
Revolving Credit Facility			the Third Amended and Restated Credit Agreement dated as of May 26, 2017, as amended by the First Amendment to Third Amended and Restated Credit Agreement dated as of September 22, 2017, the Second Amendment to Third Amended and Restated Credit Agreement dated as of June 26, 2019, the Third Amendment to Third Amended and Restated Credit Agreement dated as of December 24, 2019 and the Fourth Amendment to Third Amended and Restated Credit Agreement dated as of December 18, 2020
SEC			Securities and Exchange Commission
Securities Act			Securities Act of 1933, as amended
segment adjusted EBITDA			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) impairments and (viii) other noncash expenses or losses, less other noncash income or gains
Senior Notes			The 2025 Senior Notes and the 2026 Secured Notes, collectively
Series A Preferred Units			Series A Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units
shortfall payment			the payment received from a counterparty when its volume throughput does not meet its MVC for the applicable period
SMLP			Summit Midstream Partners, LP
SMLP LTIP			SMLP Long-Term Incentive Plan
SMP Holdings			Summit Midstream Partners Holdings, LLC, also known as SMPH
SMPH Term Loan			the Term Loan Agreement, dated as of March 21, 2017, among SMP Holdings, as borrower, the lenders party thereto and Credit Suisse AG, Cayman Islands Branch, as Administrative Agent and Collateral Agent
Subsidiary Series A Preferred Units			Series A Fixed Rate Cumulative Redeemable Preferred Units issued by Permian Holdco
Summit Holdings			Summit Midstream Holdings, LLC
Summit Investments			Summit Midstream Partners, LLC
Summit Marketing			Summit Midstream Marketing, LLC

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Summit Permian			Summit Midstream Permian, LLC
Summit Permian II			Summit Midstream Permian II, LLC
Summit Permian Transmission			Summit Permian Transmission, LLC
Summit Utica			Summit Midstream Utica, LLC
the Partnership			Summit Midstream Partners, LP and its subsidiaries
the Partnership Agreement			the Fourth Amended and Restated Agreement of Limited Partnership of the Partnership dated May 28, 2020
throughput volume			the volume of natural gas, crude oil or produced water gathered, transported or passing through a pipeline, plant or other facility during a particular period; also referred to as volume throughput
unconventional resource basin			a basin where natural gas or crude oil production is developed from unconventional sources that require hydraulic fracturing as part of the completion process, for instance, natural gas produced from shale formations and coalbeds; also referred to as an unconventional resource play
wellhead			the equipment at the surface of a well, used to control the well's pressure; also, the point at which the hydrocarbons and water exit the ground

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PART I - FINANCIAL INFORMATION

Item 1. Financial Statements.

SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS


	June 30, 2022		December 31, 2021
	(In thousands, except unit amounts)
ASSETS
Cash and cash equivalents	$	12,367	$	7,349
Restricted cash	3,333		12,223
Accounts receivable	59,392		62,121
Other current assets	3,716		5,676
Total current assets	78,808		87,369
Property, plant and equipment, net	1,531,450		1,726,082
Intangible assets, net	156,877		172,927
Investment in equity method investees	519,553		523,196
Other noncurrent assets	23,645		12,888
TOTAL ASSETS	$	2,310,333	$	2,522,462

LIABILITIES AND CAPITAL
Trade accounts payable	$	8,378	$	10,498
Accrued expenses	21,323		14,462
Deferred revenue	9,720		10,374
Ad valorem taxes payable	4,738		8,570
Accrued compensation and employee benefits	6,760		11,019
Accrued interest	15,992		12,737
Accrued environmental remediation	2,108		3,068
Current portion of long-term debt	7,526		—

Other current liabilities	10,476		8,509
Total current liabilities	87,021		79,237
Long-term debt, net of issuance costs	1,232,512		1,355,072
Noncurrent deferred revenue	40,362		42,570
Noncurrent accrued environmental remediation	2,272		2,538
Other noncurrent liabilities	32,184		32,357
Total liabilities	1,394,351		1,511,774
Commitments and contingencies (Note 14)

Mezzanine Capital
Subsidiary Series A Preferred Units (93,039 and 91,439 units issued and outstanding at June 30, 2022 and December 31, 2021, respectively)	113,574		106,325

Partners' Capital
Series A Preferred Units (65,508 and 143,447 units issued and outstanding at June 30, 2022 and December 31, 2021, respectively)	81,290		169,769
Common limited partner capital (10,166,175 and 7,169,834 units issued and outstanding at June 30, 2022 and December 31, 2021, respectively)	721,118		734,594
Total partners' capital	802,408		904,363
TOTAL LIABILITIES AND CAPITAL	$	2,310,333	$	2,522,462

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

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SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands, except per-unit amounts)
Revenues:
Gathering services and related fees	$	61,631	$	74,233	$	125,651	$	144,580
Natural gas, NGLs and condensate sales	28,278		16,416		50,736		37,180
Other revenues	9,154		9,392		18,802		17,599
Total revenues	99,063		100,041		195,189		199,359
Costs and expenses:
Cost of natural gas and NGLs	26,831		16,626		49,082		37,102
Operation and maintenance	22,277		17,507		39,339		34,100
General and administrative	10,473		29,360		23,433		39,938
Depreciation and amortization	30,111		28,364		60,556		56,875
Transaction costs	(13)		450		233		217
Gain on asset sales, net	(313)		(4)		(310)		(140)
Long-lived asset impairments	84,614		33		84,628		1,525
Total costs and expenses	173,980		92,336		256,961		169,617
Other income (expense), net	(4)		352		(4)		408
Gain (loss) on interest rate swaps	3,936		(2,686)		10,964		(2,692)

Loss on ECP Warrants	—		(12,159)		—		(13,634)
Interest expense	(24,887)		(15,502)		(49,050)		(29,455)

Loss before income taxes and equity method investment income	(95,872)		(22,290)		(99,862)		(15,631)
Income tax (expense) benefit	(325)		248		(375)		262
Income from equity method investees	4,393		2,304		8,428		4,619
Net loss	$	(91,804)	$	(19,738)	$	(91,809)	$	(10,750)
Net income attributable to Subsidiary Series A Preferred Units	(3,164)		(4,089)		(8,877)		(8,021)
Net loss attributable to Summit Midstream Partners, LP	$	(94,968)	$	(23,827)	$	(100,686)	$	(18,771)
Less: net income attributable to Series A Preferred Units	(1,888)		(3,849)		(4,108)		(8,136)
Add: deemed contribution from 2022 Preferred Exchange Offer	—		—		20,974		—
Add: deemed contribution from 2021 Preferred Exchange Offer	—		8,326		—		8,326
Net loss attributable to common limited partners	$	(96,856)	$	(19,350)	$	(83,820)	$	(18,581)
Net loss per limited partner unit:
Common unit – basic	$	(9.53)	$	(2.91)	$	(8.45)	$	(2.91)
Common unit – diluted	$	(9.53)	$	(2.91)	$	(8.45)	$	(2.91)

Weighted-average limited partner units outstanding:
Common units – basic	10,166		6,656		9,919		6,392
Common units – diluted	10,166		6,656		9,919		6,392

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

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SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF PARTNERS' CAPITAL


	Partners' Capital
		Series A Preferred Units		Common Limited Partners Capital		Total
		(In thousands)
Partners' capital, January 1, 2022		$	169,769	$	734,594	$	904,363
Net income (loss)		2,220		(7,938)		(5,718)
Unit-based compensation		—		1,690		1,690
Tax withholdings and associated payments on vested SMLP LTIP awards		—		(562)		(562)
Tax withholdings on 2022 Preferred Exchange Offer		—		(2,652)		(2,652)
Effect of 2022 Preferred Exchange Offer, inclusive of a $20.9 million deemed contribution to common unit holders (Note 10)		(92,587)		92,587		—
Partners' capital, March 31, 2022		$	79,402	$	817,719	$	897,121
Net income (loss)		1,888		(96,856)		(94,968)
Unit-based compensation		—		582		582
Tax withholdings and associated payments on vested SMLP LTIP awards		—		(327)		(327)
Partners' capital, June 30, 2022		$	81,290	$	721,118	$	802,408


	Partners' Capital
		Series A Preferred Units		Common Limited Partners Capital		Total
		(In thousands)
Partners' capital, January 1, 2021		$	174,425	$	748,466	$	922,891
Net income		4,287		769		5,056
Unit-based compensation		—		1,967		1,967
Tax withholdings and associated payments on vested SMLP LTIP awards		—		(1,274)		(1,274)
Partners' capital, March 31, 2021		$	178,712	$	749,928	$	928,640
Net income (loss)		3,849		(27,676)		(23,827)
Unit-based compensation		—		1,048		1,048
Tax withholdings and associated payments on vested SMLP LTIP awards		—		(98)		(98)
Tax withholdings on 2021 Preferred Exchange Offer		—		(465)		(465)
Effect of 2021 Preferred Exchange Offer, inclusive of an $8.3 million deemed contribution to common unit holders (Note 10)		(20,654)		20,654		—
Partners' capital, June 30, 2021		$	161,907	$	743,391	$	905,298

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

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SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS


	Six Months Ended June 30,
	2022		2021
	(In thousands)
Cash flows from operating activities:
Net loss	$	(91,809)	$	(10,750)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization	61,025		57,344
Noncash lease expense	468		519
Amortization of debt issuance costs	4,441		3,447
Unit-based and noncash compensation	2,272		3,015
Income from equity method investees	(8,428)		(4,619)
Distributions from equity method investees	20,451		13,116
Gain on asset sales, net	(310)		(140)


Loss on ECP Warrants	—		13,634
(Gain) loss on interest rate swaps, unsettled	(11,617)		2,692
Long-lived asset impairment	84,628		1,525
Changes in operating assets and liabilities:
Accounts receivable	(3,010)		(1,993)
Trade accounts payable	(1,090)		2,989
Accrued expenses	11,599		(3,127)
Deferred revenue, net	(2,748)		(2,787)
Ad valorem taxes payable	(3,384)		(3,691)
Accrued interest	3,254		—
Accrued environmental remediation, net	(1,226)		(512)
Other, net	(4,357)		15,555
Net cash provided by operating activities	60,159		86,217
Cash flows from investing activities:
Capital expenditures	(14,794)		(5,962)
Proceeds from sale of Lane G&P System, net of cash sold in transaction	75,520		—
Proceeds from asset sale	4,600		8,000
Investment in Double E equity method investee	(8,444)		(48,943)


Net cash provided from (used in) investing activities	56,882		(46,905)
Cash flows from financing activities:


Repayments on Revolving Credit Facility	—		(95,000)
Borrowings under Permian Transmission Credit Facility	—		53,500
Repayments on Permian Transmission Term Loan	(2,242)		—
Repayments on ABL Facility	(139,000)		—
Borrowings on ABL Facility	23,000





Debt issuance costs	—		(5,179)
Proceeds from asset sale	—		260
Other, net	(2,671)		(912)
Net cash used in financing activities	(120,913)		(47,331)
Net change in cash, cash equivalents and restricted cash	(3,872)		(8,019)
Cash, cash equivalents and restricted cash, beginning of period	19,572		15,544
Cash, cash equivalents and restricted cash, end of period	$	15,700	$	7,525

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

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SUMMIT MIDSTREAM PARTNERS, LP AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION, BUSINESS OPERATIONS AND PRESENTATION AND CONSOLIDATION

Organization. Summit Midstream Partners, LP (including its subsidiaries, collectively “SMLP” or the “Partnership”) is a Delaware limited partnership that was formed in May 2012 and began operations in October 2012. SMLP is a value-oriented limited partnership focused on developing, owning and operating midstream energy infrastructure assets that are strategically located in unconventional resource basins, primarily shale formations, in the continental United States. The Partnership’s business activities are primarily conducted through various operating subsidiaries, each of which is owned or controlled by its wholly owned subsidiary holding company, Summit Holdings, a Delaware limited liability company.

Business Operations. The Partnership provides 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 its customers. The Partnership’s results are primarily driven by the volumes of natural gas that it gathers, compresses, treats and/or processes as well as by the volumes of crude oil and produced water that it gathers. Other than the Partnership’s investments in Double E and Ohio Gathering, all of its business activities are conducted through wholly owned operating subsidiaries.

Presentation and Consolidation. The Partnership prepares its condensed consolidated financial statements in accordance with GAAP as established by the FASB and pursuant to the rules and regulations of the SEC pertaining to interim financial information. The unaudited condensed consolidated financial statements contained in this report include all normal and recurring material adjustments that, in the opinion of management, are necessary for a fair statement of the financial position, results of operations and cash flows for the interim periods presented herein. These unaudited condensed consolidated financial statements and notes thereto should be read in conjunction with the consolidated financial statements and related notes that are included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2021.

The Partnership makes 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.

The unaudited condensed consolidated financial statements contained in this report include the assets, liabilities and results of operations of SMLP and its subsidiaries. All intercompany transactions among the consolidated entities have been eliminated in consolidation. Comprehensive income or loss is the same as net income or loss for all periods presented.

Risks and Uncertainties. The Partnership continues to closely monitor the impact of the COVID-19 pandemic on all aspects of its business, including how it has impacted and will impact its customers, employees, supply chain and distribution network. The Partnership is unable to predict the ultimate impact that COVID-19 may have on its business, future results of operations, financial position or cash flows.

Given the dynamic nature of the COVID-19 pandemic and related market conditions, the Partnership cannot reasonably estimate the period of time that these events will persist or the full extent of the impact they will have on its business. The full extent to which the Partnership’s operations continue to be impacted by the COVID-19 pandemic will depend largely on future developments, which remain highly uncertain and cannot be accurately predicted. While many of the restrictions and measures initially implemented during 2020 have since been softened or lifted in varying degrees in different locations around the world, and the manufacture and distribution of COVID-19 vaccines during 2021 and throughout the first half of 2022 helped to initiate a recovery from the pandemic, the uncertainty regarding new potential variants of COVID-19 and the success of any vaccines in respect thereof, may in the future cause a reduction in global economic activity or prompt the re-imposition of certain restrictions and measures. In addition, even if not required by governmental authorities, increases in COVID-19 cases, such as if a new variant emerges, may result in significantly reduced economic activity, particularly in affected areas, which could result in a sharp reduction in the demand for oil and a decline in oil prices as occurred during 2020.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND RECENTLY ISSUED ACCOUNTING STANDARDS APPLICABLE TO THE PARTNERSHIP

There have been no changes to the Partnership’s significant accounting policies since December 31, 2021.

New accounting standards not yet implemented.

ASU No. 2020-6 Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815–40) (“ASU 2020-6”). ASU 2020-6 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. The ASU is part of the FASB’s simplification initiative, which aims to reduce unnecessary complexity in GAAP. The ASU’s amendments are effective for fiscal years beginning after December 15, 2023, and interim periods within those

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fiscal years. The Partnership is currently evaluating the provisions of ASU 2020-6 to determine its impact on the Partnership’s consolidated financial statements and disclosures.

ASU No. 2020-4 Reference Rate Reform (“ASU 2020-4”). ASU 2020-4 provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships and other transactions affected by reference rate reform on financial reporting. The amendments in ASU 2020-4 are effective as of March 12, 2020 through December 31, 2022. The Partnership does not expect the provisions of ASU 2020-4 will have a material impact on its consolidated financial statements and disclosures.

3. DISPOSITION

Lane G&P System. On June 30, 2022, the Partnership, completed the disposition of all the equity interests in Summit Permian, which owns the Lane Gathering and Processing System (“Lane G&P System”), to Longwood Gathering and Disposal Systems, LP (“Longwood”), a wholly owned subsidiary of Matador ͏Resources Company (“Matador”), for a cash sale price of $75.0 million. In connection with the transaction, the Partnership released to a subsidiary of Matador, and Matador agreed to assume, take or-pay firm capacity on the Double E Pipeline. The Partnership is the operator of the Double E joint venture and owns a 70% interest.

During the quarterly period ended June 30, 2022, the Partnership recognized an impairment of $84.5 million related to the disposition of the Lane G&P System based on total cash proceeds received of $77.5 million, including $2.0 million of cash sold in the transaction, net assets of $160.8 million, and other costs to sell of $1.2 million. The cash proceeds were used to reduce amounts outstanding under the ABL Facility and are subject to a final working capital adjustment.

4. REVENUE

The following table presents estimated revenue expected to be recognized during the remainder of 2022 and over the remaining contract period related to performance obligations that are unsatisfied and are comprised of estimated minimum volume commitments.


(In thousands)	2022		2023		2024		2025		2026		Thereafter

Gathering services and related fees	$	41,041	$	63,214	$	52,412	$	35,805	$	21,024	$	—

Revenue by Category. In the following tables, revenue is disaggregated by geographic area and major products and services. For more detailed information about reportable segments, see Note 15 – Segment Information.


	Three Months Ended June 30, 2022
	Gathering services and related fees		Natural gas, NGLs and condensate sales		Other revenues		Total
	(In thousands)
Reportable Segments:
Northeast	$	12,940	$	—	$	—	$	12,940
Rockies	16,510		14,927		4,728		36,165
Permian	1,822		10,514		1,298		13,634
Piceance	19,981		2,067		1,276		23,324
Barnett	10,378		786		1,671		12,835
Total reportable segments	61,631		28,294		8,973		98,898
Corporate and other	—		(16)		181		165
Total	$	61,631	$	28,278	$	9,154	$	99,063

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	Six Months Ended June 30, 2022
	Gathering services and related fees		Natural gas, NGLs and condensate sales		Other revenues		Total
	(In thousands)
Reportable Segments:
Northeast	$	27,576	$	—	$	—	$	27,576
Rockies	34,299		28,586		9,885		72,770
Permian	3,669		17,381		2,317		23,367
Piceance	40,052		3,962		2,551		46,565
Barnett	20,055		786		3,734		24,575
Total reportable segments	125,651		50,715		18,487		194,853
Corporate and other	—		21		315		336
Total	$	125,651	$	50,736	$	18,802	$	195,189


	Three Months Ended June 30, 2021
	Gathering services and related fees		Natural gas, NGLs and condensate sales		Other revenues		Total
	(In thousands)
Reportable Segments:
Northeast	$	17,961	$	—	$	—	$	17,961
Rockies	18,407		8,506		6,098		33,011
Permian	2,262		6,875		1,049		10,186
Piceance	25,527		1,025		1,233		27,785
Barnett	10,076		10		1,012		11,098
Total reportable segments	74,233		16,416		9,392		100,041
Corporate and other	—		—		—		—
Total	$	74,233	$	16,416	$	9,392	$	100,041


	Six Months Ended June 30, 2021
	Gathering services and related fees		Natural gas, NGLs and condensate sales		Other revenues		Total
	(In thousands)
Reportable Segments:
Northeast	$	32,733	$	—	$	—	$	32,733
Rockies	37,303		20,843		11,309		69,455
Permian	4,461		13,393		1,809		19,663
Piceance	50,311		2,878		2,409		55,598
Barnett	19,772		66		2,072		21,910
Total reportable segments	144,580		37,180		17,599		199,359
Corporate and other	—		—		—		—
Total	$	144,580	$	37,180	$	17,599	$	199,359

Contract balances. Contract assets relate to the Partnership’s rights to consideration for work completed but not billed at the reporting date and consist of the estimated MVC shortfall payments expected from its customers and unbilled activity

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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:


	Total
	(In thousands)
Contract assets, beginning balance December 31, 2021	$	10,327
Additions	4,802
Transfers out	(8,867)
Contract assets, ending balance June 30, 2022	$	6,262

As of June 30, 2022, receivables with customers totaled $49.9 million and contract assets totaled $6.3 million and are included in the accounts receivable caption on the unaudited condensed consolidated balance sheets.

As of December 31, 2021, receivables with customers totaled $50.5 million and contract assets totaled $10.3 million and are included in the accounts receivable caption on the unaudited condensed consolidated balance sheets.

Contract liabilities (deferred revenue) relate to the advance consideration received from customers primarily for contributions in aid of construction. The Partnership recognizes contract liabilities under these arrangements in revenue over the contract period. See Note 7 – Deferred Revenue for additional details.

5. PROPERTY, PLANT AND EQUIPMENT

Details on the Partnership’s property, plant and equipment follow.


	June 30, 2022		December 31, 2021
	(In thousands)
Gathering and processing systems and related equipment	$	2,077,369	$	2,225,267
Construction in progress	31,874		49,082
Land and line fill	10,212		10,644
Other	52,472		51,863
Total	2,171,927		2,336,856
Less: accumulated depreciation	(640,477)		(610,774)
Property, plant and equipment, net	$	1,531,450	$	1,726,082

Depreciation expense and capitalized interest for the Partnership follow.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands)
Depreciation expense	$	23,714	$	21,318	$	47,762	$	42,784
Capitalized interest	251		149		583		324

6. EQUITY METHOD INVESTMENTS

The Partnership has equity method investments in Double E and Ohio Gathering, the balances of which are included in the Investment in equity method investees caption on the unaudited condensed consolidated balance sheets. Details of the Partnership’s equity method investments follow.


	June 30, 2022		December 31, 2021
	(In thousands)
Double E	$	284,790	$	280,952
Ohio Gathering	234,763		242,244
Total	$	519,553	$	523,196

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7. DEFERRED REVENUE

Certain of the Partnership’s gathering and/or processing agreements provide for monthly or annual MVCs. The amount of the shortfall payment is based on the difference between the actual throughput volume shipped and/or processed for the applicable period and the MVC for the applicable period, multiplied by the applicable gathering or processing fee.

Many of the Partnership’s gas gathering agreements contain provisions that can reduce or delay the cash flows that it expects to receive from MVCs to the extent that a customer's actual throughput volumes are above or below its MVC for the applicable contracted measurement period.

The balances in deferred revenue as of June 30, 2022 and December 31, 2021 are primarily related to contributions in aid of construction which will be recognized as revenue over the life of the contract.

A rollforward of current deferred revenue follows.


	Total
	(In thousands)
Current deferred revenue, January 1, 2022	$	10,374
Add: additions	2,509
Less: revenue recognized	(3,163)
Current deferred revenue, June 30, 2022	$	9,720

A rollforward of noncurrent deferred revenue follows.


	Total
	(In thousands)
Noncurrent deferred revenue, January 1, 2022	$	42,570
Add: additions	269
Less: reclassification to current deferred revenue	(2,477)
Noncurrent deferred revenue, June 30, 2022	$	40,362

8. DEBT

Debt for the Partnership at June 30, 2022 and December 31, 2021, follows:


	June 30, 2022		December 31, 2021
	(In thousands)

ABL Facility: Summit Holdings' asset based credit facility due May 1, 2026	$	151,000	$	267,000
Permian Transmission Credit Facility: Permian Transmission's variable rate senior secured credit facility due March 8, 2028	—		160,000
Permian Transmission Term Loan: Permian Transmission's variable rate senior secured term loan due March 8, 2028	157,758		—


2025 Senior Notes: Summit Holdings' 5.75% senior unsecured notes due April 15, 2025	259,463		259,463

2026 Secured Notes: Summit Holdings' and Finance Corp's 8.50% senior unsecured notes due October 15, 2026	700,000		700,000
Less: unamortized debt discount and debt issuance costs	(28,183)		(31,391)
Total debt	1,240,038		1,355,072
Less: current portion	(7,526)		—
Total long-term debt	$	1,232,512	$	1,355,072

ABL Facility. On November 2, 2021, the Partnership, the Partnership’s subsidiary, Summit Holdings, and the subsidiaries of Summit Holdings party thereto entered into a first-lien, senior secured credit facility, consisting of a $400.0 million asset-based revolving credit facility (the “ABL Facility”), subject to a borrowing base comprised of a percentage of eligible accounts receivable of Summit Holdings and its subsidiaries that guarantee the ABL Facility (collectively, the “ABL Facility Subsidiary Guarantors”) and a percentage of eligible above-ground fixed assets including eligible compression units, processing plants, compression stations and related equipment of Summit Holdings and the ABL Facility Subsidiary Guarantors. As of June 30,

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2022, the most recent borrowing base determination of eligible assets totaled $584.5 million, an amount greater than the $400.0 million of aggregate commitments.

The ABL Facility will mature on May 1, 2026; provided that, (a) if the outstanding amount of the 2025 Senior Notes (or any permitted refinancing indebtedness in respect thereof that has a final maturity, scheduled amortization or any other scheduled repayment, mandatory prepayment, mandatory redemption or sinking fund obligation prior to the date that is 120 days after the Termination Date (as defined in the ABL Agreement)) on such date equals or exceeds $50,000,000, then the ABL Facility will mature on December 13, 2024 and (b) if both (i) any amount of the 2025 Senior Notes (or any permitted refinancing indebtedness in respect thereof that has a final maturity, scheduled amortization or any other scheduled repayment, mandatory prepayment, mandatory redemption or sinking fund obligation prior to the date that is 120 days after the Termination Date) is outstanding on such date and (ii) Liquidity (as defined in the ABL Agreement) is less than an amount equal to the sum of the then aggregate outstanding principal amount of the 2025 Senior Notes (or any permitted refinancing indebtedness in respect thereof that has a final maturity, scheduled amortization or any other scheduled repayment, mandatory prepayment, mandatory redemption or sinking fund obligation prior to the date that is 120 days after the Termination Date) plus the Threshold Amount (as defined in the ABL Agreement) on such date, then the ABL Facility will mature on January 14, 2025.

As of June 30, 2022, the applicable margin under the adjusted LIBOR borrowings was 3.25%, the interest rate was 4.375% and the available borrowing capacity of the ABL Facility totaled $243.1 million after giving effect to the issuance of $5.9 million in outstanding but undrawn irrevocable standby letters of credit.

The ABL Facility requires that Summit Holdings not permit (i) the First Lien Net Leverage Ratio (as defined in the ABL Agreement) as of the last day of any fiscal quarter to be greater than 2.50:1.00, or (ii) the Interest Coverage Ratio (as defined in the ABL Agreement) as of the last day of any fiscal quarter to be less than 2.00:1.00. As of June 30, 2022, the First Lien Net Leverage Ratio was 0.64:1.00 and the Interest Coverage Ratio was 2.73:1.00 As of June 30, 2022, the Partnership was in compliance with the financial covenants of the ABL Facility.

Permian Transmission Credit Facility. On March 8, 2021 (the “Permian Closing Date”), the Partnership’s unrestricted subsidiary, Permian Transmission, entered into a Credit Agreement which provided for $175.0 million of senior secured credit facilities (the “Permian Transmission Credit Facilities”), including a $160.0 million Term Loan Facility and a $15.0 million Working Capital Facility. Borrowings from the Permian Transmission Credit Facilities were used to finance Permian Transmission’s capital calls associated with its investment in Double E. In January 2022, in accordance with the terms of Permian Transmission Credit Facilities, the Partnership converted the $160.0 million portion of the Permian Transmission Credit Facilities into a term loan facility (the “Permian Term Loan Facility”).

As of June 30, 2022, the applicable margin under adjusted LIBOR borrowings was 2.375%, the interest rate was 3.4% and the available borrowing capacity of the Permian Transmission Credit Facility totaled $7.5 million, subject to a commitment fee of 0.7% after giving effect to the issuance of $7.5 million in outstanding but undrawn irrevocable standby letters of credit and surety bonds. As of June 30, 2022, the Partnership was in compliance with the financial covenants of the Permian Transmission Credit Facility.

Permian Transmission Term Loan. As described above, in January 2022, the Permian Transmission Term Loan Facility was converted into a Term Loan (the “Permian Transmission Term Loan”). The Permian Transmission Term Loan is due on May 8, 2028. As of June 30, 2022, the applicable margin under adjusted LIBOR borrowings was 2.375% and the interest rate was 3.4%. As of June 30, 2022, the Partnership was in compliance with the financial covenants governing the Permian Transmission Term Loan.

In accordance with the terms of the Permian Transmission Term Loan, Permian Transmission is required to make mandatory principal repayments. Below is a summary of the remaining mandatory principal repayments as of June 30, 2022:


(In thousands)	Total		2022		2023		2024		2025		2026		Thereafter
Amortizing principal repayments	$	157,758	$	2,405	$	10,507	$	15,524	$	16,580	$	16,967	$	95,775

2026 Secured Notes. In November 2021, the Co-Issuers issued the 2026 Secured Notes. The 2026 Secured Notes are senior secured second lien notes due 2026. The 2026 Secured Notes will pay interest semi-annually in cash in arrears on April 15 and October 15 of each year, commencing on April 15, 2022, and will be jointly and severally guaranteed, on a senior second-priority secured basis (subject to permitted liens), by the Partnership and each restricted subsidiary of the Partnership (other than the Co-Issuers) that is an obligor under the ABL Agreement, or under the Co-Issuers’ 2025 Senior Notes on the issue date of the 2026 Secured Notes.

The 2026 Secured Notes are effectively subordinated to any of our or the guarantors’ current and future secured first lien indebtedness, including indebtedness incurred under the ABL Facility, to the extent of the value of the collateral securing such indebtedness, and our and the guarantors’ current and future debt that is secured by liens on assets other than the collateral, to the extent of the value of such assets. The 2026 Secured Notes are structurally subordinated to all indebtedness and other

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liabilities of our subsidiaries that do not guarantee the 2026 Secured Notes. The 2026 Secured Notes are effectively equal to our and the guarantors’ obligations under any future second lien indebtedness and effectively senior to all of our future junior lien indebtedness and existing and future unsecured indebtedness, including our outstanding senior unsecured notes, to the extent of the value of the collateral, and senior to any of our future subordinated indebtedness. The 2026 Secured Notes will mature on October 15, 2026.

Before October 15, 2023, the Co-Issuers may redeem the 2026 Secured Notes, in whole or in part, at a price equal to 100% of their principal amount, plus a make-whole premium, together with accrued and unpaid interest to, but not including the redemption date. On and after October 15, 2023, the Co-Issuers may redeem all or part of the 2026 Secured Notes at redemption prices (expressed as percentages of principal amount) equal to: (a) 104.250% for the twelve-month period beginning October 15, 2023; (b) 102.125% for the twelve-month period beginning October 15, 2024; and (c) 100.000% for the twelve-month period beginning on October 15, 2025 and at any time thereafter, in each case plus accrued and unpaid interest, if any, to, but not including, the redemption date. As of June 30, 2022, the Partnership was in compliance with the financial covenants governing its 2026 Secured Notes.

2025 Senior Notes. In February 2017, the Co-Issuers co-issued the 2025 Senior Notes. The 2025 Senior Notes will pay interest semi-annually in cash in arrears on April 15 and October 15 of each year. The 2025 Senior Notes are senior, unsecured obligations and rank equally in right of payment with all of the Partnership’s existing and future senior obligations. The 2025 Senior Notes are effectively subordinated in right of payment to all of the Partnership’s secured indebtedness, to the extent of the collateral securing such indebtedness.

The Co-Issuers have the right to redeem all or part of the 2025 Senior Notes at a redemption price of 101.438% (with the redemption price declining to 100.00% on April 15, 2023 and thereafter), plus accrued and unpaid interest, if any, to, but not including the redemption date.

As of June 30, 2022, the Partnership was in compliance with the financial covenants governing its 2025 Senior Notes.

9. FINANCIAL INSTRUMENTS

Fair Value. A summary of the estimated fair value of our financial instruments follows.


	June 30, 2022				December 31, 2021
	Carrying Value (1)		Estimated fair value (Level 2)		Carrying Value (1)		Estimated fair value (Level 2)
	(In thousands)

2025 Senior Notes	$	259,463	$	203,354	$	259,463	$	234,814
2026 Secured Notes	700,000		628,250		700,000		718,083

________

(1) Excludes applicable unamortized debt issuance costs and debt discounts.

The carrying values on the balance sheets of the ABL Facility and Permian Transmission Term Loan represents their fair value due to its floating interest rate. The fair values of the 2026 Secured Notes and 2025 Senior Notes are based on an average of nonbinding broker quotes as of June 30, 2022 and December 31, 2021. The use of different market assumptions or valuation methodologies may have a material effect on their estimated fair value.

Interest Rate Swaps. In connection with the Permian Transmission Term Loan, formerly the Permian Transmission Credit Facility, the Partnership entered into amortizing interest rate swap agreements. As of June 30, 2022 and December 31, 2021, the outstanding notional amounts of interest rate swaps were $142.0 million and $144.0 million, respectively. These interest rate swaps manage exposure to variability in expected cash flows attributable to interest rate risk. Interest rate swaps convert a portion of the Partnership’s variable rate debt to fixed rate debt. The Partnership chooses counterparties for its derivative instruments that it believes are creditworthy at the time the transactions are entered into, and the Partnership actively monitors the creditworthiness where applicable. However, there can be no assurance that a counterparty will be able to meet its obligations to the Partnership. The Partnership presents its derivative positions on a gross basis and does not net the asset and liability positions.

As of June 30, 2022, the Partnership’s interest rate swap agreements had a fair value of $10.8 million and are recorded within other noncurrent assets, other noncurrent liabilities and other current liabilities within the unaudited condensed consolidated balance sheets. Changes in the derivative instruments’ fair value are determined using level 2 inputs from the fair value hierarchy. For the three and six months ended June 30, 2022, the Company recorded a gain on interest rate swaps of $3.9 million and $11.0 million, respectively.

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10. PARTNERS' CAPITAL AND MEZZANINE CAPITAL

Common Units. A rollforward of the number of issued and outstanding common limited partner units follows for the period from December 31, 2021 to June 30, 2022.


			Common Units
Units, December 31, 2021			7,169,834
2022 Preferred Exchange Offer, net of units withheld for taxes			2,853,875
Common units issued for SMLP LTIP, net			142,466
Units, June 30, 2022			10,166,175

Series A Preferred Units. As of June 30, 2022, the Partnership had 65,508 Series A Preferred Units outstanding and $17.4 million of accrued and unpaid distributions on its Series A Preferred Units.

Series A Preferred Unit Exchange Offers. In January 2022, the Partnership completed an offer to exchange its Series A Preferred Units for newly issued common units (the “2022 Preferred Exchange Offer”), whereby it issued 2,853,875 SMLP common units, net of units withheld for withholding taxes, in exchange for 77,939 Series A Preferred Units. As a result of the transaction, the Partnership recognized a deemed contribution of $20.9 million from the Series A Preferred Unit holders to the common unit holders.

In April 2021, the Partnership completed an offer to exchange its Series A Preferred Units for newly issued common units (the “2021 Preferred Exchange Offer”), whereby it issued 538,715 SMLP common units, net of units withheld for withholding taxes, in exchange for 18,662 Series A Preferred Units. As a result of the transaction, the Partnership recognized a deemed contribution of $8.3 million from the Series A Preferred Unit holders to the common unit holders.

Subsidiary Series A Preferred Units. The Partnership records its Subsidiary Series A Preferred Units at fair value upon issuance, net of issuance costs, and subsequently records an effective interest method accretion amount each reporting period to accrete the carrying value to a most probable redemption value that is based on a predetermined internal rate of return measure. If the Partnership elects to make payment-in-kind (“PIK”) distributions to holders of its Subsidiary Series A Preferred Units, these PIK distributions increase the liquidation preference on each Subsidiary Series A Preferred Unit. Net Income (Loss) attributable to our common units includes adjustments for PIK distributions and redemption accretion.

During the six months ended June 30, 2022, the Partnership accrued a $1.6 million of cash distribution, which was paid in July 2022, and elected to make PIK distributions, issuing 1,600 Subsidiary Series A Preferred Units, to the holders of its Subsidiary Series A Preferred Units. As of June 30, 2022, the Partnership had 93,039 Subsidiary Series A Preferred Units issued and outstanding.

If the Subsidiary Series A Preferred Units were redeemed on June 30, 2022, the redemption amount would be $117.6 million when considering the applicable multiple of invested capital metric and make-whole amount provisions contained in the Subsidiary Series A Preferred Unit agreement.

The following table shows the change in our Subsidiary Series A Preferred Unit balance from January 1, 2022 to June 30, 2022, net of $2.5 million and $3.9 million of unamortized issuance costs at June 30, 2022 and December 31, 2021, respectively:


	(In thousands)
Balance at December 31, 2021	$	106,325
PIK distributions	1,600
Redemption accretion, net of issuance cost amortization	7,277
Cash distribution	(1,628)
Balance at June 30, 2022	$	113,574

Warrants. On May 28, 2020, and in connection with the GP Buy-In Transaction, the Partnership issued (i) a warrant to purchase up to 537,307 SMLP common units (8,059,609 SMLP common units prior to the Reverse Unit Split) to SMP TopCo, LLC, a Delaware limited liability company and affiliate of ECP (“ECP NewCo”) (the “ECP NewCo Warrant”), and (ii) a warrant to purchase up to 129,360 SMLP common units (1,940,391 SMLP common units prior to the Reverse Unit Split) to SMLP Holdings, LLC, a Delaware limited liability company and affiliate of ECP (“ECP Holdings” and together with ECP NewCo, the "ECP Entities") (the “ECP Holdings Warrant” and together with the ECP NewCo Warrant, the “ECP Warrants”).

On August 5, 2021, the ECP Entities cashlessly exercised all of the ECP Warrants for an aggregate of 414,447 SMLP common units, net of the exercise price, as calculated pursuant to Section 3(c) of the ECP Warrants (the "ECP Warrant Exercise").

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Cash Distribution Policy. In connection with the GP Buy-In Transaction, the Partnership suspended its cash distributions to holders of its common units, commencing with respect to the quarter ended March 31, 2020. Upon the resumption of distributions, the Partnership Agreement requires that it distribute all available cash, subject to reserves established by its General Partner, within 45 days after the end of each quarter to unitholders of record on the applicable record date. The amount of distributions paid under this policy is subject to fluctuations based on the amount of cash the Partnership generates from its business and the decision to make any distribution is determined by the General Partner, taking into consideration the terms of the Partnership Agreement. There were no distributions paid during the three and six months ended June 30, 2022 or during the twelve months ended December 31, 2021.

11. EARNINGS PER UNIT

The following table details the components of EPU.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands, except per-unit amounts)
Numerator for basic and diluted EPU:
Allocation of net loss among limited partner interests:
Net loss	$	(91,804)	$	(19,738)	$	(91,809)	$	(10,750)
Net income attributable to Subsidiary Series A Preferred Units	(3,164)		(4,089)		(8,877)		(8,021)
Net loss attributable to Summit Midstream Partners, LP	$	(94,968)	$	(23,827)	$	(100,686)	(18,771)

Less: Net income attributable to Series A Preferred Units	$	(1,888)	$	(3,849)	$	(4,108)	(8,136)
Add: Deemed capital contribution from 2022 Preferred Exchange Offer	—		—		20,974		—
Add: Deemed capital contribution from 2021 Preferred Exchange Offer	$	—	$	8,326	$	—	$	8,326
Net loss attributable to common limited partners	$	(96,856)	$	(19,350)	$	(83,820)	$	(18,581)

Denominator for basic and diluted EPU:
Weighted-average common units outstanding – basic	10,166		6,656		9,919		6,392
Effect of nonvested phantom units	—		—		—		—
Weighted-average common units outstanding – diluted	10,166		6,656		9,919		6,392

Net income per limited partner unit:
Common unit – basic	$	(9.53)	$	(2.91)	$	(8.45)	$	(2.91)
Common unit – diluted	$	(9.53)	$	(2.91)	$	(8.45)	$	(2.91)

Nonvested anti-dilutive phantom units excluded from the calculation of diluted EPU	—		169		—		173

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12. SUPPLEMENTAL CASH FLOW INFORMATION


	Six Months Ended June 30,
	2022		2021
	(In thousands)
Supplemental cash flow information:
Cash interest paid	$	42,039	$	27,869
Cash paid for taxes	$	149	$	15

Noncash investing and financing activities:
Capital expenditures in trade accounts payable (period-end accruals)	$	3,738	$	6,059


Accretion of Subsidiary Series A Preferred Units, net of issuance cost amortization	$	7,277	$	5,008
2022 Preferred Exchange Offer	$	92,587	$	—
2021 Preferred Exchange Offer	$	—	$	20,654

13. UNIT-BASED AND NONCASH COMPENSATION

SMLP Long-Term Incentive Plan. The Partnership’s Long-Term Incentive Plan (“SMLP LTIP”) provides for equity awards to eligible officers, employees, consultants and directors of the Partnership, thereby linking the recipients’ compensation directly to SMLP’s performance. Significant items to note:

•For the six-month period ended June 30, 2022, the Partnership granted 146,529 phantom units and associated distribution equivalent rights to employees in connection with the Partnership’s annual incentive compensation award cycle. These awards had a grant date fair value of $14.21 per common unit and vest ratably over a 3-year period.

•For the six-month period ended June 30, 2022, the Partnership issued 38,664 common units to the Partnership’s six independent directors in connection with their annual compensation plan. These awards had a grant date fair value of $14.21 per common unit and vested immediately.

•On June 24, 2022, unitholders of the Partnership approved the Summit Midstream Partners, LP 2022 Long-Term Incentive Plan, which increased the number of common units available for issuance to the Partnership’s employees, consultants and directors. As of June 30, 2022, approximately 1.2 million common units remained available for future issuance under the SMLP LTIP, which includes the impact of 0.3 million granted but unvested phantom units.

14. COMMITMENTS AND CONTINGENCIES

Environmental Matters. Although the Partnership believes that it is in material compliance with applicable environmental regulations, the risk of environmental remediation costs and liabilities are inherent in pipeline ownership and operation. Furthermore, the Partnership can provide no assurances that significant environmental remediation costs and liabilities will not be incurred in the future. The Partnership is currently not aware of any material contingent liabilities that exist with respect to environmental matters, except as noted below.

As of June 30, 2022, the Partnership has 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 expected to be incurred subsequent to June 30, 2023. Each of these amounts represent the Partnership’s best estimate for costs expected to be incurred. Neither of these amounts have been discounted to their present value.

A rollforward of the Partnership’s undiscounted accrued environmental remediation follows and is primarily related to the 2015 Blacktail Release and other environmental remediation activities, as detailed below.


	(In thousands)
Accrued environmental remediation, December 31, 2021	$	5,606
Payments made	(1,883)
Changes in estimates	657
Accrued environmental remediation, June 30, 2022	$	4,380

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In 2015, the Partnership learned of the rupture of a four-inch produced water gathering pipeline on the Meadowlark Midstream system near Williston, North Dakota (“2015 Blacktail Release”). On August 4, 2021, subsidiaries of the Partnership entered into the following agreements to resolve the U.S. federal and North Dakota state governments’ environmental claims with respect to the 2015 Blacktail Release: (i) a Consent Decree with the U.S. Department of Justice (“DOJ”), the U.S. Environmental Protection Agency (“EPA”), and the State of North Dakota (“Consent Decree”); (ii) a Plea Agreement with the United States (“Plea Agreement”); and (iii) a Consent Agreement with the North Dakota Industrial Commission (“Consent Agreement” together with the Consent Decree and Plea Agreement, the “Global Settlement”). As of June 30, 2022 and December 31, 2021, the accrued loss liability for the 2015 Blacktail Release was $33.2 million.

Key terms of the Global Settlement included (i) payment of penalties and fines totaling $36.3 million, consisting of $1.25 million in natural resource damages payable to federal and state governments, a $25.0 million payable to the federal government over 5 years, and a $10.0 million payable to state governments over six years, with interest applied to unpaid amounts accruing at a fixed rate of 3.25%, and of which $5.6 million is expected to be paid within the next twelve months; (ii) continuation of remediation efforts at the site of the 2015 Blacktail Release; (iii) other injunctive relief including but not limited to control room management, environmental management system audit, training, and reporting; (iv) guilty pleas by Defendant subsidiary for (a) one charge of negligent discharge of a harmful quantity of oil and (b) one charge of knowing failure to immediately report a discharge of oil; and (v) organizational probation for a minimum period of three years from sentencing, including payment in full of certain components of the fines and penalty amounts. The agreements comprising the Global Settlement were subject to the approval of the U.S. District Court for the District of North Dakota (the “U.S. District Court”). The U.S. District Court entered an order making the civil components of the Global Settlement effective on September 28, 2021 and accepted the sentencing in the Plea Agreement on December 6, 2021, completing approval of the Global Settlement.

In conjunction with the criminal proceedings under the Plea Agreement, the U.S. District Court received two claims for restitution, including claims for diminution in property value and the cost of additional environmental testing. The prosecution notified the U.S District Court that the government declined to support the claims, citing “insufficient evidence to support the claims.” Defendant subsidiary of the Partnership has responded that restitution is not applicable in this matter because claimants did not provide any supporting evidence for their claims that showed any harm, and because the plea agreement in this matter does not permit restitution sought by the claimants. On August 4, 2022, the U.S. District Court denied the claims.

Subsidiaries of the Partnership are also participating in two proceedings before the EPA as a result of the Plea Agreement becoming effective. Following the U.S. District Court’s entering judgment on Defendant subsidiary’s guilty plea to one count of negligent discharge of produced water in violation of the Clean Water Act, Defendant subsidiary was statutorily debarred by operation of law pursuant to 33 U.S.C. § 1368(a) to participate in federal awards performed at the “violating facility,” which EPA determined to be the Marmon subsystem of the produced water gathering system in North Dakota. Defendant has submitted a petition for reinstatement, which was denied by the EPA’s suspension and debarment office (“SDO”) on July 11, 2022. The SDO determined that the term of probation in the Plea Agreement was the appropriate period of time to demonstrate Defendant subsidiary’s change of corporate attitude, policies, practices, and procedures. The Partnership and certain subsidiaries have also received a show cause notice from the EPA requesting us to “show cause” why SDO should not issue a Notice of Proposed Debarment to the Defendant subsidiary and certain affiliates under 2 C.F.R. § 180.800(d), to which we have responded.

Legal Proceedings. The Partnership is involved in various litigation and administrative proceedings arising in the ordinary course of business. In the opinion of management, any liabilities that may result from these claims or those arising in the ordinary 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.

15. SEGMENT INFORMATION

In accordance with ASC No. 280 - Segment Reporting, the Partnership routinely evaluates whether its reportable segments have changed. In the fourth quarter of 2021, the Partnership changed its segment reporting to align with how the General Partner’s Chief Executive Officer, its chief operating decision maker, reviews financial information in order to allocate resources and assess performance. The new segment reporting as of December 31, 2021, resulted from changes enacted to optimize commercial efforts and geographic workforce in order to better align its commercial, engineering, and operational capabilities. As a result of the revised reportable segment structure, the Partnership has recast the corresponding segment information for all periods presented.

As of June 30, 2022, the Partnership’s reportable segments are:

•Rockies – Includes the Partnership’s wholly owned midstream assets located in the Williston Basin and the DJ Basin.

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•Permian – Includes the Partnership’s equity method investment in Double E and its wholly owned Lane G&P System, which was sold on June 30, 2022 to Matador. For additional information regarding the sale of the Lane G&P System, see Note 3 - Disposition.

•Northeast – Includes the Partnership’s wholly owned midstream assets located in the Utica and Marcellus shale plays and the equity method investment in Ohio Gathering that is focused on the Utica Shale.

•Piceance – Includes the Partnership’s wholly owned midstream assets located in the Piceance Basin.

•Barnett – Includes the Partnership’s wholly owned midstream assets located in the Barnett Shale.

Corporate and Other represents those results that: (i) are not specifically attributable to a reportable segment; (ii) are not individually reportable; or (iii) have not been allocated to a reportable segment for the purpose of evaluating their performance, including certain general and administrative expense items, certain natural gas and crude oil marketing services and transaction costs.

Assets by reportable segment follow.


	June 30, 2022		December 31, 2021
	(In thousands)
Assets:
Northeast	$	610,167	$	623,224
Rockies	576,087		592,148
Permian	300,994		458,988
Piceance	501,137		524,218
Barnett	305,855		315,055
Total reportable segment assets	2,294,240		2,513,633
Corporate and Other	16,093		8,829
Total assets	$	2,310,333	$	2,522,462

Segment adjusted EBITDA by reportable segment follows.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands)
Reportable segment adjusted EBITDA
Northeast	$	18,568	$	23,361	$	38,636	$	43,554
Rockies	13,899		14,732		29,729		30,884
Permian	4,817		1,341		8,966		2,592
Piceance	15,350		20,324		31,118		41,358
Barnett	7,247		8,889		16,533		16,905
Total of reportable segments' measures of profit	$	59,881	$	68,647	$	124,982	$	135,293

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A reconciliation of income or loss before income taxes and income from equity method investees to total of reportable segments' measures of profit follows.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands)
Reconciliation of income (loss) before income taxes and
income from equity method investees to total of
reportable segments' measures of profit:
Income (loss) before income taxes and income from equity method investees	$	(95,872)	$	(22,290)	$	(99,862)	$	(15,631)
Add:
Corporate and Other expense	5,809		41,144		9,627		49,482
Interest expense	24,887		15,502		49,050		29,455
Depreciation and amortization (1)	30,346		28,598		61,025		57,344
Proportional adjusted EBITDA for equity method investees	11,406		6,841		21,858		13,713
Adjustments related to capital reimbursement activity	(1,578)		(2,225)		(3,306)		(3,470)
Unit-based and noncash compensation	582		1,048		2,272		3,015
Gain on asset sales, net	(313)		(4)		(310)		(140)
Long-lived asset impairment	84,614		33		84,628		1,525
Total of reportable segments' measures of profit	$	59,881	$	68,647	$	124,982	$	135,293

________

(1) Includes the amortization expense associated with our favorable gas gathering contracts as reported in other revenues.

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

This Management’s Discussion and Analysis of Financial Condition and Results of Operations (“MD&A”) is intended to inform the reader about matters affecting the financial condition and results of operations of the Partnership and its subsidiaries for the periods since December 31, 2021. As a result, the following discussion should be read in conjunction with the unaudited condensed consolidated financial statements and notes thereto included in this report and the MD&A and the audited consolidated financial statements and related notes that are included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2021 (the “2021 Annual Report”). Among other things, those financial statements and the related notes include more detailed information regarding the basis of presentation for the following information. This discussion contains forward-looking statements that constitute our plans, estimates and beliefs. These forward-looking statements involve numerous risks and uncertainties, including, but not limited to, those discussed in Forward-Looking Statements. Actual results may differ materially from those contained in any forward-looking statements.

Overview

We are a value-driven limited partnership focused on developing, owning and operating midstream energy infrastructure assets that are strategically located in unconventional resource basins, primarily shale formations, in the continental United States.

Our financial results are driven primarily by volume throughput across our gathering systems and by expense management. We generate the majority of our revenues from the gathering, compression, treating and processing services that we provide to our customers. A majority of the volumes that we gather, compress, treat and/or process have a fixed-fee rate structure which enhances the stability of our cash flows by providing a revenue stream that is not subject to direct commodity price risk. We also earn a portion of our revenues from the following activities that directly expose us to fluctuations in commodity prices: (i) the sale of physical natural gas and/or NGLs purchased under percentage-of-proceeds or other processing arrangements with certain of our customers in the Rockies, and Piceance segments, (ii) the sale of natural gas we retain from certain Barnett segment customers, (iii) the sale of condensate we retain from our gathering services in the Piceance segment and (iv) additional gathering fees that are tied to the performance of certain commodity price indexes which are then added to the fixed gathering rates.

We also have indirect exposure to changes in commodity prices such that persistently low commodity prices may cause our customers to delay and/or cancel drilling and/or completion activities or temporarily shut-in production, which would reduce the volumes of natural gas and crude oil (and associated volumes of produced water) that we gather. If certain of our customers cancel or delay drilling and/or completion activities or temporarily shut-in production, the associated MVCs, if any, ensure that we will earn a minimum amount of revenue. Commodity prices have increased and remain at higher levels primarily due to Russia’s invasion of Ukraine beginning in February 2022, which mitigates the risk of cancelled or delayed drilling and/or completion activities.

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The following table presents certain consolidated and reportable segment financial data. For additional information on our reportable segments, see the "Segment Overview for the Three and Six Months Ended June 30, 2022 and 2021" section included herein.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands)				(In thousands)
Net loss	$	(91,804)	$	(19,738)	$	(91,809)	$	(10,750)
Reportable segment adjusted EBITDA
Northeast	$	18,568	$	23,361	$	38,636	$	43,554
Rockies	13,899		14,732		29,729		30,884
Permian	4,817		1,341		8,966		2,592
Piceance	15,350		20,324		31,118		41,358
Barnett	7,247		8,889		16,533		16,905

Net cash provided by operating activities	$	14,113	$	34,787	$	60,159	$	86,217
Capital expenditures (1)	6,091		3,352		14,794		5,962
Proceeds from the disposition of Lane G&P System, net of cash sold in transaction	75,520		—		75,520		—
Investment in Double E equity method investee (2)	—		43,324		8,444		48,943

Repayments on ABL Facility	(105,000)		—		(139,000)		—
Repayments on Revolving Credit Facility	—		(40,000)		—		(95,000)
Borrowings on ABL Facility	23,000		—		23,000		—
Repayments on Permian Transmission Term Loan	(1,147)		—		(2,242)		—
Borrowings under Permian Transmission Credit Facility	—		36,000		—		53,500

________

(1)See "Liquidity and Capital Resources" herein to the unaudited condensed consolidated financial statements for additional information on capital expenditures.

(2)Inclusive of $0.6 and $1.6 million, respectively, of capitalized interest for the three and six months ended June 30, 2021. There was no capitalized interest recorded for the three and six months ended June 30, 2022.

Trends and Outlook

Our business has been, and we expect our future business to continue to be, affected by the following key trends:

•Ongoing impact of the COVID-19 pandemic and fluctuations in demand for oil and natural gas;

•Ongoing impact of the current Russia-Ukraine conflict and the international sanctions against Russia on commodity prices;

•Natural gas, NGL and crude oil supply and demand dynamics;

•Production from U.S. shale plays;

•Capital markets availability and cost of capital; and

•Inflation and shifts in operating costs.

Our expectations are based on assumptions made by us and information currently available to us. To the extent our underlying assumptions about, or interpretations of, available information prove to be incorrect, our actual results may vary materially from our expected results. For additional information, see the "Trends and Outlook" section of MD&A included in the 2021 Annual Report.

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Ongoing impact of the COVID-19 pandemic and fluctuations in demand for oil and natural gas. We continue to closely monitor the impact of the COVID-19 pandemic, including its variants, on all aspects of our business, including how it has impacted and will impact our customers, employees, supply chain and distribution network. In response to the COVID-19 pandemic, we modified our business practices, including restricting employee travel and utilizing COVID-19 pandemic tax relief in 2021 (as allowed by the Consolidated Appropriations Act, 2021, the "ERC Tax Credit"). We are unable to predict the broader implications of and the ultimate impact that COVID-19, its variants and related factors may have on our business, future results of operations, financial position or cash flows. Given the dynamic nature of the COVID-19 pandemic and related market conditions, we cannot reasonably estimate the period of time that these events will persist or the full extent of the impact they will have on our business. The extent to which our operations continue to be impacted by the COVID-19 pandemic will depend largely on future developments, which remain highly uncertain and cannot be accurately predicted, including changes in the severity of the pandemic, countermeasures taken by governments, businesses and individuals to slow the spread of the pandemic, and the development and availability of treatments and the extent to which these treatments and vaccines may remain effective as potential new strains of COVID-19 emerge.

We have collaborated extensively with our customer base regarding impacts to their drilling and completion activities in light of the COVID-19 pandemic. Based on recently updated production forecasts and 2022 development plans from our customers, we currently expect that 2022 activity will be lower than historical periods prior to COVID-19, notwithstanding the recent increase in commodity prices primarily driven by Russia’s invasion of Ukraine in February 2022.

Ongoing impact of the current Russia-Ukraine conflict and the international sanctions against Russia on commodity prices. In February of 2022, Russia invaded Ukraine and is still engaged in active armed conflict against the country. As a result, governments in the European Union, the United States and other countries have enacted additional sanctions against Russia, certain of its citizens and Russian interests.

Although the Partnership does not operate in Ukraine, Russia or other parts of Europe, there are certain impacts arising from Russia’s invasion of Ukraine that could have a potential effect on the Partnership, including, but not limited to, volatility in currencies and commodity prices, higher inflation, cost and supply chain pressures and availability and disruptions in banking systems and capital markets. As of the date of filing, there have been no material impacts.

Cost structure optimization and portfolio management. The Partnership intends to optimize its capital structure in the future by reducing its indebtedness with free cash flow, and when appropriate, it may pursue opportunistic transactions with the objective of increasing long term unitholder value. This may include opportunistic acquisitions, divestitures (such as the disposition of the Lane G&P System), re-allocation of capital to new or existing areas, and development of joint ventures involving our existing midstream assets or new investment opportunities. We believe that our internally generated cash flow, our ABL Facility, the Permian Term Loan Facility, and access to debt or equity will be adequate to finance our strategic initiatives. To attain our overall corporate strategic objectives, we may conduct an asset divestiture, or divestitures, at a transaction valuation that is less than the net book value of the divested asset.

How We Evaluate Our Operations

We conduct and report our operations in the midstream energy industry through five reportable segments: Northeast, Rockies, Permian, Piceance and Barnett. Each of our reportable segments provides midstream services in a specific geographic area and 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. For additional information see Note 15 - Segment Information.

Our management uses a variety of financial and operational metrics to analyze our consolidated and segment performance. We view these metrics as important factors in evaluating our profitability. These metrics include:

•throughput volume;

•revenues;

•operation and maintenance expenses;

•capital expenditures; and

•segment adjusted EBITDA.

We review these metrics on a regular basis for consistency and trend analysis. There have been no changes in the composition or characteristics of these metrics during the three and six months ended June 30, 2022.

Additional Information. For additional information, see the "Results of Operations" section herein and the notes to the unaudited condensed consolidated financial statements. For additional information on how these metrics help us manage our business, see the "How We Evaluate Our Operations" section of MD&A included in the 2021 Annual Report. For information on impending accounting changes that are expected to materially impact our financial results reported in future periods, see Note 2 – Summary of Significant Accounting Policies and Recently Issued Accounting Standards applicable to the Partnership.

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Results of Operations

Consolidated Overview for the Three and Six Months Ended June 30, 2022 and 2021

The following table presents certain consolidated financial and operating data.


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
	(In thousands)				(In thousands)
Revenues:
Gathering services and related fees	$	61,631	$	74,233	$	125,651	$	144,580
Natural gas, NGLs and condensate sales	28,278		16,416		50,736		37,180
Other revenues	9,154		9,392		18,802		17,599
Total revenues	99,063		100,041		195,189		199,359
Costs and expenses:
Cost of natural gas and NGLs	26,831		16,626		49,082		37,102
Operation and maintenance	22,277		17,507		39,339		34,100
General and administrative(2)	10,473		29,360		23,433		39,938
Depreciation and amortization	30,111		28,364		60,556		56,875
Transaction costs	(13)		450		233		217
Gain on asset sales, net	(313)		(4)		(310)		(140)
Long-lived asset impairment	84,614		33		84,628		1,525
Total costs and expenses	173,980		92,336		256,961		169,617
Other income (expense), net	(4)		352		(4)		408
Gain (loss) on interest rate swaps	3,936		(2,686)		10,964		(2,692)
Loss on ECP Warrants	—		(12,159)		—		(13,634)
Interest expense	(24,887)		(15,502)		(49,050)		(29,455)

Loss before income taxes and equity method investment income	(95,872)		(22,290)		(99,862)		(15,631)
Income tax (expense) benefit	(325)		248		(375)		262
Income from equity method investees	4,393		2,304		8,428		4,619
Net loss	$	(91,804)	$	(19,738)	$	(91,809)	$	(10,750)

Volume throughput (1):
Aggregate average daily throughput - natural gas (MMcf/d)	1,200		1,441		1,254		1,393
Aggregate average daily throughput - liquids (Mbbl/d)	54		63		60		64

________

(1)Excludes volume throughput for Ohio Gathering and Double E. For additional information, see the Northeast and Permian sections herein under the caption “Segment Overview for the Three and Six Months Ended June 30, 2022 and 2021”.

(2)Includes a $19.3 million incremental loss contingency recognized during the three and six months ended June 30, 2021 for the 2015 Blacktail Release (See Note 14 - Commitments and Contingencies for additional information).

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Volumes – Gas.

Natural gas throughput volumes decreased 241 MMcf/d for the three months ended June 30, 2022 compared to the three months ended June 30, 2021, primarily reflecting:

•a volume throughput decrease of 221 MMcf/d for the Northeast segment.

•a volume throughput decrease of 14 MMcf/d for the Piceance segment.

•a volume throughput decrease of 2 MMcf/d for the Permian segment.

•a volume throughput decrease of 6 MMcf/d for the Rockies segment.

•a volume throughput increase of 2 MMcf/d for the Barnett segment.

Natural gas throughput volumes decreased 139 MMcf/d for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, primarily reflecting:

•a volume throughput decrease of 113 MMcf/d for the Northeast segment.

•a volume throughput decrease of 22 MMcf/d for the Piceance segment.

•a volume throughput decrease of 2 MMcf/d for the Permian segment.

•a volume throughput decrease of 6 MMcf/d for the Rockies segment.

•a volume throughput increase of 4 MMcf/d for the Barnett segment.

Volumes – Liquids.

Crude oil and produced water throughput volumes at the Rockies segment decreased for the three and six months ended June 30, 2022, compared to the three and six months ended June 30, 2021, primarily as a result of natural production declines and weather related downtime, offset by 31 new well connections that came online subsequent to June 30, 2021.

For additional information on volumes, see the "Segment Overview for the Three and Six Months Ended June 30, 2022 and 2021" section herein.

Revenues. Total revenues decreased $1.0 million during the three months ended June 30, 2022 compared to the prior year period, comprised of a $11.9 million increase in natural gas, NGLs and condensate sales, offset by a $12.6 million decrease in gathering services and related fees and a $0.2 million decrease in Other Revenue.

Gathering Services and Related Fees. Gathering services and related fees decreased $12.6 million compared to the three months ended June 30, 2021, primarily reflecting:

•a $5.5 million decrease in the Piceance, primarily due to decreased volume throughput and the expiration of a customer’s minimum volume commitment;

•a $5.0 million decrease in the Northeast, primarily due to decreased volume throughput;

•a $1.9 million decrease in the Rockies, primarily due to decreased volume throughput and the expiration of a customer’s minimum volume commitment contract in the DJ basin.

Natural Gas, NGLs and Condensate Sales. Natural gas, NGLs and condensate revenues increased $11.9 million compared to the three months ended June 30, 2021, primarily reflecting:

•a $6.4 million increase in revenues in the Rockies, primarily as a result of increased commodity prices;

•a $3.6 million increase in revenues from the Permian, primarily as a result of increased commodity prices.

Total revenues decreased $4.2 million during the six months ended June 30, 2022 compared to the prior year period, comprised of an $18.9 million decrease in gathering services and related fees; offset by a $13.6 million increase in natural gas, NGLs and condensate sales, a $1.2 million increase in Other Revenue.

Gathering Services and Related Fees. Gathering services and related fees decreased $18.9 million compared to the six months ended June 30, 2021, primarily reflecting:

•a $10.3 million decrease in the Piceance, primarily due to decreased volume throughput and the expiration of a customer’s minimum volume commitment;

•a $5.2 million decrease in the Northeast, primarily due to decreased volume throughput;

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•a $3.0 million decrease in the Rockies, primarily due to decreased volume throughput and the expiration of a customer’s minimum volume commitment contract in the DJ basin.

Natural Gas, NGLs and Condensate Sales. Natural gas, NGLs and condensate revenues increased $13.6 million compared to the six months ended June 30, 2021, primarily reflecting:

•a $7.7 million increase in revenues in the Rockies, primarily as a result of increased commodity prices; and

•a $4.0 million increase in the Permian, primarily due to increased commodity prices.

Costs and Expenses. Total costs and expenses increased $81.6 million during the three months ended June 30, 2022 compared to the three months ended June 30, 2021.

Total costs and expenses increased $87.3 million during the six months ended June 30, 2022 compared to the six months ended June 30, 2021.

Cost of Natural Gas and NGLs. Cost of natural gas and NGLs increased $10.2 million for the three months ended June 30, 2022 compared to the three months ended June 30, 2021, primarily driven by an increase in commodity prices.

Cost of natural gas and NGLs increased $12.0 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, primarily driven by an increase in commodity prices.

Operation and Maintenance. Operation and maintenance expense increased $4.8 million for the three months ended June 30, 2022 compared to the three months ended June 30, 2021 primarily as a result of the 2021 recognition of certain commercial settlement benefits and the employee retention tax credit (“ERC Tax Credit”) that were not repeated in 2022.

Operation and maintenance expense increased $5.2 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, primarily as a result of the 2021 recognition of certain commercial settlement benefits and the ERC Tax Credit that were not repeated in 2022 and totaled $5.6 million for the six months ended June 2021.

General and Administrative. General and administrative expense decreased $18.9 million for the three months ended June 30, 2022 compared to the three months ended June 30, 2021, primarily related to the nonrecurrence of a $19.3 million loss contingency recognized in 2021 (for the 2015 Blacktail Release) and partially offset by $1.0 million of deal costs.

General and administrative expense decreased $16.5 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021, primarily related to the nonrecurrence of a $19.3 million loss contingency recognized in 2021 (for the 2015 Blacktail Release), partially offset by $2.4 million of employee severance costs and $1.1 million of deal costs incurred during the six months ended June 30, 2022.

Depreciation and Amortization. Depreciation and amortization expense increased $1.7 million for the three months ended June 30, 2022 compared to the three months ended June 30, 2021 primarily as a result of increased depreciation expense on certain gas processing equipment.

Depreciation and amortization expense increased $3.7 million for the six months ended June 30, 2022 compared to the six months ended June 30, 2021 primarily as a result of increased depreciation expense on certain gas processing equipment.

Asset Impairments. During the quarterly period ended June 30, 2022, the Partnership recognized an impairment of $84.5 million related to the disposition of the Lane G&P System.

Interest Expense. Interest expense increased $9.4 million for the three months ended June 30, 2022, compared to the three months ended June 30, 2021, primarily due to higher interest costs resulting from the issuance of the 2026 Secured Notes and borrowings on the Permian Transmission Term Loan, partially offset by principal reduction payments to our credit facilities (ABL Facility and Revolving Credit Facility).

Interest expense increased $19.6 million for the six months ended June 30, 2022, compared to the six months ended June 30, 2021, primarily due to higher interest costs resulting from the issuance of the 2026 Secured Notes and borrowings on the Permian Transmission Term Loan, partially offset by principal reduction payments to our credit facilities (ABL Facility and Revolving Credit Facility).

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Segment Overview for the Three and Six Months Ended June 30, 2022 and 2021

Northeast.

Volume throughput for the Northeast reportable segment follows.


	Northeast
	Three Months Ended June 30,			Six Months Ended June 30,
	2022	2021	Percentage Change	2022	2021	Percentage Change
Average daily throughput (MMcf/d)	632	853	(26)%	687	800	(14)%
Average daily throughput (MMcf/d) (Ohio Gathering)	562	514	9%	580	536	8%

Volume throughput for the Northeast, excluding Ohio Gathering, decreased 26% and 14% compared to the three and six months ended June 30, 2021, respectively, primarily due to natural production declines, maintenance related downtime, and frac-protect activities, partially offset by 18 well connections that came online subsequent to June 30, 2021.

Volume throughput for the Ohio Gathering system increased 9% and 8% compared to the three and six months ended June 30, 2021, respectively, primarily as a result of 16 new well connections that came online subsequent to June 30, 2021, partially offset by natural production declines and frac-protect activities.

Financial data for our Northeast reportable segment follows.


	Northeast
	Three Months Ended June 30,					Six Months Ended June 30,
	2022		2021		Percentage Change	2022		2021		Percentage Change
	(In thousands)					(In thousands)
Revenues:
Gathering services and related fees	$	12,940	$	17,961	(28)%	$	27,576	$	32,733	(16)%
Total revenues	12,940		17,961		(28)%	27,576		32,733		(16)%
Costs and expenses:
Operation and maintenance	1,588		1,316		21%	3,235		2,596		25%
General and administrative	237		104		128%	420		254		65%
Depreciation and amortization	4,338		4,229		3%	8,638		8,459		2%
(Gain) loss on asset sales, net	—		8		*	(10)		(54)		*
Long-lived asset impairment	—		(8)		*	—		130		*
Total costs and expenses	6,163		5,649		9%	12,283		11,385		8%
Add:
Depreciation and amortization	4,338		4,229			8,638		8,459
Adjustments related to capital reimbursement activity	(20)		(21)			(40)		(42)
(Gain) loss on asset sales, net	—		8			(10)		(54)
Long-lived asset impairment	—		(8)			—		130
Proportional adjusted EBITDA for Ohio Gathering	7,473		6,841			14,749		13,713
Other	—		—			6		—
Segment adjusted EBITDA	$	18,568	$	23,361	(21)%	$	38,636	$	43,554	(11)%

________

* Not considered meaningful

Three and six months ended June 30, 2022. Segment adjusted EBITDA decreased $4.8 million and $4.9 million, respectively, compared to the three and six months ended June 30, 2021 primarily as a result of a $5.0 million and $5.2 million, respectively, decrease in revenues from gathering services and related fees for the three and six months ended June 30, 2022, partially offset by a $0.6 million and $1.0 million, respectively, increase in proportional adjusted EBITDA from Ohio Gathering.

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Rockies.

Volume throughput for our Rockies reportable segment follows.


	Rockies
	Three Months Ended June 30,			Six Months Ended June 30,
	2022	2021	Percentage Change	2022	2021	Percentage Change
Aggregate average daily throughput - natural gas (MMcf/d)	29	35	(17%)	29	35	(17%)
Aggregate average daily throughput - liquids (Mbbl/d)	54	63	(14%)	60	64	(6%)

Natural gas. Natural gas volume throughput decreased 17% compared to the three and six months ended June 30, 2021, primarily reflecting natural production declines and weather related downtime, partially offset by five new well connections that came online subsequent to June 30, 2021.

Liquids. Liquids volume throughput decreased 14% and 6% compared to the three and six months ended June 30, 2021, primarily associated with natural product declines and operational and weather related downtime, partially offset by 31 new well connections that came online subsequent to June 30, 2021.

Financial data for our Rockies reportable segment follows.


	Rockies
	Three Months Ended June 30,						Six Months Ended June 30,
	2022			2021		Percentage Change	2022			2021		Percentage Change
	(In thousands)						(In thousands)
Revenues:
Gathering services and related fees	$	16,510		$	18,407	(10)%	$	34,299		$	37,303	(8%)
Natural gas, NGLs and condensate sales	14,927			8,506		75%	28,586			20,843		37%
Other revenues	4,728			6,098		(22)%	9,885			11,309		(13)%
Total revenues	36,165			33,011		10%	72,770			69,455		5%
Costs and expenses:
Cost of natural gas and NGLs	14,207			8,762		62%	27,629			21,103		31%
Operation and maintenance	7,214			7,365		(2%)	13,426			14,201		(5%)
General and administrative	515			1,682		(69%)	1,199			2,355		(49%)
Depreciation and amortization	7,471			7,459		0%	14,919			14,933		0%
(Gain) loss on asset sales, net	—			(5)		*	14			(22)		*
Long-lived asset impairment	98			41		*	111			136		*
Total costs and expenses	29,505			25,304		17%	57,298			52,706		9%
Add:
Depreciation and amortization	7,471			7,459			14,919			14,933

Adjustments related to capital reimbursement activity	(462)			(470)			(940)			(935)
(Gain) loss on asset sales, net	—			(5)			14			(22)
Long-lived asset impairment	98			41			111			136
Other	132		—	—			153		—	23
Segment adjusted EBITDA	$	13,899		$	14,732	(6)%	$	29,729		$	30,884	(4%)

_______

* Not considered meaningful

Three and six months ended June 30, 2022. Segment adjusted EBITDA decreased $0.8 million and $1.2 million, respectively, compared to the three and six months ended June 30, 2021 primarily due to lower volume throughput on our systems as previously discussed, as well as the expiration of a customer’s minimum volume commitment contract in the DJ basin, partially offset by $0.2 million and $0.8 million, respectively, of lower operating and maintenance expenses.

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Permian.

Volume throughput for our Permian reportable segment follows.


	Permian
	Three Months Ended June 30,			Six Months Ended June 30,
	2022	2021	Percentage Change	2022	2021	Percentage Change
Average daily throughput (MMcf/d)	27	29	(7%)	27	29	(7%)
Average daily throughput (MMcf/d) (Double E)	314	—	n/a	251	—	n/a

On June 30, 2022, we completed the sale of our Lane G&P System. The volumes above include daily volume throughput data through the date of sale. Subsequent to the date of sale, the Permian reportable segment will consist solely of our equity method investment in Double E.

Volume throughput, excluding Double E, decreased 7% compared to the three and six months ended June 30, 2021, primarily as a result of natural production declines, partially offset by four new connections that came online subsequent to June 30, 2021.

Double E commenced operations during November 2021. Volume throughput for Double E for the three and six months ended June 30, 2021 averaged 314 MMcf per day and 251 MMcf per day, respectively.

The following table presents the MVC quantities that Double E’s shippers have contracted to with firm transportation service agreements and related negotiated rate agreements.


(Amounts in MMBTU/day)			Weighted average MVC quantities for the year ended December 31,
2022			622,603
2023			839,247
2024			990,205
2025			1,000,000
2026			1,000,178
2027			1,000,000
2028			1,002,562
2029			1,000,000
2030			1,000,000
2031			832,877

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Financial data for our Permian reportable segment follows.


	Permian
	Three Months Ended June 30,					Six Months Ended June 30,
	2022		2021		Percentage Change	2022		2021		Percentage Change
	(In thousands)					(In thousands)
Revenues:
Gathering services and related fees	$	1,822	$	2,262	(19%)	$	3,669	$	4,461	(18%)
Natural gas, NGLs and condensate sales	10,514		6,875		53%	17,381		13,393		30%
Other revenues	1,298		1,049		24%	2,317		1,809		28%
Total revenues	13,634		10,186		34%	23,367		19,663		19%
Costs and expenses:
Cost of natural gas and NGLs	10,721		7,167		50%	17,813		14,183		26%
Operation and maintenance	1,779		1,527		17%	3,083		2,519		22%
General and administrative	187		166		13%	550		384		43%
Depreciation and amortization	1,236		1,464		(16)%	2,733		2,933		(7)%
Gain on asset sales, net	(13)		—		*	(13)		—		*
Long-lived asset impairment	84,516		—		*	84,516		—		*
Total costs and expenses	98,426		10,324		853%	108,682		20,019		443%
Add:
Depreciation and amortization	1,236		1,464			2,733		2,933
Adjustments related to capital reimbursement activity	(63)		—			(63)		—
Gain on asset sales, net	(13)		—			(13)		—
Long-lived asset impairment	84,516		—			84,516		—
Proportional adjusted EBITDA for Double E	3,933		—			7,108		—
Other	—		15			—		15
Segment adjusted EBITDA	$	4,817	$	1,341	259%	$	8,966	$	2,592	246%

________

*Not considered meaningful

Three and six months ended June 30, 2022. Segment adjusted EBITDA increased $3.5 million and $6.4 million compared to the three and six months ended June 30, 2021, primarily reflecting an increase in proportional adjusted EBITDA from Double E.

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Piceance.

Volume throughput for our Piceance reportable segment follows.


	Piceance
	Three Months Ended June 30,			Six Months Ended June 30,
	2022	2021	Percentage Change	2022	2021	Percentage Change
Aggregate average daily throughput (MMcf/d)	312	326	(4%)	312	334	(7%)

Volume throughput decreased 4% and 7%, respectively, compared to the three and six months ended June 30, 2021, as a result of natural production declines, partially offset by 9 new well connections that came online in October 2021.

Financial data for our Piceance reportable segment follows.


	Piceance
	Three Months Ended June 30,					Six Months Ended June 30,
	2022		2021		Percentage Change	2022		2021		Percentage Change
	(In thousands)					(In thousands)
Revenues:
Gathering services and related fees	$	19,981	$	25,527	(22%)	$	40,052	$	50,311	(20%)
Natural gas, NGLs and condensate sales	2,067		1,025		102%	3,962		2,878		38%
Other revenues	1,276		1,233		3%	2,551		2,409		6%
Total revenues	23,324		27,785		(16%)	46,565		55,598		(16%)
Costs and expenses:
Cost of natural gas and NGLs	1,266		697		82%	2,374		1,816		31%
Operation and maintenance	5,785		5,367		8%	11,058		10,309		7%
General and administrative	326		345		(6)%	654		643		2%
Depreciation and amortization	12,846		10,757		19%	25,626		21,631		18%
(Gain) loss on asset sales, net	(300)		4		*	(300)		(53)		*
Long-lived asset impairment	—		—		*	—		970		*
Total costs and expenses	19,923		17,170		16%	39,412		35,316		12%
Add:
Depreciation and amortization	12,846		10,757			25,626		21,631

Adjustments related to capital reimbursement activity	(702)		(1,403)			(1,601)		(1,831)
(Gain) loss on asset sales, net	(300)		4			(300)		(53)
Long-lived asset impairment	—		—			—		970
Other	105		351			240		359
Segment adjusted EBITDA	$	15,350	$	20,324	(24%)	$	31,118	$	41,358	(25%)

________

*Not considered meaningful

Three and six months ended June 30, 2022. Segment adjusted EBITDA decreased $5.0 million and $10.2 million, respectively, compared to the three and six months ended June 30, 2021, primarily reflecting a decrease in volume throughput as a result of natural production declines as discussed above as well as $3.6 million and $7.0 million in reduced revenue for the three and six month periods, respectively, related to the expiration of a customer’s minimum volume commitment contract in 2021.

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Barnett.

Volume throughput for our Barnett reportable segment follows.


	Barnett
	Three Months Ended June 30,			Six Months Ended June 30,
	2022	2021	Percentage Change	2022	2021	Percentage Change
Average daily throughput (MMcf/d)	200	198	1%	199	195	2%

Volume throughput increased 1% and 2% compared to the three and six months ended June 30, 2021, primarily as a result of eleven wells that came online subsequent to June 30, 2021, partially offset by natural production declines.

Financial data for our Barnett reportable segment follows.


	Barnett
	Three Months Ended June 30,					Six Months Ended June 30,
	2022		2021		Percentage Change	2022		2021		Percentage Change
	(In thousands)					(In thousands)
Revenues:
Gathering services and related fees	$	10,378	$	10,076	3%	$	20,055	$	19,772	1%
Natural gas, NGLs and condensate sales	786		10		7,760%	786		66		1,091%
Other revenues (1)	1,671		1,012		65%	3,734		2,072		80%
Total revenues	12,835		11,098		16%	24,575		21,910		12%
Costs and expenses:

Operation and maintenance	5,220		1,852		182%	7,344		4,316		70%
General and administrative	272		260		5%	514		495		4%
Depreciation and amortization	3,790		3,798		—	7,582		7,596		—
Gain on asset sales, net	—		(11)		*	—		(11)		*
Long-lived asset impairment	—		—		*	—		289		*
Total costs and expenses	9,282		5,899		57%	15,440		12,685		22%
Add:
Depreciation and amortization	4,025		4,032			8,051		8,064
Adjustments related to capital reimbursement activity	(331)		(331)			(658)		(662)
Gain on asset sales, net	—		(11)			—		(11)
Long-lived asset impairment	—		—			—		289
Other	—		—			5		—
Segment adjusted EBITDA	$	7,247	$	8,889	(18)%	$	16,533	$	16,905	(2)%

________

*Not considered meaningful

(1)Includes the amortization expense associated with our favorable gas gathering contracts as reported in Other revenues.

Three and six months ended June 30, 2022. Segment adjusted EBITDA decreased $1.6 million and $0.4 million, respectively, compared to the three and six months ended June 30, 2021, primarily as a result of higher general operating expenses that resulted from the nonrecurrence of commercial settlements that benefited the segment’s financial results in 2021, partially offset by a $0.7 million and $1.7 million increase in other revenues for the three and six months ended June 30, 2022.

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Corporate and Other Overview for the Three and Six Months Ended June 30, 2022 and 2021

Corporate and Other represents those results that are not specifically attributable to a reportable segment or that have not been allocated to our reportable segments, including certain general and administrative expense items, natural gas and crude oil marketing services, transaction costs and interest expense.


	Corporate and Other
	Three Months Ended June 30,					Six Months Ended June 30,
	2022		2021		Percentage Change	2022		2021		Percentage Change
	(In thousands)					(In thousands)
Revenues:
Total revenues	$	165	$	—	*	$	336	$	—	*
Costs and expenses:
Operation and maintenance	$	691	$	80	*	$	1,193	$	159	*
General and administrative(1)	8,936		26,803		(67)%	20,096		35,808		(44)%
Transaction costs	(13)		450		*	233		217		*
Interest expense	24,887		15,502		61%	49,050		29,455		67%

________

* Not considered meaningful

(1)Inclusive of a $19.3 million incremental loss contingency accrual during the three months ended June 30, 2021 related to the 2015 Blacktail Release (See Note 14 - Commitments and Contingencies for additional information).

General and Administrative. General and administrative expense decreased by $17.9 million, compared to the three months ended June 30, 2021, primarily related to the nonrecurrence of a $19.3 million loss contingency recognized in 2021 (for the 2015 Blacktail Release) and partially offset by $1.0 million of deal costs.

General and administrative expense decreased by $15.7 million, compared to the six months ended June 30, 2021, primarily related to primarily related to the nonrecurrence of a $19.3 million loss contingency recognized in 2021 (for the 2015 Blacktail Release), partially offset by $2.4 million of employee severance costs and $1.1 million of deal costs incurred during the six months ended June 30, 2022.

Interest Expense. The increase in interest expense for the three and six months ended June 30, 2022, compared to three and six months ended June 30, 2021, was primarily due to higher interest costs resulting from the issuance of the 2026 Secured Notes and borrowings on the Permian Transmission Term Loan, partially offset by principal reduction payments to our credit facilities (ABL Facility and Revolving Credit Facility).

Liquidity and Capital Resources

We rely primarily on internally generated cash flows as well as external financing sources, including our ABL Facility, and the issuance of debt, equity and preferred equity securities, and proceeds from potential asset divestitures to fund our capital expenditures. We believe that our ABL Facility and Permian Transmission Credit Facility, together with internally generated cash flows and access to debt or equity capital markets, will be adequate to finance our operations for the next twelve months without adversely impacting our liquidity.

We may enter into off-balance sheet arrangements and transactions that can give rise to material off-balance sheet obligations. As of June 30, 2022, our material off-balance sheet arrangements and transactions include (i) letters of credit outstanding against our ABL Facility aggregating to $5.9 million, (ii) letters of credit outstanding against our Permian Transmission Credit Facility aggregating to $7.5 million. There are no other transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect our liquidity or availability of our capital resources.

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Indebtedness Compliance as of June 30, 2022. As of June 30, 2022, we were in compliance with all covenants contained in the Senior Notes, ABL Facility and the Permian Transmission Credit Facility. The ABL Facility requires that Summit Holdings not permit (i) the First Lien Net Leverage Ratio (as defined in the ABL Agreement) as of the last day of any fiscal quarter to be greater than 2.50:1.00, or (ii) the Interest Coverage Ratio (as defined in the ABL Agreement) as of the last day of any fiscal quarter to be less than 2.00:1.00. As of June 30, 2022, the First Lien Net Leverage Ratio and Interest Coverage Ratio was 0.64:1.00 and 2.73:1.00, respectively.

Credit Agreements and Financing Activities

ABL Facility. As of June 30, 2022, we had a $400.0 million revolving ABL Facility with a maturity date of May 1, 2026. As of June 30, 2022, the outstanding balance of the ABL Facility was $151.0 million and the available borrowing capacity totaled $243.1 million after giving effect to the issuance thereunder of $5.9 million of outstanding but undrawn irrevocable standby letters of credit.

We may in the future use a combination of cash, secured or unsecured borrowings and issuances of our common units or other securities and the proceeds from asset sales to retire or refinance our outstanding debt or Series A Preferred Units through privately negotiated transactions, open market repurchases, redemptions, exchange offers, tender offers or otherwise, but we are under no obligation to do so.

LIBOR Transition

LIBOR is the basic rate of interest widely used as a reference for setting the interest rates on loans globally. In 2017, the United Kingdom’s Financial Conduct Authority, which regulates LIBOR, announced that it intended to phase out LIBOR by the end of 2021. The U.S. Federal Reserve, in conjunction with the Alternative Reference Rates Committee, a steering committee comprised of large U.S. financial institutions, is considering replacing U.S. dollar LIBOR with a new index, the Secured Overnight Financing Rate (“SOFR”), calculated using short-term repurchase agreements backed by Treasury securities. After December 31, 2021, the United Kingdom ceased publications of certain LIBOR tenors and expects to cease publications of all USD LIBOR tenors after June 30, 2023. We are evaluating the potential impact of the eventual replacement of the LIBOR benchmark interest rate, however, we are not able to predict when LIBOR will cease to be available, whether SOFR will become a widely accepted benchmark in place of LIBOR or what the impact of such a possible transition to SOFR may be on our business, financial condition and results of operations.

The ABL Facility includes an ability of the administrative agent to transition loans based on LIBOR to loans based on term SOFR or daily simple SOFR. The adjustment rate upon a transition to term SOFR is 11.448 bps for a one-month tenor, 26.161 bps for a three-month tenor, 42.826 for a six-month tenor, and 71.513 for a twelve-month tenor. This transition has not yet occurred with the ABL Facility.

Cash Flows

The components of the net change in cash and cash equivalents were as follows:


	Six Months Ended June 30,
	2022		2021
	(In thousands)
Net cash provided by operating activities	$	60,159	$	86,217
Net cash provided by (used in) investing activities	56,882		(46,905)
Net cash used in financing activities	(120,913)		(47,331)
Net change in cash, cash equivalents and restricted cash	$	(3,872)	$	(8,019)

Operating activities.

Cash flows provided by operating activities for the six months ended June 30, 2022 primarily reflected:

•a net loss of $91.8 million plus positive adjustments of $152.9 million for non-cash operating items.

Cash flows provided by operating activities for the six months ended June 30, 2021 primarily reflected:

•net loss of $10.8 million plus adjustments of $90.5 million for non-cash items; and

• $6.4 million increase in working capital accounts.

Investing activities.

Cash flows provided by investing activities during the six months ended June 30, 2022 primarily reflected:

•$75.5 million of cash proceeds from the disposition of the Lane G&P System, net of cash sold in the transaction;

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•$4.6 million of cash proceeds from the sale of compressors; offset by

•$14.8 million cash outflow for capital expenditures; and

•$8.4 million of cash investments in the Double E Project.

Cash flows used in investing activities during the six months ended June 30, 2021 primarily reflected:

•$48.9 million for cash investments in the Double E Project;

•$6.0 million cash outflow for capital expenditures; offset by

•$8.0 million of cash proceeds from the sale of compressors.

Financing activities.

Cash flows used in financing activities during the six months ended June 30, 2022 primarily reflected:

•$139.0 million of cash outflow for repayments on the ABL Facility, offset by

•$23.0 million from borrowings on ABL Facility.

Cash flows used in financing activities during the six months ended June 30, 2021 primarily reflected:

•$95.0 million of cash outflow for repayments on the Revolving Credit Facility;

•$5.2 million of cash payments related to debt issuance costs; offset by

•$53.5 million from borrowings under the Permian Transmission Credit Facility.

Capital Requirements

Overall.

Our business is capital intensive, requiring significant investment for the maintenance of existing gathering systems and the acquisition or construction and development of new gathering systems and other midstream assets and facilities. Our Partnership Agreement requires that we categorize our capital expenditures as either:

•maintenance capital expenditures, which are cash expenditures (including expenditures for the addition or improvement to, or the replacement of, our capital assets or for the acquisition of existing, or the construction or development of, new capital assets) made to maintain our long-term operating income or operating capacity; or

•expansion capital expenditures, which are cash expenditures incurred for acquisitions or capital improvements that we expect will increase our operating income or operating capacity over the long term.

For the six months ended June 30, 2022, cash paid for capital expenditures totaled $14.8 million which included $4.8 million of maintenance capital expenditures. For the six months ended June 30, 2022, there were no contributions to Ohio Gathering and we contributed $8.4 million to Double E.

We rely primarily on internally generated cash flows as well as external financing sources, including commercial bank borrowings and the issuance of debt, equity and preferred equity securities, and proceeds from potential asset divestitures to fund our capital expenditures. We believe that our internally generated cash flows, our ABL Facility and the Permian Transmission Credit Facility, and access to debt or equity capital markets, will be adequate to finance our operations for the next twelve months without adversely impacting our liquidity.

There are a number of risks and uncertainties that could cause our current expectations to change, including, but not limited to, (i) the ability to reach agreements with third parties; (ii) prevailing conditions and outlook in the natural gas, crude oil and NGLs and markets, and (iii) our ability to obtain financing from commercial banks, the capital markets, or other financing sources.

Excess Cash Flow Offers to Purchase.

Starting in the first quarter of 2023 with respect to the fiscal year ended 2022, and continuing annually through fiscal year 2025, the Partnership is required under the terms of the 2026 Secured Notes Indenture to, if it has Excess Cash Flow (as defined in the 2026 Secured Notes Indenture), and subject to its ability to make such an offer under the ABL Credit Facility, offer to purchase an amount of the 2026 Secured Notes, at 100% of the principal amount plus accrued and unpaid interest, equal to 100% of the Excess Cash Flow generated in the prior year.

Generally, if the Partnership does not offer to purchase designated annual amounts of its 2026 Secured Notes or reduce its first lien capacity under the 2026 Secured Notes Indenture per annum from 2023 through 2025, the interest rate on the 2026 Secured Notes are subject to certain rate escalations. Per the terms of the 2026 Secured Notes Indenture, the designated amounts are; (i)

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$50.0 million in aggregate by April 1, 2023, otherwise the interest rate shall automatically increase by 50 basis points per annum; (ii) $100.0 million in aggregate by April 1, 2024, otherwise the interest rate shall automatically increase by 100 basis points per annum (minus any amount previously increased); and (iii) $200.0 million in aggregate by April 1, 2025, otherwise the interest rate shall automatically increase by 200 basis points per annum (minus any amount previously increased).

To the extent the Partnership makes an offer to purchase, and the offer is not fully accepted by the holders of the 2026 Secured Notes, the Partnership may use any remaining amount not accepted for any purpose not prohibited by the 2026 Secured Notes Indenture or the ABL Facility.

Credit and Counterparty Concentration Risks

We examine the creditworthiness of counterparties to whom we extend credit and manage our exposure to credit risk through credit analysis, credit approval, credit limits and monitoring procedures, and for certain transactions, we may request letters of credit, prepayments or guarantees.

Certain of our customers may be temporarily unable to meet their current obligations. While this may cause disruption to cash flows, we believe that we are properly positioned to deal with the potential disruption because the vast majority of our gathering assets are strategically positioned at the beginning of the midstream value chain. The majority of our infrastructure is connected directly to our customers’ wellheads and pad sites, which means our gathering systems are typically the first third-party infrastructure through which our customers’ commodities flow and, in many cases, the only way for our customers to get their production to market.

We have exposure due to nonperformance under our MVC contracts whereby a potential customer, may not have the wherewithal to make its MVC shortfall payments when they become due. We typically receive payment for all prior-year MVC shortfall billings in the quarter immediately following billing. Therefore, our exposure to risk of nonperformance is limited to and accumulates during the current year-to-date contracted measurement period.

Off-Balance Sheet Arrangements

During the three and six months ended June 30, 2022, there were no material changes to the off-balance sheet obligations disclosed in our 2021 Annual Report other than the following. On June 30, 2022, in connection with the disposition of the Lane G&P System, a subsidiary of Matador Resources assumed our commitment related to the take-or-pay firm capacity on the Double E Pipeline. The assumption of the take-or-pay contract relieved the Partnership of $29.2 million of remaining firm transportation obligations to Double E as of June 30, 2022.

Summarized Financial Information

The supplemental summarized financial information below reflects SMLP's separate accounts, the combined accounts of Summit Holdings and Finance Corp. (together, the “Co-Issuers”) and its guarantor subsidiaries (the “Guarantor Subsidiaries” and together with the Co-Issuers, the “Obligor Group”) for the dates and periods indicated. The financial information of the Obligor Group is presented on a combined basis and intercompany balances and transactions between the Co-Issuers and Guarantor Subsidiaries have been eliminated. There were no reportable transactions between the Co-Issuers and Obligor Group and the subsidiaries that were not issuers or guarantors of the Senior Notes.

Payments to holders of the Senior Notes are affected by the composition of and relationships among the Co-Issuers, the Guarantor Subsidiaries and Permian Holdco and Summit Permian Transmission, both of which are unrestricted subsidiaries of SMLP and are not issuers or guarantors of the Senior Notes. The assets of our unrestricted subsidiaries are not available to satisfy the demands of the holders of the Senior Notes. In addition, our unrestricted subsidiaries are subject to certain contractual restrictions related to the payment of dividends, and other rights in favor of their non-affiliated stakeholders, that limit their ability to satisfy the demands of the holders of the Senior Notes.

A list of each of SMLP’s subsidiaries that is a guarantor, issuer or co-issuer of our registered securities subject to the reporting requirements in Release 33-10762 is filed as Exhibit 22.1 to this report.

On June 30, 2022, the Partnership completed the disposition of all the equity interests in Summit Permian and Summit Permian Finance for a cash sale price of $75.0 million. In connection with the sale, the status of Summit Permian and Summit Permian Finance as guarantor subsidiaries was modified prior to the disposition. The summarized financial information below presents the activities and balances of Summit Permian and Summit Permian Finance as guarantor subsidiaries for all summarized income statement periods and balance sheet dates presented in which they were owned by the Partnership. Summit Permian and Summit Permian Finance were not included in the Partnership’s balance sheet as of June 30, 2022 and their assets and liabilities are not included in the June 30, 2022 summarized balance sheet below.

Summarized Balance Sheet Information. Summarized balance sheet information as of June 30, 2022 and December 31, 2021 follows.

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	June 30, 2022
	SMLP		Obligor Group
	(In thousands)
Assets
Current assets	$	3,577	$	66,579
Noncurrent assets	5,424		1,930,417

Liabilities
Current liabilities	$	11,388	$	57,259
Noncurrent liabilities	2,470		1,158,937


	December 31, 2021
	SMLP		Obligor Group
	(In thousands)
Assets
Current assets	$	2,495	$	70,483
Noncurrent assets	4,776		2,149,300

Liabilities
Current liabilities	$	12,463	$	58,658
Noncurrent liabilities	1,771		1,274,803

Summarized Statements of Operations Information. For the purposes of the following summarized statements of operations, we allocate a portion of general and administrative expenses recognized at the SMLP parent to the Obligor Group to reflect what those entities' results would have been had they operated on a stand-alone basis. Summarized statements of operations for the six months ended June 30, 2022 and for the year ended December 31, 2021 follow.


	Six Months Ended June 30, 2022
	SMLP		Obligor Group
	(In thousands)
Total revenues	$	—	$	195,189
Total costs and expenses	1,020		255,077
Loss before income taxes and income from equity method investees	(1,020)		(106,113)
Income from equity method investees	—		6,280
Net loss	$	(1,393)	$	(99,833)


	Year Ended December 31, 2021
	SMLP		Obligor Group
	(In thousands)
Total revenues	$	—	$	400,619
Total costs and expenses	23,989		317,975
Income (loss) before income taxes and loss from equity method investees	(37,618)		13,931
Income from equity method investees	—		9,116
Net income (loss)	$	(37,291)	$	23,047

Critical Accounting Estimates

We prepare our financial statements in accordance with GAAP. These principles are established by the FASB. We employ methods, estimates and assumptions based on currently available information when recording transactions resulting from business operations. There have been no significant changes to our critical accounting estimates from those disclosed on Form 10-K for the fiscal year ended December 31, 2021.

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Forward-Looking Statements

Investors are cautioned that certain statements contained in this report as well as in periodic press releases and certain oral statements made by our officers and employees during our presentations are “forward-looking” statements. Forward-looking statements include, without limitation, any statement that may project, indicate or imply future results, events, performance or achievements and may contain the words “expect,” “intend,” “plan,” “anticipate,” “estimate,” “believe,” “will be,” “will continue,” “will likely result,” and similar expressions, or future conditional verbs such as “may,” “will,” “should,” “would,” and “could.” In addition, any statement concerning future financial performance (including future revenues, earnings or growth rates), ongoing business strategies or prospects, and possible actions taken by us or our subsidiaries are also forward-looking statements. These forward-looking statements involve various risks and uncertainties, including, but not limited to, those described in Part II. Item 1A. Risk Factors included in this report.

Forward-looking statements are based on current expectations and projections about future events and are inherently subject to a variety of risks and uncertainties, many of which are beyond the control of our management team. All forward-looking statements in this report and subsequent written and oral forward-looking statements attributable to us, or to persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements in this paragraph. These risks and uncertainties include, among others:

•our decision whether to pay, or our ability to grow, our cash distributions;

•fluctuations in natural gas, NGLs and crude oil prices, including as a result of political or economic measures taken by various countries or OPEC or as a result of the Russia-Ukraine conflict;

•the extent and success of our customers' drilling and completion efforts, as well as the quantity of natural gas, crude oil and produced water volumes produced within proximity of our assets;

•the current and potential future impact of the COVID-19 pandemic on our business, results of operations, financial position or cash flows;

•failure or delays by our customers in achieving expected production in their natural gas, crude oil and produced water projects;

•competitive conditions in our industry and their impact on our ability to connect hydrocarbon supplies to our gathering and processing assets or systems;

•actions or inactions taken or nonperformance by third parties, including suppliers, contractors, operators, processors, transporters and customers, including the inability or failure of our shipper customers to meet their financial obligations under our gathering agreements and our ability to enforce the terms and conditions of certain of our gathering agreements in the event of a bankruptcy of one or more of our customers;

•our ability to divest of certain of our assets to third parties on attractive terms, which is subject to a number of factors, including prevailing conditions and outlook in the natural gas, NGL and crude oil industries and markets;

•the ability to attract and retain key management personnel;

•commercial bank and capital market conditions and the potential impact of changes or disruptions in the credit and/or capital markets;

•changes in the availability and cost of capital and the results of our financing efforts, including availability of funds in the credit and/or capital markets;

•our ability to refinance near-term maturities on favorable terms or at all and the related impact on our ability to continue as a going concern;

•restrictions placed on us by the agreements governing our debt and preferred equity instruments;

•the availability, terms and cost of downstream transportation and processing services;

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

•operational risks and hazards inherent in the gathering, compression, treating and/or processing of natural gas, crude oil and produced water;

•our ability to comply with the terms of the agreements comprising the Global Settlement;

•weather conditions and terrain in certain areas in which we operate;

•any other issues that can result in deficiencies in the design, installation or operation of our gathering, compression, treating and processing facilities;

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•timely receipt of necessary government approvals and permits, our ability to control the costs of construction, including costs of materials, labor and rights-of-way and other factors that may impact our ability to complete projects within budget and on schedule;

•our ability to finance our obligations related to capital expenditures, including through opportunistic asset divestitures or joint ventures and the impact any such divestitures or joint ventures could have on our results;

•the effects of existing and future laws and governmental regulations, including environmental, safety and climate change requirements and federal, state and local restrictions or requirements applicable to oil and/or gas drilling, production or transportation;

•changes in tax status;

•the effects of litigation;

•changes in general economic conditions; and

•certain factors discussed elsewhere in this report.

Developments in any of these areas could cause actual results to differ materially from those anticipated or projected or cause a significant reduction in the market price of our common units, preferred units and senior notes.

The foregoing list of risks and uncertainties may not contain all of the risks and uncertainties that could affect us. In addition, in light of these risks and uncertainties, the matters referred to in the forward-looking statements contained in this document may not in fact occur. Accordingly, undue reliance should not be placed on these statements. We undertake no obligation to publicly update or revise any forward-looking statements as a result of new information, future events or otherwise, except as otherwise required by law.

Information About Us

Investors should note that we make available, free of charge on our website at www.summitmidstream.com, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. We also post announcements, updates, events, investor information and presentations on our website in addition to copies of all recent news releases. We may use the Investors section of our website to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. Documents and information on our website are not incorporated by reference herein.

The SEC maintains a website at www.sec.gov that contains reports, proxy and information statements, and other information regarding issuers, including us, that file electronically with the SEC.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Interest Rate Risk

Our interest rate risk exposure, which is largely related to our indebtedness, has not changed materially since December 31, 2021. As of June 30, 2022, we had approximately $959.5 million principal of fixed-rate debt, $151.0 million outstanding under our variable rate ABL Facility and $157.8 million outstanding under the variable rate Permian Transmission Term Loan (see Note 8 - Debt). As of June 30, 2022, we had $142.0 million of interest rate exposure hedged to offset the impact of changes in interest rates on our Permian Transmission Term Loan. While existing fixed-rate debt mitigates the downside impact of fluctuations in interest rates, future issuances of long-term debt could be impacted by increases in interest rates, which could result in higher overall interest costs. In addition, the borrowings under our ABL Facility, which have a variable interest rate, also expose us to the risk of increasing interest rates. For additional information, see the "Interest Rate Risk" section included in Item 7A. Quantitative and Qualitative Disclosures About Market Risk of the 2021 Annual Report and updates to our risk factors included herein.

Commodity Price Risk

We generate a majority of our revenues pursuant to primarily long-term and fee-based gathering agreements, many of which include MVCs and areas of mutual interest. Our direct commodity price exposure relates to (i) the sale of physical natural gas and/or NGLs purchased under percentage-of-proceeds and other processing arrangements with certain of our customers in the Rockies, and Piceance segments, (ii) the sale of natural gas we retain from certain Barnett segment customers and (iii) the sale of condensate we retain from certain gathering services in the Piceance segment. Our gathering agreements with certain Barnett customers permit us to retain a certain quantity of natural gas that we sell to offset the power costs we incur to operate our electric-drive compression assets. We manage our direct exposure to natural gas and power prices through the use of forward power purchase contracts with wholesale power providers that require us to purchase a fixed quantity of power at a fixed heat rate based on prevailing natural gas prices on the Henry Hub Index. We sell retainage natural gas at prices that are based on the Atmos Zone 3 Index. By basing the power prices on a system and basin-relevant market, we are able to closely associate the relationship between the compression electricity expense and natural gas retainage sales. We do not enter into risk management contracts for speculative purposes. Our current commodity price risk exposure has not changed materially since December 31, 2021. For additional information, see the "Commodity Price Risk" section included in Item 7A. Quantitative and Qualitative Disclosures About Market Risk of the 2021 Annual Report.

Item 4. Controls and Procedures.

Under the direction of our General Partner's Chief Executive Officer and Chief Financial Officer, we evaluated our disclosure controls and procedures and internal control over financial reporting and concluded that (i) our disclosure controls and procedures were effective as of June 30, 2022 and (ii) no change in internal control over financial reporting occurred during the quarter ended June 30, 2022, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II - OTHER INFORMATION

Item 1. Legal Proceedings.

Although we may, from time to time, be involved in litigation and claims arising out of our operations in the ordinary course of business, we are not currently a party to any significant legal or governmental proceedings, except as described below. In addition, we are not aware of any significant legal or governmental proceedings contemplated to be brought against us, under the various environmental protection statutes to which we are subject.

Moore Control Systems

Moore Control Systems, Inc. (“MCSI”) initiated an arbitration in December 2020 related to the construction of Summit’s Lane Gas Processing Plant in Eddy County, New Mexico (the “Lane Plant”). MCSI was the EPC contractor on the Lane Plant under a lump sum contract. During the course of construction, the parties executed change orders that increased the lump sum price. Summit paid the adjusted lump sum amount in full upon the plant’s completion in June 2019.

A merits hearing is currently scheduled for March 6, 2023 in Houston, Texas. MCSI seeks alleged damages totaling approximately $12 million on various theories, including breach of contract, quantum meruit and fraud, plus interest, fees and costs. Summit denies all liability and seeks to recover all costs and fees associated with defending the arbitration. We do not currently believe that the eventual outcome of this matter could have a material adverse effect on our business, financial condition, results of operations or cash flows. In conjunction with the disposition of Lane Gathering and Processing system on June 30, 2022, Summit Holdings provided the buyer with an indemnity for and hold harmless from these claims.

Fiberspar Corporation

On May 3, 2022, Fiberspar Corporation filed a petition in state court alleging $5 million or more owed but not paid by Summit Midstream Partners, LLC for orders of pipeline product from Fiberspar. The petition asserts causes of action for breach of contract and suit on sworn account. A civil action on the same claims had been filed by Fiberspar on January 29, 2016, which was non-suited on September 26, 2016 pursuant to an agreement that included a standstill period through September 30, 2021. We have not been served with the petition, which is pending in the District Court of Harris County, Texas.

Item 1A. Risk Factors.

The risk factors contained in the Item 1A. Risk Factors of the 2021 Annual Report are incorporated herein by reference except to the extent they address risks arising from or relating to the failure of events described therein to occur, which events have since occurred.

Item 5. Other Information.

None.

Item 6. Exhibits.

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Exhibit number		Description
3.1		Fourth Amended and Restated Agreement of Limited Partnership of Summit Midstream Partners, LP, dated May 28, 2020 (Incorporated herein by reference to Exhibit 3.1 to SMLP’s Current Report on Form 8-K dated June 2, 2020 (Commission File No. 001-35666))
3.2		Second Amended and Restated Limited Liability Company Agreement of Summit Midstream GP, LLC, dated May 28, 2020 (Incorporated herein by reference to Exhibit 3.2 to SMLP's Current Report on Form 8-K filed June 2, 2020 (Commission File No. 001-35666))
3.3		Certificate of Limited Partnership of Summit Midstream Partners, LP (Incorporated herein by reference to Exhibit 3.1 to SMLP's Form S-1 Registration Statement dated August 21, 2012 (Commission File No. 333-183466))
3.4		Certificate of Formation of Summit Midstream GP, LLC (Incorporated herein by reference to Exhibit 3.4 to SMLP's Form S-1 Registration Statement dated August 21, 2012 (Commission File No. 333-183466))
10.1	+	Purchase and Sale Agreement, dated as of June 9, 2022, among Summit Midstream Holdings, LLC as Seller, Longwood Gathering and Disposal Systems, LP as Buyer, and Summit Midstream Partners LP
10.2		Form of Summit Midstream Partners, LP 2012 Long-Term Incentive Plan Grant Award Agreement (Incorporated herein by reference to Exhibit 10.54 to SMLP’s Annual Report on Form 10-K filed February 28, 2022 (Commission File No. 001-35666))
10.3		Summit Midstream Partners, LP 2022 Long-Term Incentive Plan (incorporated herein by reference to Appendix B to SMLP’s definitive proxy statement on Schedule 14A filed March 31, 2022 (Commission File No. 001-35666))
22.1		Summit Midstream Partners, LP Subsidiary Issuers and Guarantors of Registered Securities (Incorporated herein by reference to Exhibit 22.1 to SMLP's Report on Form 10-Q filed May 8, 2020 (Commission File No. 001-35666))
31.1	+	Rule 13a-14(a)/15d-14(a) Certification, executed by Heath Deneke, President, Chief Executive Officer and Director
31.2	+	Rule 13a-14(a)/15d-14(a) Certification, executed by William J. Mault, Executive Vice President and Chief Financial Officer
32.1	+	Certifications required by Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350), executed by Heath Deneke, President, Chief Executive Officer and Director, and William J. Mault, Executive Vice President and Chief Financial Officer
101.INS	*	Inline XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
101.SCH	*	Inline XBRL Taxonomy Extension Schema
101.CAL	*	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	*	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	*	Inline XBRL Taxonomy Extension Label Linkbase
101.PRE	*	Inline XBRL Taxonomy Extension Presentation Linkbase
104	*	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

+ Filed herewith.

* Pursuant to Rule 406T of Regulation S-T, the Interactive Data Files on Exhibit 101 hereto are deemed not filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are deemed not filed for purposes of Section 18 of the Securities and Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections. The financial information contained in the XBRL (eXtensible Business Reporting Language)-related documents is unaudited and unreviewed.

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SIGNATURES

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


			Summit Midstream Partners, LP
			(Registrant)

			By: Summit Midstream GP, LLC (its General Partner)

August 5, 2022			/s/ WILLIAM J. MAULT
			William J. Mault, Executive Vice President and Chief Financial Officer (Principal Financial Officer)