UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


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

For the quarterly period ended ~~September~~June 30, ~~2021~~2022


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

For the transition period from to


WESTERN MIDSTREAM PARTNERS, LP
WESTERN MIDSTREAM OPERATING, LP
(Exact name of registrant as specified in its charter)


	Commission file number:	State or other jurisdiction of incorporation or organization:	I.R.S. Employer Identification No.:
Western Midstream Partners, LP	001-35753	Delaware	46-0967367
Western Midstream Operating, LP	001-34046	Delaware	26-1075808

Address of principal executive offices:

Zip Code:

Registrant’s telephone number, including area code:

Western Midstream Partners, LP

9950 Woodloch Forest Drive, Suite 2800

The Woodlands,

Texas

77380

(346)

786-5000

Western Midstream Operating, LP

9950 Woodloch Forest Drive, Suite 2800

The Woodlands,

Texas

77380

(346)

786-5000

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

Title of each class

Trading symbol

Name of exchange
on which registered

Common units outstanding as of ~~November 4, 2021:~~July 29, 2022:

Western Midstream Partners, LP

Common units

WES

New York Stock Exchange

~~408,390,278~~386,450,080

Western Midstream Operating, LP

None

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.

Western Midstream Partners, LP

Yes

Western Midstream Operating, LP

Yes

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).

Western Midstream Partners, LP

Yes

Western Midstream Operating, LP

Yes

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a 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.

Western Midstream Partners, LP

Large Accelerated Filer

Accelerated Filer

Non-accelerated Filer

Smaller Reporting Company

Emerging Growth Company

☐

Western Midstream Operating, LP

Large Accelerated Filer

Accelerated Filer

Non-accelerated Filer

Smaller Reporting Company

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.


Western Midstream Partners, LP			¨
Western Midstream Operating, LP			¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Western Midstream Partners, LP

Yes

☐

Western Midstream Operating, LP

Yes

☐

FILING FORMAT

This quarterly report on Form 10-Q is a combined report being filed by two separate registrants: Western Midstream Partners, LP and Western Midstream Operating, LP. Western Midstream Operating, LP is a consolidated subsidiary of Western Midstream Partners, LP that has publicly traded debt, but does not have any publicly traded equity securities. Information contained herein related to any individual registrant is filed by such registrant solely on its own behalf. Each registrant makes no representation as to information relating exclusively to the other registrant.

Part I, Item 1 of this quarterly report includes separate financial statements (i.e., consolidated statements of operations, consolidated balance sheets, consolidated statements of equity and partners’ capital, and consolidated statements of cash flows) for Western Midstream Partners, LP and Western Midstream Operating, LP. The accompanying Notes to Consolidated Financial Statements, which are included under Part I, Item 1 of this quarterly report, and Management’s Discussion and Analysis of Financial Condition and Results of Operations, which is included under Part I, Item 2 of this quarterly report, are presented on a combined basis for each registrant, with any material differences between the registrants disclosed separately.


TABLE OF CONTENTS
		PAGE
PART I		FINANCIAL INFORMATION (UNAUDITED)
	Item 1.	Financial Statements
		Western Midstream Partners, LP
		Consolidated Statements of Operations for the three ~~and~~ ~~nine~~and six months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	7
		Consolidated Balance Sheets as of ~~September~~ June 30 ~~2021,~~, 2022, and December 31, ~~2020~~2021	8
		Consolidated Statements of Equity and Partners’ Capital for the three and ~~nine~~six months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	9
		Consolidated Statements of Cash Flows for the ~~nin~~esix months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	1110
		Western Midstream Operating, LP
		Consolidated Statements of Operations for the three and ~~nine~~six months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	1211
		Consolidated Balance Sheets as of ~~September~~June 30 ~~30, 2021,~~, 2022, and December 31, ~~2020~~2021	1312
		Consolidated Statements of Equity and Partners’ Capital for the three and six ~~nine~~months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	1413
		Consolidated Statements of Cash Flows for the ~~nine~~ six months ended ~~September~~June 30 ~~30,~~, 2022 and 2021 ~~and 2020~~	1614
		Notes to Consolidated Financial Statements	1715
		Note 1. Description of Business and Basis of Presentation	1715
		Note 2. Revenue from Contracts with Customers	2018
		Note 3. Acquisitions and Divestitures	19
		Note 4 . Partnership Distributions	20
		Note 5 . Equity and Partners’ Capital	21
		Note 6 . Related-Party Transactions	22
		Note ~~4. Partnership Distributions~~7 . Equity Investments	2327
		Note ~~5. Equity and Partners’ Capital~~	248
		~~Note 6. Related-Party Transactions~~	26
		~~Note 7. Equity Investments~~	31
		~~Note 8.~~. Property, Plant, and Equipment	3228

		Note ~~9. Goodwill~~	339
		~~Note 10.~~. Selected Components of Working Capital	3429
		Note ~~11.~~10 . Debt and Interest Expense	3530
		Note ~~12.~~1 1 . Commitments and Contingencies	3732

	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3833
		Cautionary Note Regarding Forward-Looking Statements	3833
		Executive Summary	4035
		Outlook	4337
		Acquisitions and Divestitures	4337

		Results of Operations	4438
		Operating Results	4438
		Key Performance Metrics	5346
		Liquidity and Capital Resources	5952
		Items Affecting the Comparability of Financial Results with WES Operating	6456
		Critical Accounting Estimates	6557

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	6558
	Item 4.	Controls and Procedures	6658
PART II		OTHER INFORMATION
	Item 1.	Legal Proceedings	6759
	Item 1A.	Risk Factors	6760
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6960

	Item 6.	Exhibits	7061

Table of Contents

COMMONLY USED TERMS AND DEFINITIONS

Unless the context otherwise requires, references to “we,” “us,” “our,” “WES,” “the Partnership,” or “Western Midstream Partners, LP” refer to Western Midstream Partners, LP (formerly Western Gas Equity Partners, LP) and its subsidiaries. As used in this Form 10-Q, the terms and definitions below have the following meanings:

~~AESC:~~ ~~Anadarko Energy Services Company, a subsidiary of Occidental.~~

Anadarko: Anadarko Petroleum Corporation and its subsidiaries, excluding our general partner, which became a wholly owned subsidiary of Occidental upon closing of the Occidental Merger on August 8, 2019.

~~Anadarko note receivable:~~ ~~The 30~~-year $260.0 million note established in May 2008 between WES Operating as the lender and Anadarko as the borrower. The note bore interest at a fixed annual rate of 6.50%, payable quarterly. Following the Occidental Merger, Occidental became the ultimate counterparty. On September 11, 2020, the Partnership and Occidental entered into a Unit Redemption Agreement, pursuant to which (i) WES Operating transferred and assigned its interest in the Anadarko note receivable to its limited partners on a pro-rata basis, transferring 98% of its interest in (and accrued interest owed under) the Anadarko note receivable to the Partnership and the remaining 2% to WGRAH, a subsidiary of Occidental, (ii) the Partnership subsequently assigned the 98% interest in (and accrued interest owed under) the Anadarko note receivable to Anadarko, which Anadarko canceled and retired immediately upon receipt, in exchange for which Occidental caused certain of its subsidiaries to transfer an aggregate of 27,855,398 common units of the Partnership to the Partnership, and (iii) the Partnership canceled such common units immediately upon receipt.

Barrel or Bbl: 42 U.S. gallons measured at 60 degrees Fahrenheit.

Bbls/d: Barrels per day.

~~Board of Directors:~~Board: The board of directors of WES’s general partner.

Cactus II: Cactus II Pipeline LLC.

Chipeta: Chipeta Processing, LLC.

Condensate: A natural-gas liquid with a low vapor pressure compared to drip condensate, mainly composed of propane, butane, pentane, and heavier hydrocarbon fractions.

Cryogenic: The process by which liquefied gases are used to bring natural-gas volumes to very low temperatures (below approximately -238 degrees Fahrenheit) to separate natural-gas liquids from natural gas. Through cryogenic processing, more natural-gas liquids are extracted as compared to traditional refrigeration methods.

DBM: Delaware Basin Midstream, LLC.

DBM water systems: ~~The~~DBM’s produced-water gathering and disposal systems in West Texas.

DJ Basin complex: The Platte Valley system, Wattenberg system, Lancaster plant, Latham plant, and Wattenberg processing plant.

EBITDA: Earnings before interest, taxes, depreciation, and amortization. For a definition of “Adjusted EBITDA,” see Key Performance Metrics under Part I, Item 2 of this Form 10-Q.

Exchange Act: The Securities Exchange Act of 1934, as amended.

Fixed-Rate Senior Notes: WES Operating’s fixed-rate 3.100% Senior Notes due 2025, 4.050% Senior Notes due 2030, and 5.250% Senior Notes due 2050, issued in January 2020.

~~Table of Contents~~

Floating-Rate Senior Notes: WES Operating’s floating-rate Senior Notes due 2023.

Fort Union: Fort Union Gas Gathering, LLC.

Fractionation: The process of applying various levels of high pressure and low temperature to separate a stream of natural-gas liquids into ethane, propane, normal butane, isobutane, and natural gasoline for end-use sale.

FRP: Front Range Pipeline LLC.

GAAP: Generally accepted accounting principles in the United States.

General partner: Western Midstream Holdings, LLC, the general partner of the Partnership.

Hydraulic fracturing: The high-pressure injection of fluids into the wellbore to create fractures in rock formations, stimulating the production of oil or gas.

Imbalance: Imbalances result from (i) differences between gas and NGLs volumes nominated by customers and gas and NGLs volumes received from those customers and (ii) differences between gas and NGLs volumes received from customers and gas and NGLs volumes delivered to those customers.

Table of Contents

LIBOR: London Interbank Offered Rate.

Marcellus Interest: The 33.75% interest in the Larry’s Creek, Seely, and Warrensville gas-gathering systems and related facilities located in northern Pennsylvania.

MBbls/d: Thousand barrels per day.

Mcf: Thousand cubic feet.

MGR: Mountain Gas Resources, LLC.

MGR assets: The Red Desert complex and the Granger straddle plant.

Mi Vida: Mi Vida JV LLC.

MLP: Master limited partnership.

MMcf: Million cubic feet.

MMcf/d: Million cubic feet per day.

Mont Belvieu JV: Enterprise EF78 LLC.

Natural-gas liquid(s) or NGL(s): The combination of ethane, propane, normal butane, isobutane, and natural gasolines that, when removed from natural gas, become liquid under various levels of pressure and temperature.

NYMEX: New York Mercantile Exchange.

Occidental: Occidental Petroleum Corporation and, as the context requires, its subsidiaries, excluding our general partner.

Occidental Merger: Occidental’s acquisition by merger of Anadarko pursuant to the Agreement and Plan of Merger, dated as of May 9, 2019, by and among Occidental, Baseball Merger Sub 1, Inc., and Anadarko, which closed on August 8, 2019.

Panola: Panola Pipeline Company, LLC.

Produced water: Byproduct associated with the production of crude oil and natural gas that often contains a number of dissolved solids and other materials found in oil and gas reservoirs.

~~Purchase Program:~~ The buyback program announced in November 2020, pursuant to which we may purchase up to $250.0 million in aggregate value of our common units through December 31, 2021. The common units may be purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions.

~~Table of Contents~~

Ranch Westex: Ranch Westex JV LLC.

RCF: WES Operating’s $2.0 billion senior unsecured revolving credit ~~facility that matures in February 2025.~~facility.

Red Bluff Express: Red Bluff Express Pipeline, LLC.

Red Desert complex: The Patrick Draw ~~processing plant, the~~and Red Desert processing ~~plant,~~plants, which are currently inactive, associated gathering lines, and related facilities.

Related parties: Occidental, ~~and~~ the Partnership’s equity interests (see Note 7—Equity Investmentsin ~~Fort Union (until divested in October 2020)~~the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q), ~~White Cliffs, Rendezvous,~~and the ~~Mont Belvieu JV, TEP, TEG, FRP, Whitethorn LLC, Cactus II, Saddlehorn, Panola, Mi Vida, Ranch Westex,~~Partnership and ~~Red Bluff Express.~~WES Operating for transactions that eliminate upon consolidation.

Rendezvous: Rendezvous Gas Services, LLC.

Residue: The natural gas remaining after the unprocessed natural-gas stream has been processed or treated.

Saddlehorn: Saddlehorn Pipeline Company, LLC.

SEC: U.S. Securities and Exchange Commission.

Table of Contents

Services Agreement: That certain amended and restated Services, Secondment, and Employee Transfer Agreement, dated as of December 31, 2019, by and among Occidental, Anadarko, and WES Operating GP.

Springfield system: The Springfield gas-gathering system and Springfield oil-gathering system.

SOFR: Secured Overnight Financing Rate.

TEFR Interests: The interests in TEP, TEG, and FRP.

TEG: Texas Express Gathering LLC.

TEP: Texas Express Pipeline LLC.

~~Term loan facility:~~ ~~WES Operating’s senior unsecured credit facility entered into in December 2018, which was repaid and terminated in January 2020.~~

WES Operating: Western Midstream Operating, LP, formerly known as Western Gas Partners, LP, and its subsidiaries.

WES Operating GP: Western Midstream Operating GP, LLC, the general partner of WES Operating.

West Texas complex: The DBM complex and DBJV and Haley systems.

WGRAH: WGR Asset Holding Company LLC.

~~WGRI:~~ ~~Western Gas Resources, Inc., a subsidiary of Occidental.~~

White Cliffs: White Cliffs Pipeline, LLC.

Whitethorn LLC: Whitethorn Pipeline Company LLC.

Whitethorn: A crude-oil and condensate pipeline, and related storage facilities, owned by Whitethorn LLC.

$1.0 billion Purchase Program: In February 2022, we announced a buyback program of up to $1.0 billion of our common units through December 31, 2024. The common units may be purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions.

$250.0 million Purchase Program: In November 2020, we announced a buyback program of up to $250.0 million of our common units through December 31, 2021. The common units were purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions. As of December 31, 2021, the entire $250.0 million authorized program had been fulfilled.

Table of Contents

PART I. FINANCIAL INFORMATION (UNAUDITED)

Item 1. Financial Statements

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands except per-unit amounts	thousands except per-unit amounts	2021		2020		2021		2020		thousands except per-unit amounts	2022		2021		2022		2021
Revenues and other	Revenues and other									Revenues and other
Service revenues – fee based	Service revenues – fee based	$	650,482	$	636,522	$	1,841,742	$	1,980,546	Service revenues – fee based	$	655,952	$	618,985	$	1,287,550	$	1,191,260
Service revenues – product based	Service revenues – product based	28,812		12,316		88,267		35,237		Service revenues – product based	70,498		27,803		111,365		59,455
Product sales	Product sales	84,298		30,106		227,359		108,491		Product sales	149,736		72,256		235,325		143,061
Other	Other	248		100		577		838		Other	233		87		476		329
Total revenues and other (1)	Total revenues and other (1)	763,840		679,044		2,157,945		2,125,112		Total revenues and other (1)	876,419		719,131		1,634,716		1,394,105
Equity income, net – related parties	Equity income, net – related parties	48,506		61,026		159,337		176,788		Equity income, net – related parties	48,464		58,666		98,071		110,831
Operating expenses	Operating expenses									Operating expenses
Cost of product	Cost of product	83,232		31,739		250,245		153,611		Cost of product	148,556		78,044		221,404		167,013
Operation and maintenance	Operation and maintenance	140,838		132,293		434,198		436,670		Operation and maintenance	168,153		153,028		297,129		293,360
General and administrative	General and administrative	50,409		41,578		139,973		118,466		General and administrative	47,848		44,448		96,450		89,564
Property and other taxes	Property and other taxes	13,641		19,392		45,992		57,263		Property and other taxes	22,662		17,967		41,104		32,351
Depreciation and amortization	Depreciation and amortization	139,002		132,564		407,404		384,688		Depreciation and amortization	139,036		137,849		273,618		268,402
Long-lived asset and other impairments	Long-lived asset and other impairments	1,594		34,640		29,198		200,575		Long-lived asset and other impairments	90		12,738		90		27,604
Goodwill impairment		—		—		—		441,017

Total operating expenses (2)	Total operating expenses (2)	428,716		392,206		1,307,010		1,792,290		Total operating expenses (2)	526,345		444,074		929,795		878,294
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(364)		(768)		278		(3,651)		Gain (loss) on divestiture and other, net	(1,150)		1,225		(780)		642
Operating income (loss)	Operating income (loss)	383,266		347,096		1,010,550		505,959		Operating income (loss)	397,388		334,948		802,212		627,284
Interest income – Anadarko note receivable		—		3,286		—		11,736

Interest expense	Interest expense	(93,257)		(95,571)		(287,040)		(278,811)		Interest expense	(80,772)		(95,290)		(166,227)		(193,783)
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	(24,655)		1,632		(24,944)		10,372		Gain (loss) on early extinguishment of debt	91		—		91		(289)
Other income (expense), net	Other income (expense), net	110		720		(1,013)		612		Other income (expense), net	(45)		84		61		(1,123)
Income (loss) before income taxes	Income (loss) before income taxes	265,464		257,163		697,553		249,868		Income (loss) before income taxes	316,662		239,742		636,137		432,089
Income tax expense (benefit)	Income tax expense (benefit)	1,826		3,028		4,403		3,792		Income tax expense (benefit)	1,491		1,465		3,296		2,577
Net income (loss)	Net income (loss)	263,638		254,135		693,150		246,076		Net income (loss)	315,171		238,277		632,841		429,512
Net income (loss) attributable to noncontrolling interests	Net income (loss) attributable to noncontrolling interests	7,913		7,524		20,375		(17,045)		Net income (loss) attributable to noncontrolling interests	8,854		7,018		17,807		12,462
Net income (loss) attributable to Western Midstream Partners, LP	Net income (loss) attributable to Western Midstream Partners, LP	$	255,725	$	246,611	$	672,775	$	263,121	Net income (loss) attributable to Western Midstream Partners, LP	$	306,317	$	231,259	$	615,034	$	417,050
Limited partners’ interest in net income (loss):	Limited partners’ interest in net income (loss):									Limited partners’ interest in net income (loss):
Net income (loss) attributable to Western Midstream Partners, LP	Net income (loss) attributable to Western Midstream Partners, LP	$	255,725	$	246,611	$	672,775	$	263,121	Net income (loss) attributable to Western Midstream Partners, LP	$	306,317	$	231,259	$	615,034	$	417,050

General partner interest in net (income) loss	General partner interest in net (income) loss	(5,527)		(5,132)		(14,484)		(5,462)		General partner interest in net (income) loss	(6,767)		(4,964)		(13,550)		(8,957)
Limited partners’ interest in net income (loss) (3)	Limited partners’ interest in net income (loss) (3)	250,198		241,479		658,291		257,659		Limited partners’ interest in net income (loss) (3)	299,550		226,295		601,484		408,093
Net income (loss) per common unit – basic (3)	Net income (loss) per common unit – basic (3)	$	0.61	$	0.55	$	1.60	$	0.58	Net income (loss) per common unit – basic (3)	$	0.74	$	0.55	$	1.49	$	0.99
Net income (loss) per common unit – diluted (3)	Net income (loss) per common unit – diluted (3)	$	0.61	$	0.55	$	1.59	$	0.58	Net income (loss) per common unit – diluted (3)	$	0.74	$	0.55	$	1.49	$	0.99
Weighted-average common units outstanding – basic (3)	Weighted-average common units outstanding – basic (3)	411,909		438,857		412,690		442,255		Weighted-average common units outstanding – basic (3)	403,027		413,070		403,140		413,087
Weighted-average common units outstanding – diluted (3)	Weighted-average common units outstanding – diluted (3)	412,714		438,926		413,150		442,275		Weighted-average common units outstanding – diluted (3)	404,162		413,720		404,280		413,557

(1)Total revenues and other includes ~~related~~-~~party~~related-party amounts of ~~$431.7~~$456.8 million and ~~$1.2 billion~~$885.5 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~$455.6~~$415.4 million and ~~$1.4 billion~~$793.7 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively. See Note 6.

(2)Total operating expenses includes ~~related~~-~~party~~related-party amounts of ~~$22.7~~$(11.2) million and ~~$91.5~~$(28.8) million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~$10.4~~$29.0 million and ~~$161.5~~$68.8 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively. See Note 6.

(3)See Note 5.

See accompanying Notes to Consolidated Financial Statements.

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WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


thousands except number of units	thousands except number of units	September 30, 2021		December 31, 2020		thousands except number of units	June 30, 2022		December 31, 2021
ASSETS	ASSETS					ASSETS
Current assets	Current assets					Current assets
Cash and cash equivalents	Cash and cash equivalents	$	99,862	$	444,922	Cash and cash equivalents	$	97,434	$	201,999
Accounts receivable, net	Accounts receivable, net	583,652		452,880		Accounts receivable, net	716,343		436,513
Other current assets	Other current assets	73,196		45,262		Other current assets	49,666		46,252
Total current assets	Total current assets	756,710		943,064		Total current assets	863,443		684,764
Property, plant, and equipment	Property, plant, and equipment					Property, plant, and equipment
Cost	Cost	12,732,926		12,641,745		Cost	13,058,689		12,846,078
Less accumulated depreciation	Less accumulated depreciation	4,208,845		3,931,800		Less accumulated depreciation	4,581,122		4,333,171
Net property, plant, and equipment	Net property, plant, and equipment	8,524,081		8,709,945		Net property, plant, and equipment	8,477,567		8,512,907
Goodwill	Goodwill	4,783		4,783		Goodwill	4,783		4,783
Other intangible assets	Other intangible assets	752,659		776,409		Other intangible assets	728,908		744,742
Equity investments	Equity investments	1,181,181		1,224,813		Equity investments	1,148,487		1,167,187
Other assets (1)	Other assets (1)	199,964		171,013		Other assets (1)	165,671		158,696
Total assets (2)	Total assets (2)	$	11,419,378	$	11,830,027	Total assets (2)	$	11,388,859	$	11,273,079
LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL	LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL					LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL
Current liabilities	Current liabilities					Current liabilities
Accounts and imbalance payables	Accounts and imbalance payables	$	341,220	$	210,691	Accounts and imbalance payables	$	492,979	$	326,061
Short-term debt	Short-term debt	726,429		438,870		Short-term debt	2,613		505,932
Accrued ad valorem taxes	Accrued ad valorem taxes	49,065		41,427		Accrued ad valorem taxes	41,268		44,955
Accrued liabilities	Accrued liabilities	190,628		269,947		Accrued liabilities	217,817		263,249

Total current liabilities	Total current liabilities	1,307,342		960,935		Total current liabilities	754,677		1,140,197
Long-term liabilities	Long-term liabilities					Long-term liabilities
Long-term debt	Long-term debt	6,399,874		7,415,832		Long-term debt	6,656,123		6,400,616

Deferred income taxes	Deferred income taxes	24,470		22,195		Deferred income taxes	14,345		12,425
Asset retirement obligations	Asset retirement obligations	271,022		260,283		Asset retirement obligations	303,548		298,275
Other liabilities	Other liabilities	320,224		275,570		Other liabilities	355,163		325,806
Total long-term liabilities	Total long-term liabilities	7,015,590		7,973,880		Total long-term liabilities	7,329,179		7,037,122
Total liabilities (3)	Total liabilities (3)	8,322,932		8,934,815		Total liabilities (3)	8,083,856		8,177,319
Equity and partners’ capital	Equity and partners’ capital					Equity and partners’ capital
Common units (408,610,916 and 413,839,863 units issued and outstanding at September 30, 2021, and December 31, 2020, respectively)		2,965,944		2,778,339
General partner units (9,060,641 units issued and outstanding at September 30, 2021, and December 31, 2020)		(11,286)		(17,208)
Common units (400,248,341 and 402,993,919 units issued and outstanding at June 30, 2022, and December 31, 2021, respectively)						Common units (400,248,341 and 402,993,919 units issued and outstanding at June 30, 2022, and December 31, 2021, respectively)	3,164,328		2,966,955
General partner units (9,060,641 units issued and outstanding at June 30, 2022, and December 31, 2021)						General partner units (9,060,641 units issued and outstanding at June 30, 2022, and December 31, 2021)	(2,825)		(8,882)

Total partners’ capital	Total partners’ capital	2,954,658		2,761,131		Total partners’ capital	3,161,503		2,958,073
Noncontrolling interests	Noncontrolling interests	141,788		134,081		Noncontrolling interests	143,500		137,687
Total equity and partners’ capital	Total equity and partners’ capital	3,096,446		2,895,212		Total equity and partners’ capital	3,305,003		3,095,760
Total liabilities, equity, and partners’ capital	Total liabilities, equity, and partners’ capital	$	11,419,378	$	11,830,027	Total liabilities, equity, and partners’ capital	$	11,388,859	$	11,273,079

(1)Other assets includes ~~$11.2~~$12.2 million and ~~$4.2~~$9.8 million of NGLs line-fill inventory as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively. Other assets also includes ~~$63.1~~$55.3 million and ~~$71.9~~$56.2 million of materials and supplies inventory as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively.

(2)Total assets includes related-party amounts of ~~$1.6~~$1.5 billion and $1.4 billion as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively, which includes related-party Accounts receivable, net of ~~$289.4~~$322.7 million and ~~$291.3~~$180.2 million as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively. See Note 6.

(3)Total liabilities includes related-party amounts of ~~$250.7~~$288.3 million and ~~$164.7~~$270.5 million as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively. See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF EQUITY AND PARTNERS’ CAPITAL

(UNAUDITED)


		Partners’ Capital									Partners’ Capital
thousands	thousands	Common Units		General Partner Units		Noncontrolling Interests		Total		thousands	Common Units		General Partner Units		Noncontrolling Interests		Total
Balance at December 31, 2020		$	2,778,339	$	(17,208)	$	134,081	$	2,895,212

Balance at December 31, 2021										Balance at December 31, 2021	$	2,966,955	$	(8,882)	$	137,687	$	3,095,760
Net income (loss)	Net income (loss)	181,798		3,993		5,444		191,235		Net income (loss)	301,934		6,783		8,953		317,670
Distributions to Chipeta noncontrolling interest owner	Distributions to Chipeta noncontrolling interest owner	—		—		(276)		(276)		Distributions to Chipeta noncontrolling interest owner	—		—		(1,984)		(1,984)
Distributions to noncontrolling interest owner of WES Operating	Distributions to noncontrolling interest owner of WES Operating	—		—		(2,551)		(2,551)		Distributions to noncontrolling interest owner of WES Operating	—		—		(2,805)		(2,805)
Distributions to Partnership unitholders	Distributions to Partnership unitholders	(128,447)		(2,818)		—		(131,265)		Distributions to Partnership unitholders	(131,786)		(2,963)		—		(134,749)
Unit repurchases (1)	Unit repurchases (1)	(16,241)		—		—		(16,241)		Unit repurchases (1)	(5,149)		—		—		(5,149)
Contributions of equity-based compensation from Occidental	Contributions of equity-based compensation from Occidental	3,210		—		—		3,210		Contributions of equity-based compensation from Occidental	1,949		—		—		1,949
Equity-based compensation expense	Equity-based compensation expense	3,524		—		—		3,524		Equity-based compensation expense	5,794		—		—		5,794
Net contributions from (distributions to) related parties	Net contributions from (distributions to) related parties	1,627		—		—		1,627		Net contributions from (distributions to) related parties	409		—		—		409
Other	Other	(2,355)		—		—		(2,355)		Other	(6,088)		—		—		(6,088)
Balance at March 31, 2021		$	2,821,455	$	(16,033)	$	136,698	$	2,942,120
Net income (loss)		226,295		4,964		7,018		238,277
Distributions to Chipeta noncontrolling interest owner		—		—		(1,245)		(1,245)
Distributions to noncontrolling interest owner of WES Operating		—		—		(2,741)		(2,741)
Distributions to Partnership unitholders		(130,115)		(2,854)		—		(132,969)

Contributions of equity-based compensation from Occidental		2,375		—		—		2,375
Equity-based compensation expense		4,746		—		—		4,746
Net contributions from (distributions to) related parties		2,881		—		—		2,881
Other		(571)		—		—		(571)
Balance at June 30, 2021		$	2,927,066	$	(13,923)	$	139,730	$	3,052,873
Balance at March 31, 2022										Balance at March 31, 2022	$	3,134,018	$	(5,062)	$	141,851	$	3,270,807
Net income (loss)	Net income (loss)	250,198		5,527		7,913		263,638		Net income (loss)	299,550		6,767		8,854		315,171
Distributions to Chipeta noncontrolling interest owner	Distributions to Chipeta noncontrolling interest owner	—		—		(1,213)		(1,213)		Distributions to Chipeta noncontrolling interest owner	—		—		(1,198)		(1,198)
Distributions to noncontrolling interest owner of WES Operating	Distributions to noncontrolling interest owner of WES Operating	—		—		(4,642)		(4,642)		Distributions to noncontrolling interest owner of WES Operating	—		—		(6,007)		(6,007)
Distributions to Partnership unitholders	Distributions to Partnership unitholders	(131,772)		(2,890)		—		(134,662)		Distributions to Partnership unitholders	(201,667)		(4,530)		—		(206,197)
Unit repurchases (1)	Unit repurchases (1)	(88,125)		—		—		(88,125)		Unit repurchases (1)	(74,068)		—		—		(74,068)
Contributions of equity-based compensation from Occidental	Contributions of equity-based compensation from Occidental	2,311		—		—		2,311		Contributions of equity-based compensation from Occidental	241		—		—		241
Equity-based compensation expense	Equity-based compensation expense	4,668		—		—		4,668		Equity-based compensation expense	6,797		—		—		6,797
Net contributions from (distributions to) related parties	Net contributions from (distributions to) related parties	2,165		—		—		2,165		Net contributions from (distributions to) related parties	375		—		—		375
Other	Other	(567)		—		—		(567)		Other	(918)		—		—		(918)
Balance at September 30, 2021		$	2,965,944	$	(11,286)	$	141,788	$	3,096,446
Balance at June 30, 2022										Balance at June 30, 2022	$	3,164,328	$	(2,825)	$	143,500	$	3,305,003

(1)See Note 5.


	Partners’ Capital
thousands	Common Units		General Partner Units		Noncontrolling Interests		Total
Balance at December 31, 2020	$	2,778,339	$	(17,208)	$	134,081	$	2,895,212
Net income (loss)	181,798		3,993		5,444		191,235
Distributions to Chipeta noncontrolling interest owner	—		—		(276)		(276)
Distributions to noncontrolling interest owner of WES Operating	—		—		(2,551)		(2,551)
Distributions to Partnership unitholders	(128,447)		(2,818)		—		(131,265)
Unit repurchases (1)	(16,241)		—		—		(16,241)
Contributions of equity-based compensation from Occidental	3,210		—		—		3,210
Equity-based compensation expense	3,524		—		—		3,524
Net contributions from (distributions to) related parties	1,627		—		—		1,627
Other	(2,355)		—		—		(2,355)
Balance at March 31, 2021	$	2,821,455	$	(16,033)	$	136,698	$	2,942,120
Net income (loss)	226,295		4,964		7,018		238,277
Distributions to Chipeta noncontrolling interest owner	—		—		(1,245)		(1,245)
Distributions to noncontrolling interest owner of WES Operating	—		—		(2,741)		(2,741)
Distributions to Partnership unitholders	(130,115)		(2,854)		—		(132,969)
Contributions of equity-based compensation from Occidental	2,375		—		—		2,375
Equity-based compensation expense	4,746		—		—		4,746
Net contributions from (distributions to) related parties	2,881		—		—		2,881
Other	(571)		—		—		(571)
Balance at June 30, 2021	$	2,927,066	$	(13,923)	$	139,730	$	3,052,873

(1)See Note 5.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF ~~EQUITY AND PARTNERS’ CAPITAL~~CASH FLOWS

(UNAUDITED)

Partners’ Capital
thousands Common
Units General Partner
Units Noncontrolling
Interests Total
Balance at December 31, 2019 $ 3,209,947 $ (14,224) $ 149,570 $ 3,345,293
Net income (loss) (251,396) (5,131) (32,873) (289,400)
Distributions to Chipeta noncontrolling interest owner — — (1,738) (1,738)
Distributions to noncontrolling interest owner of WES Operating — — (5,807) (5,807)
Distributions to Partnership unitholders (276,151) (5,635) — (281,786)
Acquisitions from related parties (3,987) — 3,987 —
Contributions of equity-based compensation from Occidental
4,105 — — 4,105
Equity-based compensation expense
1,129 — — 1,129
Net contributions from (distributions to) related parties (1)
489 — 20,000 20,489
Balance at March 31, 2020 $ 2,684,136 $ (24,990) $ 133,139 $ 2,792,285
Net income (loss) 267,576 5,461 8,304 281,341
Distributions to Chipeta noncontrolling interest owner — — (1,037) (1,037)
Distributions to noncontrolling interest owner of WES Operating — — (2,869) (2,869)
Distributions to Partnership unitholders (138,075) (2,818) — (140,893)
Contributions of equity-based compensation from Occidental 3,562 — — 3,562
Equity-based compensation expense 2,115 — — 2,115
Net contributions from (distributions to) related parties 1,343 — — 1,343
Other (330) — — (330)
Balance at June 30, 2020 $ 2,820,327 $ (22,347) $ 137,537 $ 2,935,517
Net income (loss) 241,479 5,132 7,524 254,135
Distributions to Chipeta noncontrolling interest owner — — (1,148) (1,148)
Distributions to noncontrolling interest owner of WES Operating — — (2,869) (2,869)
Distributions to Partnership unitholders (138,083) (2,817) — (140,900)
Unit exchange with Occidental (2)
(256,640) — (5,238) (261,878)
Contributions of equity-based compensation from Occidental 3,488 — — 3,488
Equity-based compensation expense 2,128 — — 2,128
Net contributions from (distributions to) related parties 842 — — 842
Other 1,141 — — 1,141
Balance at September 30, 2020 $ 2,674,682 $ (20,032) $ 135,806 $ 2,790,456



	Six Months Ended June 30,
thousands	2022		2021
Cash flows from operating activities
Net income (loss)	$	632,841	$	429,512
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	273,618		268,402
Long-lived asset and other impairments	90		27,604

Non-cash equity-based compensation expense	14,781		13,855
Deferred income taxes	1,920		1,273
Accretion and amortization of long-term obligations, net	3,586		4,002
Equity income, net – related parties	(98,071)		(110,831)
Distributions from equity-investment earnings – related parties	96,404		110,763
(Gain) loss on divestiture and other, net	780		(642)
(Gain) loss on early extinguishment of debt	(91)		289

Other	136		41
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	(279,830)		(69,164)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	82,909		39,291
Change in other items, net	14,366		(734)
Net cash provided by operating activities	743,439		713,661
Cash flows from investing activities
Capital expenditures (1)	(191,357)		(139,928)


Contributions to equity investments – related parties	(5,040)		(3,508)
Distributions from equity investments in excess of cumulative earnings – related parties	25,407		21,373

Proceeds from the sale of assets to third parties	1,096		8,003
(Increase) decrease in materials and supplies inventory and other	(1,053)		7,656
Net cash used in investing activities	(170,947)		(106,404)
Cash flows from financing activities
Borrowings, net of debt issuance costs	634,010		100,000
Repayments of debt	(883,548)		(531,085)
Increase (decrease) in outstanding checks	13,038		(29,102)
Distributions to Partnership unitholders (2)	(340,946)		(264,234)
Distributions to Chipeta noncontrolling interest owner	(3,182)		(1,521)
Distributions to noncontrolling interest owner of WES Operating	(8,812)		(5,292)
Net contributions from (distributions to) related parties	784		4,508
Unit repurchases	(79,217)		(16,241)
Other	(9,184)		(3,639)
Net cash provided by (used in) financing activities	(677,057)		(746,606)
Net increase (decrease) in cash and cash equivalents	(104,565)		(139,349)
Cash and cash equivalents at beginning of period	201,999		444,922
Cash and cash equivalents at end of period	$	97,434	$	305,573
Supplemental disclosures

Interest paid, net of capitalized interest	$	181,790	$	188,280
Income taxes paid (reimbursements received)	905		932
Accrued capital expenditures	51,878		27,592

(1)Includes purchases from related parties of $2.0 million for the six months ended June 30, 2021. See~~Services Agreement~~ ~~within~~ Note 6.

(2)See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM ~~PARTNERS,~~OPERATING, LP

CONSOLIDATED STATEMENTS OF ~~CASH FLOWS~~OPERATIONS

(UNAUDITED)

Nine Months Ended
September 30,
thousands 2021 2020
Cash flows from operating activities
Net income (loss) $ 693,150 $ 246,076
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 407,404 384,688
Long-lived asset and other impairments
29,198 200,575
Goodwill impairment — 441,017
Non-cash equity-based compensation expense
20,834 16,527
Deferred income taxes 2,275 2,393
Accretion and amortization of long-term obligations, net
5,873 6,482
Equity income, net – related parties (159,337) (176,788)
Distributions from equity-investment earnings – related parties
164,772 187,816
(Gain) loss on divestiture and other, net (278) 3,651
(Gain) loss on early extinguishment of debt 24,944 (10,372)
Cash paid to settle interest-rate swaps — (19,181)
Other 46 192
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net (130,773) (192,338)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net 56,495 37,814
Change in other items, net (9,609) 3,341
Net cash provided by operating activities 1,104,994 1,131,893
Cash flows from investing activities
Capital expenditures (217,757) (372,262)
Purchases from related parties (2,000) —
Contributions to equity investments – related parties (3,683) (19,017)
Distributions from equity investments in excess of cumulative earnings – related parties 30,075 21,750
Proceeds from the sale of assets to third parties 8,002 —
(Increase) decrease in materials and supplies inventory and other (1,924) (57,141)
Net cash used in investing activities (187,287) (426,670)
Cash flows from financing activities
Borrowings, net of debt issuance costs 400,000 3,681,173
Repayments of debt (1,132,966) (3,780,390)
Increase (decrease) in outstanding checks (11,757) 691
Distributions to Partnership unitholders (1)
(398,896) (563,579)
Distributions to Chipeta noncontrolling interest owner (2,734) (3,923)
Distributions to noncontrolling interest owner of WES Operating (9,934) (11,545)
Net contributions from (distributions to) related parties 6,673 22,674
Finance lease payments (2)
(5,295) (12,241)
Unit repurchases (104,366) —
Other (3,492) —
Net cash provided by (used in) financing activities (1,262,767) (667,140)
Net increase (decrease) in cash and cash equivalents (345,060) 38,083
Cash and cash equivalents at beginning of period 444,922 99,962
Cash and cash equivalents at end of period $ 99,862 $ 138,045
Supplemental disclosures
Non-cash unit exchange with Occidental (1)
$ — $ (261,878)
Interest paid, net of capitalized interest 348,904 307,713
Income taxes paid (reimbursements received) 932 (384)
Accrued capital expenditures 29,085 20,275



	Three Months Ended June 30,				Six Months Ended June 30,
thousands	2022		2021		2022		2021
Revenues and other
Service revenues – fee based	$	655,952	$	618,985	$	1,287,550	$	1,191,260
Service revenues – product based	70,498		27,803		111,365		59,455
Product sales	149,736		72,256		235,325		143,061
Other	233		87		476		329
Total revenues and other (1)	876,419		719,131		1,634,716		1,394,105
Equity income, net – related parties	48,464		58,666		98,071		110,831
Operating expenses
Cost of product	148,556		78,044		221,404		167,013
Operation and maintenance	168,153		153,028		297,129		293,360
General and administrative	47,227		42,848		95,088		87,078
Property and other taxes	22,662		17,967		41,104		32,351
Depreciation and amortization	139,036		137,849		273,618		268,402
Long-lived asset and other impairments	90		12,738		90		27,604

Total operating expenses (2)	525,724		442,474		928,433		875,808
Gain (loss) on divestiture and other, net	(1,150)		1,225		(780)		642
Operating income (loss)	398,009		336,548		803,574		629,770

Interest expense	(80,772)		(95,290)		(166,227)		(193,783)
Gain (loss) on early extinguishment of debt	91		—		91		(289)
Other income (expense), net	(49)		82		54		(1,128)
Income (loss) before income taxes	317,279		241,340		637,492		434,570
Income tax expense (benefit)	1,491		1,465		3,296		2,577
Net income (loss)	315,788		239,875		634,196		431,993
Net income (loss) attributable to noncontrolling interest	2,587		2,264		5,223		3,897
Net income (loss) attributable to Western Midstream Operating, LP	$	313,201	$	237,611	$	628,973	$	428,096

(1)Total revenues and other includes related-party amounts of $456.8 million and $885.5 million for the three and six months ended June 30, 2022, respectively, and $415.4 million and $793.7 million for the three and six months ended June 30, 2021, respectively. See Note 6.

(2)~~For~~Total operating expenses includes related-party amounts of $(10.5) million and $(27.2) million for the ~~nine~~three and six months ended ~~September~~June 30, ~~2020, includes related-party payments of $6.4 million.~~2022, respectively, and $29.6 million and $69.9 million for the three and six months ended June 30, 2021, respectively. See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED ~~STATEMENTS OF OPERATIONS~~BALANCE SHEETS

(UNAUDITED)

Three Months Ended
September 30, Nine Months Ended
September 30,
thousands 2021 2020 2021 2020
Revenues and other
Service revenues – fee based $ 650,482 $ 636,522 $ 1,841,742 $ 1,980,546
Service revenues – product based 28,812 12,316 88,267 35,237
Product sales 84,298 30,106 227,359 108,491
Other 248 100 577 838
Total revenues and other (1)
763,840 679,044 2,157,945 2,125,112
Equity income, net – related parties 48,506 61,026 159,337 176,788
Operating expenses
Cost of product 83,232 31,739 250,245 153,611
Operation and maintenance 140,838 132,293 434,198 436,670
General and administrative 50,689 41,483 137,767 115,783
Property and other taxes 13,641 19,392 45,992 57,263
Depreciation and amortization 139,002 132,564 407,404 384,688
Long-lived asset and other impairments
1,594 34,640 29,198 200,575
Goodwill impairment — — — 441,017
Total operating expenses (2)
428,996 392,111 1,304,804 1,789,607
Gain (loss) on divestiture and other, net (364) (768) 278 (3,651)
Operating income (loss) 382,986 347,191 1,012,756 508,642
Interest income – Anadarko note receivable — 3,286 — 11,736
Interest expense (93,257) (95,571) (287,040) (278,811)
Gain (loss) on early extinguishment of debt (24,655) 1,632 (24,944) 10,372
Other income (expense), net 106 718 (1,022) 606
Income (loss) before income taxes 265,180 257,256 699,750 252,545
Income tax expense (benefit) 1,823 3,028 4,400 3,792
Net income (loss) 263,357 254,228 695,350 248,753
Net income (loss) attributable to noncontrolling interest 2,699 2,488 6,596 (22,471)
Net income (loss) attributable to Western Midstream Operating, LP $ 260,658 $ 251,740 $ 688,754 $ 271,224




thousands except number of units	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	79,898	$	195,598
Accounts receivable, net	716,343		436,513
Other current assets	48,276		44,421
Total current assets	844,517		676,532
Property, plant, and equipment
Cost	13,058,689		12,846,078
Less accumulated depreciation	4,581,122		4,333,171
Net property, plant, and equipment	8,477,567		8,512,907
Goodwill	4,783		4,783
Other intangible assets	728,908		744,742
Equity investments	1,148,487		1,167,187
Other assets (1)	164,985		158,696
Total assets (2)	$	11,369,247	$	11,264,847
LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables	$	519,125	$	374,443
Short-term debt	2,613		505,932
Accrued ad valorem taxes	41,268		44,955
Accrued liabilities	179,243		210,693

Total current liabilities	742,249		1,136,023
Long-term liabilities
Long-term debt	6,656,123		6,400,616
Deferred income taxes	14,345		12,425
Asset retirement obligations	303,548		298,275
Other liabilities	354,478		324,842
Total long-term liabilities	7,328,494		7,036,158
Total liabilities (3)	8,070,743		8,172,181
Equity and partners’ capital
Common units (318,675,578 units issued and outstanding at June 30, 2022, and December 31, 2021)	3,267,086		3,063,289



Total partners’ capital	3,267,086		3,063,289
Noncontrolling interest	31,418		29,377
Total equity and partners’ capital	3,298,504		3,092,666
Total liabilities, equity, and partners’ capital	$	11,369,247	$	11,264,847

(1)Other assets includes $12.2 million and $9.8 million of NGLs line-fill inventory as of June 30, 2022, and December 31, 2021, respectively. Other assets also includes $55.3 million and $56.2 million of materials and supplies inventory as of June 30, 2022, and December 31, 2021, respectively.

(2)Total ~~revenues and other~~assets includes related-party amounts of ~~$431.7 million and $1.2~~$1.5 billion ~~for the three and nine months ended September 30, 2021, respectively, and $455.6 million~~ and $1.4 billion ~~for the three~~as of June 30, 2022, and ~~nine months ended September~~December 31, 2021, respectively, which includes related-party Accounts receivable, net of $322.7 million and $180.2 million as of June 30, ~~2020,~~2022, and December 31, 2021, respectively. See Note 6.

~~(2)~~(3)Total ~~operating expenses~~liabilities includes related-party amounts of ~~$23.7~~$314.2 million and ~~$93.6~~$318.7 million ~~for the three~~as of June 30, 2022, and ~~nine months ended September 30,~~December 31, 2021, ~~respectively, and $11.1 million and $162.2 million for the three and nine months ended September 30, 2020,~~ respectively. See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED ~~BALANCE SHEETS~~STATEMENTS OF EQUITY AND PARTNERS’ CAPITAL

(UNAUDITED)

thousands except number of units September 30,
2021 December 31,
2020
ASSETS
Current assets
Cash and cash equivalents $ 92,863 $ 418,537
Accounts receivable, net 583,652 407,549
Other current assets 70,907 43,244
Total current assets 747,422 869,330
Property, plant, and equipment
Cost 12,732,926 12,641,745
Less accumulated depreciation 4,208,845 3,931,800
Net property, plant, and equipment 8,524,081 8,709,945
Goodwill 4,783 4,783
Other intangible assets 752,659 776,409
Equity investments 1,181,181 1,224,813
Other assets (1)
199,964 171,013
Total assets (2)
$ 11,410,090 $ 11,756,293
LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables $ 382,406 $ 210,532
Short-term debt
726,429 438,870
Accrued ad valorem taxes 49,065 41,427
Accrued liabilities 145,241 230,833
Total current liabilities 1,303,141 921,662
Long-term liabilities
Long-term debt
6,399,874 7,415,832
Deferred income taxes 24,470 22,195
Asset retirement obligations 271,022 260,283
Other liabilities 320,224 275,570
Total long-term liabilities
7,015,590 7,973,880
Total liabilities (3)
8,318,731 8,895,542
Equity and partners’ capital
Common units (318,675,578 units issued and outstanding at September 30, 2021, and December 31, 2020) 3,057,945 2,831,199
Total partners’ capital 3,057,945 2,831,199
Noncontrolling interest 33,414 29,552
Total equity and partners’ capital 3,091,359 2,860,751
Total liabilities, equity, and partners’ capital $ 11,410,090 $ 11,756,293


thousands	Common Units		Noncontrolling Interest		Total

























Balance at December 31, 2021	$	3,063,289	$	29,377	$	3,092,666
Net income (loss)	315,772		2,636		318,408
Distributions to Chipeta noncontrolling interest owner	—		(1,984)		(1,984)
Distributions to WES Operating unitholders	(140,217)		—		(140,217)
Contributions of equity-based compensation from Occidental	1,949		—		1,949
Contributions of equity-based compensation from WES	5,663		—		5,663
Net contributions from (distributions to) related parties	409		—		409

Balance at March 31, 2022	$	3,246,865	$	30,029	$	3,276,894
Net income (loss)	313,201		2,587		315,788
Distributions to Chipeta noncontrolling interest owner	—		(1,198)		(1,198)
Distributions to WES Operating unitholders	(300,248)		—		(300,248)
Contributions of equity-based compensation from Occidental	241		—		241
Contributions of equity-based compensation from WES	6,652		—		6,652
Net contributions from (distributions to) related parties	375		—		375

Balance at June 30, 2022	$	3,267,086	$	31,418	$	3,298,504

~~(1)Other assets includes $11.2 million and $4.2 million of NGLs line~~-fill inventory as of September 30, 2021, and December 31, 2020, respectively. Other assets also includes $63.1 million and $71.9 million of materials and supplies inventory as of September 30, 2021, and December 31, 2020, respectively.

~~(2)Total assets includes related~~-~~party amounts of $1.6 billion and $1.5 billion as of September 30, 2021, and December 31, 2020, respectively, which includes related~~-~~party Accounts receivable, net of $289.4 million and $246.1 million as of September 30, 2021, and December 31, 2020, respectively. See~~ ~~Note 6~~.


thousands	Common Units		Noncontrolling Interest		Total
Balance at December 31, 2020	$	2,831,199	$	29,552	$	2,860,751
Net income (loss)	190,485		1,633		192,118
Distributions to Chipeta noncontrolling interest owner	—		(276)		(276)
Distributions to WES Operating unitholders	(127,470)		—		(127,470)
Contributions of equity-based compensation from Occidental	3,210		—		3,210
Contributions of equity-based compensation from WES	10,826		—		10,826
Net contributions from (distributions to) related parties	1,627		—		1,627
Balance at March 31, 2021	$	2,909,877	$	30,909	$	2,940,786
Net income (loss)	237,611		2,264		239,875
Distributions to Chipeta noncontrolling interest owner	—		(1,245)		(1,245)
Distributions to WES Operating unitholders	(137,030)		—		(137,030)
Contributions of equity-based compensation from Occidental	2,375		—		2,375
Contributions of equity-based compensation from WES	4,613		—		4,613
Net contributions from (distributions to) related parties	2,881		—		2,881
Balance at June 30, 2021	$	3,020,327	$	31,928	$	3,052,255

~~(3)Total liabilities includes related~~-~~party amounts of $291.6 million and $164.3 million as of September 30, 2021, and December 31, 2020, respectively. See~~ ~~Note 6~~.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED STATEMENTS OF ~~EQUITY AND PARTNERS’ CAPITAL~~CASH FLOWS

(UNAUDITED)

thousands Common
Units Noncontrolling
Interest Total
Balance at December 31, 2020 $ 2,831,199 $ 29,552 $ 2,860,751
Net income (loss) 190,485 1,633 192,118
Distributions to Chipeta noncontrolling interest owner — (276) (276)
Distributions to WES Operating unitholders (127,470) — (127,470)
Contributions of equity-based compensation from Occidental
3,210 — 3,210
Contributions of equity-based compensation from WES
10,826 — 10,826
Net contributions from (distributions to) related parties 1,627 — 1,627
Balance at March 31, 2021 $ 2,909,877 $ 30,909 $ 2,940,786
Net income (loss) 237,611 2,264 239,875
Distributions to Chipeta noncontrolling interest owner — (1,245) (1,245)
Distributions to WES Operating unitholders (137,030) — (137,030)
Contributions of equity-based compensation from Occidental
2,375 — 2,375
Contributions of equity-based compensation from WES
4,613 — 4,613
Net contributions from (distributions to) related parties 2,881 — 2,881
Balance at June 30, 2021 $ 3,020,327 $ 31,928 $ 3,052,255
Net income (loss) 260,658 2,699 263,357
Distributions to Chipeta noncontrolling interest owner — (1,213) (1,213)
Distributions to WES Operating unitholders (232,055) — (232,055)
Contributions of equity-based compensation from Occidental
2,311 — 2,311
Contributions of equity-based compensation from WES
4,539 — 4,539
Net contributions from (distributions to) related parties 2,165 — 2,165
Balance at September 30, 2021 $ 3,057,945 $ 33,414 $ 3,091,359

~~See accompanying Notes to Consolidated Financial Statements.~~

~~Table of Contents~~

~~WESTERN MIDSTREAM OPERATING, LP~~

~~CONSOLIDATED STATEMENTS OF EQUITY AND PARTNERS’ CAPITAL~~

~~(UNAUDITED)~~

thousands Common
Units Noncontrolling
Interest Total
Balance at December 31, 2019 $ 3,286,620 $ 55,199 $ 3,341,819
Net income (loss) (260,330) (27,665) (287,995)
Distributions to Chipeta noncontrolling interest owner — (1,738) (1,738)
Distributions to WES Operating unitholders (290,314) — (290,314)
Acquisitions from related parties (3,987) 3,987 —
Contributions of equity-based compensation from Occidental
4,105 — 4,105
Net contributions from (distributions to) related parties (1)
20,489 — 20,489
Balance at March 31, 2020 $ 2,756,583 $ 29,783 $ 2,786,366
Net income (loss) 279,814 2,706 282,520
Distributions to Chipeta noncontrolling interest owner — (1,037) (1,037)
Distributions to WES Operating unitholders (143,404) — (143,404)
Contributions of equity-based compensation from Occidental 3,562 — 3,562
Net contributions from (distributions to) related parties 1,343 — 1,343
Balance at June 30, 2020 $ 2,897,898 $ 31,452 $ 2,929,350
Net income (loss) 251,740 2,488 254,228
Distributions to Chipeta noncontrolling interest owner — (1,148) (1,148)
Distributions to WES Operating unitholders (143,404) — (143,404)
Contributions of equity-based compensation from Occidental 3,488 — 3,488
Unit exchange with Occidental (2)
(261,878) — (261,878)
Net contributions from (distributions to) related parties 842 — 842
Other 1,545 — 1,545
Balance at September 30, 2020 $ 2,750,231 $ 32,792 $ 2,783,023



	Six Months Ended June 30,
thousands	2022		2021
Cash flows from operating activities
Net income (loss)	$	634,196	$	431,993
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	273,618		268,402
Long-lived asset and other impairments	90		27,604

Non-cash equity-based compensation expense	14,505		21,024
Deferred income taxes	1,920		1,273
Accretion and amortization of long-term obligations, net	3,586		4,002
Equity income, net – related parties	(98,071)		(110,831)
Distributions from equity-investment earnings – related parties	96,404		110,763
(Gain) loss on divestiture and other, net	780		(642)
(Gain) loss on early extinguishment of debt	(91)		289

Other	136		41
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	(279,830)		(111,567)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	74,551		73,215
Change in other items, net	14,889		(1,591)
Net cash provided by operating activities	736,683		713,975
Cash flows from investing activities
Capital expenditures (1)	(191,357)		(139,928)


Contributions to equity investments – related parties	(5,040)		(3,508)
Distributions from equity investments in excess of cumulative earnings – related parties	25,407		21,373

Proceeds from the sale of assets to third parties	1,096		8,003
(Increase) decrease in materials and supplies inventory and other	(1,053)		7,656
Net cash used in investing activities	(170,947)		(106,404)
Cash flows from financing activities
Borrowings, net of debt issuance costs	634,010		100,000
Repayments of debt	(883,548)		(531,085)
Increase (decrease) in outstanding checks	13,142		(29,110)
Distributions to WES Operating unitholders (2)	(440,465)		(264,500)
Distributions to Chipeta noncontrolling interest owner	(3,182)		(1,521)
Net contributions from (distributions to) related parties	784		4,508
Other	(2,177)		(3,639)
Net cash provided by (used in) financing activities	(681,436)		(725,347)
Net increase (decrease) in cash and cash equivalents	(115,700)		(117,776)
Cash and cash equivalents at beginning of period	195,598		418,537
Cash and cash equivalents at end of period	$	79,898	$	300,761
Supplemental disclosures


Interest paid, net of capitalized interest	$	181,790	$	188,280
Income taxes paid (reimbursements received)	905		932
Accrued capital expenditures	51,878		27,592

(1)Includes purchases from related parties of $2.0 million for the six months ended June 30, 2021. See~~Services Agreement~~ ~~within~~ Note 6.

(2)See Note 6.

See accompanying Notes to Consolidated Financial Statements.

~~Table of Contents~~

~~WESTERN MIDSTREAM OPERATING, LP~~

~~CONSOLIDATED STATEMENTS OF CASH FLOWS~~

~~(UNAUDITED)~~

Nine Months Ended
September 30,
thousands 2021 2020
Cash flows from operating activities
Net income (loss) $ 695,350 $ 248,753
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 407,404 384,688
Long-lived asset and other impairments
29,198 200,575
Goodwill impairment — 441,017
Non-cash equity-based compensation expense
27,874 11,155
Deferred income taxes 2,275 2,393
Accretion and amortization of long-term obligations, net
5,873 6,482
Equity income, net – related parties (159,337) (176,788)
Distributions from equity-investment earnings – related parties
164,772 187,816
(Gain) loss on divestiture and other, net (278) 3,651
(Gain) loss on early extinguishment of debt 24,944 (10,372)
Cash paid to settle interest-rate swaps — (19,181)
Other 46 192
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net (176,104) (155,008)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net 91,508 4,836
Change in other items, net (9,336) 3,763
Net cash provided by operating activities 1,104,189 1,133,972
Cash flows from investing activities
Capital expenditures (217,757) (372,262)
Purchases from related parties (2,000) —
Contributions to equity investments – related parties (3,683) (19,017)
Distributions from equity investments in excess of cumulative earnings – related parties 30,075 21,750
Proceeds from the sale of assets to third parties 8,002 —
(Increase) decrease in materials and supplies inventory and other (1,924) (57,141)
Net cash used in investing activities (187,287) (426,670)
Cash flows from financing activities
Borrowings, net of debt issuance costs 400,000 3,681,173
Repayments of debt (1,132,966) (3,780,390)
Increase (decrease) in outstanding checks (11,699) 1,007
Distributions to WES Operating unitholders (1)
(496,555) (577,122)
Distributions to Chipeta noncontrolling interest owner (2,734) (3,923)
Net contributions from (distributions to) related parties 6,673 22,674
Finance lease payments (2)
(5,295) (12,241)
Net cash provided by (used in) financing activities (1,242,576) (668,822)
Net increase (decrease) in cash and cash equivalents (325,674) 38,480
Cash and cash equivalents at beginning of period 418,537 98,122
Cash and cash equivalents at end of period $ 92,863 $ 136,602
Supplemental disclosures
Non-cash unit exchange with Occidental (1)
$ — $ (261,878)
Interest paid, net of capitalized interest 348,904 307,713
Income taxes paid (reimbursements received) 932 (384)
Accrued capital expenditures 29,085 20,275

~~(1)See~~ ~~Note 6.~~

~~(2)For the nine months ended September 30, 2020, includes related-party payments of $6.4 million.~~

~~See accompanying Notes to Consolidated Financial Statements.~~

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION

General. Western Midstream Partners, LP is a Delaware master limited partnership formed in September 2012. Western Midstream Operating, LP (together with its subsidiaries, “WES Operating”) is a Delaware limited partnership formed in 2007 to acquire, own, develop, and operate midstream assets. Western Midstream Partners, LP owns, directly and indirectly, a 98.0% limited partner interest in WES Operating, and directly owns all of the outstanding equity interests of Western Midstream Operating GP, LLC, which holds the entire non-economic general partner interest in WES Operating.

For purposes of these consolidated financial statements, the “Partnership” refers to Western Midstream Partners, LP in its individual capacity or to Western Midstream Partners, LP and its subsidiaries, including Western Midstream Operating GP, LLC and WES Operating, as the context requires. “WES Operating GP” refers to Western Midstream Operating GP, LLC, individually as the general partner of WES Operating. The Partnership’s general partner, Western Midstream Holdings, LLC (the “general partner”), is a wholly owned subsidiary of Occidental Petroleum Corporation. “Occidental” refers to Occidental Petroleum Corporation, as the context requires, and its subsidiaries, excluding the general partner. “Anadarko” refers to Anadarko Petroleum Corporation and its subsidiaries, excluding Western Midstream Holdings, LLC. Anadarko became a wholly owned subsidiary of Occidental as a result of Occidental’s acquisition by merger of Anadarko on August 8, 2019. “Related parties” refers to Occidental (see Note 6), the Partnership’s investments accounted for under the equity method of accounting (see Note 7), and the Partnership and WES Operating for transactions that eliminate upon consolidation (see Note 6).

The Partnership is engaged in the business of gathering, compressing, treating, processing, and transporting natural gas; gathering, stabilizing, and transporting condensate, natural-gas liquids (“NGLs”), and crude oil; and gathering and disposing of produced water. In its capacity as a natural-gas processor, the Partnership also buys and sells natural gas, NGLs, and condensate on behalf of itself and as an agent for its customers under certain contracts. As of ~~September~~June 30, ~~2021,~~2022, the Partnership’s assets and investments consisted of the following:


		Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests		Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems (1)	Gathering systems (1)	17	2	3	1	Gathering systems (1)	17	2	3	1
Treating facilities	Treating facilities	36	3	—	—	Treating facilities	37	3	—	—
Natural-gas processing plants/trains	Natural-gas processing plants/trains	24	3	—	5	Natural-gas processing plants/trains	24	3	—	5
NGLs pipelines	NGLs pipelines	2	—	—	5	NGLs pipelines	2	—	—	5
Natural-gas pipelines	Natural-gas pipelines	5	—	—	1	Natural-gas pipelines	5	—	—	1
Crude-oil pipelines	Crude-oil pipelines	3	1	—	4	Crude-oil pipelines	3	1	—	4

(1)Includes the DBM water systems.

These assets and investments are located in Texas, New Mexico, the Rocky Mountains (Colorado, Utah, and Wyoming), and North-central Pennsylvania.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION

Basis of presentation. The consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”) and include the accounts of the Partnership and entities in which it holds a controlling financial interest, including WES Operating, WES Operating GP, proportionately consolidated interests, and equity investments (see table below). All significant intercompany transactions have been eliminated.

The following table outlines the ownership interests and the accounting method of consolidation used in the consolidated financial statements for entities not wholly owned:


	Percentage Interest
Full consolidation
Chipeta (1)	75.00	%
Proportionate consolidation (2)
Springfield system	50.10	%
Marcellus Interest systems	33.75	%
Equity investments (3)
Mi Vida JV LLC (“Mi Vida”)	50.00	%
Ranch Westex JV LLC (“Ranch Westex”)	50.00	%
Front Range Pipeline LLC (“FRP”)	33.33	%
Red Bluff Express Pipeline, LLC (“Red Bluff Express”)	30.00	%
Enterprise EF78 LLC (“Mont Belvieu JV”)	25.00	%
Rendezvous Gas Services, LLC (“Rendezvous”)	22.00	%
Texas Express Pipeline LLC (“TEP”)	20.00	%
Texas Express Gathering LLC (“TEG”)	20.00	%
Whitethorn Pipeline Company LLC (“Whitethorn LLC”)	20.00	%
Saddlehorn Pipeline Company, LLC (“Saddlehorn”)	20.00	%
Cactus II Pipeline LLC (“Cactus II”)	15.00	%
Panola Pipeline Company, LLC (“Panola”)	15.00	%
White Cliffs Pipeline, LLC (“White Cliffs”)	10.00	%

(1)The 25% third-party interest in Chipeta Processing LLC (“Chipeta”) is reflected within noncontrolling interests in the consolidated financial statements. See Noncontrolling interests below.

(2)The Partnership proportionately consolidates its associated share of the assets, liabilities, revenues, and expenses attributable to these assets.

(3)Investments in non-controlled entities over which the Partnership exercises significant influence are accounted for under the equity method of accounting. “Equity-investment throughput” refers to the Partnership’s share of average throughput for these investments.

Certain information and note disclosures commonly included in annual financial statements have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the accompanying consolidated financial statements and notes should be read in conjunction with the Partnership’s ~~2020~~2021 Form 10-K,10-K, as filed with the SEC on February ~~26, 2021.~~23, 2022. Management believes that the disclosures made are adequate to make the information not misleading.

1816

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION

The consolidated financial results of WES Operating are included in the Partnership’s consolidated financial statements. Throughout these notes to consolidated financial statements, and to the extent material, any differences between the consolidated financial results of the Partnership and WES Operating are discussed separately. The Partnership’s consolidated financial statements differ from those of WES Operating primarily as a result of (i) the presentation of noncontrolling interest ownership (see Noncontrolling interests below), (ii) the elimination of WES Operating GP’s investment in WES Operating with WES Operating GP’s underlying capital account, (iii) the general and administrative expenses incurred by the Partnership, which are separate from, and in addition to, those incurred by WES Operating, (iv) the inclusion of the impact of Partnership equity balances and Partnership distributions, and (v) transactions between the Partnership and WES Operating that eliminate upon consolidation.

Presentation of the Partnership’s assets. The Partnership’s assets include assets owned and ownership interests accounted for by the Partnership under the equity method of accounting, through its 98.0% partnership interest in WES Operating, as of ~~September~~June 30, ~~2021~~2022 (see Note 7). The Partnership also owns and controls the entire non-economic general partner interest in WES Operating GP, and the Partnership’s general partner is owned by Occidental.

Use of estimates. In preparing financial statements in accordance with GAAP, management makes informed judgments and estimates that affect the reported amounts of assets, liabilities, revenues, and expenses. Management evaluates its estimates and related assumptions regularly, using historical experience and other reasonable methods. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from these estimates. Effects on the business, financial condition, and results of operations resulting from revisions to estimates are recognized when the facts that give rise to the revisions become known. The information included herein reflects all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the consolidated financial ~~statements.~~statements, and certain prior-period amounts have been reclassified to conform to the current-year presentation.

Noncontrolling interests. The Partnership’s noncontrolling interests in the consolidated financial statements consist of (i) the 25% third-party interest in Chipeta and (ii) the 2.0% Occidental subsidiary-owned limited partner interest in WES Operating. WES Operating’s noncontrolling interest in the consolidated financial statements consists of the 25% third-party interest in Chipeta. See Note 5.

Segments. The Partnership’s operations continue to be organized into a single operating segment, the assets of which gather, compress, treat, process, and transport natural gas; gather, stabilize, and transport condensate, NGLs, and crude oil; and gather and dispose of produced water in the United States.

Equity-based compensation. During the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, the Partnership issued ~~357,472~~568,984 common units under its long-term incentive plans. Compensation expense was ~~$4.7~~$6.8 million and ~~$12.9~~$12.6 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~$2.1~~$4.7 million and ~~$5.4~~$8.3 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively.

~~On March 22, 2021, the Board of Directors approved the Western Midstream Partners, LP 2021 Long~~-Term Incentive Plan (the “2021 LTIP”). Subject to the capitalization adjustment provisions included in the 2021 LTIP, the total aggregate number of common units that may be delivered with respect to awards under the 2021 LTIP is 9,500,000 (the “2021 LTIP Limit”). Common units withheld from an award or surrendered by a participant to satisfy tax withholding obligations or to satisfy the payment of any exercise price with respect to an award will not be considered to be common units delivered under the 2021 LTIP for purposes of the 2021 LTIP Limit. If any award is forfeited, cancelled, exercised, settled in cash, or otherwise terminates or expires without the actual delivery of common units, the common units subject to such award will again be available for awards under the 2021 LTIP. The 2021 LTIP provides for the grant of unit options, unit appreciation rights, restricted units, phantom units, other unit-based awards, cash awards, and a unit award or a substitute award to employees and directors of the Partnership and its general partner. Affiliates of Occidental who held a majority of the Partnership’s outstanding common units as of March 22, 2021, approved the 2021 LTIP via written consent. On April 7, 2021, the Partnership mailed an information statement on Schedule 14C to its unitholders of record as of March 22, 2021. The 2021 LTIP became effective on April 27, 2021.

1917

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

~~1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION~~

~~Defined-contribution plan.Beginning in the first quarter of 2020, employees of the Partnership are eligible to participate in the Western Midstream Savings Plan, a defined~~-contribution benefit plan maintained by the Partnership. All regular employees may participate in the plan by making elective contributions that are matched by the Partnership, subject to certain limitations. The Partnership also makes other contributions based on plan guidelines. The Partnership recognized expense related to the plan of $5.3 million and $18.3 million for the three and nine months ended September 30, 2021, respectively, and $3.8 million and $8.2 million for the three and nine months ended September 30, 2020, respectively.

2. REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table summarizes revenue from contracts with customers:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands	thousands	2021		2020		2021		2020		thousands	2022		2021		2022		2021
Revenue from customers	Revenue from customers									Revenue from customers
Service revenues – fee based	Service revenues – fee based	$	605,967	$	582,725	$	1,707,987	$	1,806,097	Service revenues – fee based	$	655,952	$	572,607	$	1,287,550	$	1,102,020
Service revenues – product based	Service revenues – product based	28,812		12,316		88,267		35,237		Service revenues – product based	70,498		27,803		111,365		59,455
Product sales	Product sales	84,298		30,106		227,359		108,491		Product sales	149,736		72,256		235,325		143,061
Total revenue from customers	Total revenue from customers	719,077		625,147		2,023,613		1,949,825		Total revenue from customers	876,186		672,666		1,634,240		1,304,536
Revenue from other than customers	Revenue from other than customers									Revenue from other than customers
Lease revenue (1)	Lease revenue (1)	44,515		53,797		133,755		174,449		Lease revenue (1)	—		46,378		—		89,240

Other	Other	248		100		577		838		Other	233		87		476		329
Total revenues and other	Total revenues and other	$	763,840	$	679,044	$	2,157,945	$	2,125,112	Total revenues and other	$	876,419	$	719,131	$	1,634,716	$	1,394,105

(1)Includes fixed- and variable-lease revenue from an operating and maintenance agreement entered into with Occidental. See Operating leases within Note 6.

~~Certain of the Partnership’s midstream services contracts have minimum~~-~~volume commitment demand fees and fees that require periodic rate redeterminations based on the related facility cost~~-of-service rate provisions. During the year ended December 31, 2020, and the six months ended June 30, 2021, the Partnership constrained revenue on certain cost-of-service agreements based on the status of commercial negotiations relating to a legal dispute with one of the contract counterparties. During the three months ended September 30, 2021, the Partnership determined it was no longer necessary to constrain revenue under these cost-of-service agreements. The Partnership updated its estimate of variable consideration and a cumulative catch-up revenue adjustment of $18.9 million was recorded to Service revenues – fee based. Future revenue reversals could occur to the extent the outcome of the legal proceedings and commercial negotiations differ from our current assumptions.

~~Table of Contents~~

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~2. REVENUE FROM CONTRACTS WITH CUSTOMERS~~

Contract balances. Receivables from customers, which are included in Accounts receivable, net on the consolidated balance sheets were ~~$572.8~~$705.3 million and ~~$428.2~~$424.6 million as of ~~September~~June 30, ~~2021,~~2022, and December 31, ~~2020,~~2021, respectively.

Contract assets primarily relate to (i) revenue accrued but not yet billed under cost-of-service contracts with fixed and variable fees and (ii) accrued deficiency fees the Partnership expects to charge customers once the related performance periods are completed. The following table summarizes activity related to contract assets from contracts with customers:

thousands

Contract assets balance at December 31, ~~2020~~2021

~~56,344~~22,557

Amounts transferred to Accounts receivable, net that were included in the contract assets balance at the beginning of the period(1)

~~(3,858)~~(336)

Additional estimated revenues recognized (2)

~~17,472~~12,444

Contract assets balance at ~~September~~June 30, ~~2021~~2022

~~69,958~~34,665

Contract assets at ~~September~~June 30, ~~2021~~2022

Other current assets

~~23,766~~16,512

Other assets

~~46,192~~18,153

Total contract assets from contracts with customers

~~69,958~~34,665

(1)Includes ~~$(3.9)~~$(0.1) million for the three months ended ~~September~~June 30, ~~2021.~~2022.

(2)Includes ~~$8.9~~$5.9 million for the three months ended ~~September~~June 30, ~~2021.~~2022.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. REVENUE FROM CONTRACTS WITH CUSTOMERS

Contract liabilities primarily relate to (i) ~~aid~~-in-~~construction payments received from customers that must be recognized over the expected period of customer benefit, (ii)~~ fixed and variable fees under cost-of-service contracts that are received from customers for which revenue recognition is deferred, (ii) aid-in-construction payments received from customers that must be recognized over the expected period of customer benefit, and (iii) fees that are charged to customers for only a portion of the contract term and must be recognized as revenues over the expected period of customer benefit. The following table summarizes activity related to contract liabilities from contracts with customers:

thousands

Contract liabilities balance at December 31, ~~2020~~2021

~~266,937~~313,146

Cash received or receivable, excluding revenues recognized during the period (1)

~~60,786~~28,036

Revenues recognized that were included in the contract liability balance at the beginning of the period(2)

~~(13,553)~~(13,932)

~~Cumulative catch-up adjustment for change in estimated consideration~~ ~~(3)~~

~~(17,209)~~

Contract liabilities balance at ~~September~~June 30, ~~2021~~2022

~~296,961~~327,250

Contract liabilities at ~~September~~June 30, ~~2021~~2022

Accrued liabilities

~~22,854~~9,142

Other liabilities

~~274,107~~318,108

Total contract liabilities from contracts with customers

~~296,961~~327,250

(1)Includes ~~$26.7~~$19.8 million for the three months ended ~~September~~June 30, ~~2021.~~2022.

(2)Includes ~~$(5.5)~~$(2.7) million for the three months ended ~~September~~June 30, ~~2021, $(1.7) million of which is related to the cumulative catch-up revenue adjustment recognized for the nine months ended September 30, 2021.~~2022.

~~(3)Includes $(17.2) million for the three months ended September 30, 2021.~~

~~Table of Contents~~

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~2. REVENUE FROM CONTRACTS WITH CUSTOMERS~~

Transaction price allocated to remaining performance obligations. Revenues expected to be recognized from certain performance obligations that are unsatisfied (or partially unsatisfied) as of ~~September~~June 30, ~~2021,~~2022, are presented in the following table. The Partnership applies the optional exemptions in Revenue from Contracts with Customers (Topic 606) and does not disclose consideration for remaining performance obligations with an original expected duration of one year or less or for variable consideration related to unsatisfied (or partially unsatisfied) performance obligations. Therefore, the following table represents only a portion of expected future revenues from existing contracts as most future revenues from customers are dependent on future variable customer volumes and, in some cases, variable commodity prices for those volumes.


thousands	thousands			thousands
Remainder of 2021		$	211,353
2022		1,057,409
Remainder of 2022				Remainder of 2022	$	550,444
2023	2023	1,002,351		2023	1,046,368
2024	2024	973,300		2024	1,020,299
2025	2025	890,903		2025	936,523
2026				2026	808,712
Thereafter	Thereafter	2,719,380		Thereafter	2,176,400
Total	Total	$	6,854,696	Total	$	6,538,746

3. ACQUISITIONS AND DIVESTITURES

~~Fort Union and~~ Bison ~~facilities.~~facility. In October 2020, the Partnership ~~(i) sold its 14.81% interest in Fort Union Gas Gathering, LLC (“Fort Union”), which was accounted for under the equity method of accounting, and (ii)~~ entered into an option agreement to sell the Bison treating facility, located in Northeast Wyoming, to a third party. The Partnership received combined proceeds of $27.0 million, resulting in a net gain on sale of $21.0 million related to the Fort Union interest that was recorded in the fourth quarter of 2020 as Gain (loss) on divestiture and other, net in the consolidated statements of operations.

During the second quarter of 2021, the third party exercised its option to purchase the Bison treating facility and the sale closed. The Partnership received total proceeds of $8.0 million, $7.0 million in the fourth quarter of 2020 and $1.0 million when the sale closed in the second quarter of 2021, resulting in a net gain on sale of $5.4 million that was recorded as Gain (loss) on divestiture and other, net in the consolidated statements of operations.

2219

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

4. PARTNERSHIP DISTRIBUTIONS

Partnership distributions. Under its partnership agreement, the Partnership distributes all of its available cash (beyond proper reserves as defined in its partnership agreement) to unitholders of record on the applicable record date within 55 days following each quarter’s end. The Board of Directors of the general partner (the ~~“Board of Directors”~~“Board”) declared the following cash distributions to the Partnership’s unitholders for the periods presented:

thousands except per-unit amounts
Quarters Ended
Total Quarterly
Per-unit
Distribution Total Quarterly
Cash Distribution Distribution
Date
2020
March 31 $ 0.31100 $ 140,893 May 2020
June 30 0.31100 140,900 August 2020
September 30 0.31100 132,255 November 2020
December 31 0.31100 131,265 February 2021
2021
March 31 $ 0.31500 $ 132,969 May 2021
June 30 0.31900 134,662 August 2021
September 30 (1)
0.32300 134,862 November 2021

~~(1)~~The Board of Directors declared a cash distribution to the Partnership’s unitholders for the third quarter of 2021 of $0.32300 per unit, or $134.9 million in aggregate. The cash distribution is payable on November 12, 2021, to unitholders of record at the close of business on November 1, 2021, including the general partner units.


thousands except per-unit amounts Quarters Ended	Total Quarterly Per-unit Distribution		Total Quarterly Cash Distribution		Distribution Date	Record Date





2021
March 31	$	0.31500	$	132,969	May 14, 2021	April 30, 2021
June 30	0.31900		134,662		August 13, 2021	July 30, 2021
September 30	0.32300		134,862		November 12, 2021	November 1, 2021
December 31	0.32700		134,749		February 14, 2022	January 31, 2022
2022
March 31	$	0.50000	$	206,197	May 13, 2022	May 2, 2022
June 30	0.50000		197,744		August 12, 2022	August 1, 2022

Available cash. The amount of available cash (beyond proper reserves as defined in ~~our~~the partnership agreement) generally is all cash on hand at the end of the quarter, plus, at the discretion of the general partner, working capital borrowings made subsequent to the end of such quarter, less the amount of cash reserves established by the general partner to provide for the proper conduct of the Partnership’s business, including ~~reserves~~(i) to fund future capital expenditures; (ii) to comply with applicable laws, debt instruments, or other agreements; or (iii) to provide funds for unitholder distributions for any one or more of the next four quarters. Working capital borrowings generally include borrowings made under a credit facility or similar financing arrangement and are intended to be repaid or refinanced within 12 months. In all cases, working capital borrowings are used solely for working capital purposes or to fund unitholder distributions.

WES Operating partnership distributions. WES Operating makes quarterly cash distributions to the Partnership and WGR Asset Holding Company LLC (“WGRAH”), a subsidiary of Occidental, in proportion to their share of limited partner interests in WES Operating. See Note 5. WES Operating made the following cash distributions to its limited partners for the periods presented:

thousands

Quarters Ended

Total Quarterly
Cash Distribution

Distribution
Date

~~2020~~

~~March 31~~

~~143,404~~

~~June 30~~

~~143,404~~

~~September 30~~

~~143,404~~

~~December 31~~

~~127,470~~

2021

March 31

137,030

May 2021

June 30

140,217

August 2021

September 30

140,217

November 2021

December 31

140,217

February 2022

2022

March 31

213,513

May 2022

June 30

213,513

August 2022

In addition to the distributions above, during the three months ended June 30, 2022, WES Operating made distributions of $86.7 million to the Partnership and WGRAH. The Partnership used its portion of the distribution to repurchase common units. See Note 5.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

~~4. PARTNERSHIP DISTRIBUTIONS~~

In addition to the distributions above, during the quarter ended September 30, 2021, WES Operating made a distribution of $91.8 million to the Partnership and WGRAH. The Partnership used its portion of the distribution to repurchase common units on the open market. See ~~Note 5~~.

5. EQUITY AND PARTNERS’ CAPITAL

Holdings of Partnership equity. The Partnership’s common units are listed on the New York Stock Exchange under the ticker symbol “WES.” As of ~~September~~June 30, ~~2021,~~2022, Occidental held ~~202,781,578~~200,281,578 common units, representing a ~~48.5%~~48.9% limited partner interest in the Partnership, and through its ownership of the general partner, Occidental indirectly held 9,060,641 general partner units, representing a 2.2% general partner interest in the Partnership. The public held ~~205,829,338~~199,966,763 common units, representing a ~~49.3%~~48.9% limited partner interest in the Partnership.

In March 2021, an affiliate of Occidental sold 11,500,000 of the Partnership’s common units it held ~~to the public~~ through an underwritten offering, including 1,500,000 common units pursuant to the full exercise of the underwriters’ over-allotment option. The Partnership did not receive any proceeds from the public offering.

~~On September 11, 2020, the Partnership assigned its 98% interest in the 30~~-year $260.0 million note established in May 2008 between WES Operating and Anadarko (the “Anadarko note receivable”) to Anadarko, which Anadarko canceled and retired immediately upon receipt, in exchange for which Occidental caused certain of its subsidiaries to transfer an aggregate of 27,855,398 common units representing limited partner interests in the Partnership to the Partnership. The units were canceled by the Partnership immediately upon receipt. See ~~Note 6.~~

Partnership equity repurchases. In ~~November 2020,~~February 2022, the Board ~~of Directors~~ authorized the Partnership to buy back up to ~~$250.0 million~~$1.0 billion of the Partnership’s common units through December 31, ~~2021~~2024 (the ~~“Purchase~~“$1.0 billion Purchase Program”). The common units may be purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions. During the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, the Partnership repurchased ~~5,586,419~~3,314,562 common units on the open market for an aggregate purchase price of ~~$104.4~~$79.2 million. From July 1, 2022, through July 29, 2022, the Partnership repurchased 13,800,805 common units, which includes 10,000,000 common units repurchased from Occidental, for an aggregate purchase price of $346.1 million. The units were canceled immediately upon receipt. As of July 29, 2022, Occidental held 190,281,578 common units and the public held 196,168,502 common units, representing a 48.1% and 49.6% limited partner interest in the Partnership, respectively. General partner units remained at 9,060,641, representing a 2.3% general partner interest in the Partnership. Inclusive of the unit repurchases through July 29, 2022, the Partnership had an authorized amount of $574.6 million remaining under the $1.0 billion Purchase Program.

In November 2020, the Board authorized the Partnership to buy back up to $250.0 million of the Partnership’s common units through December 31, 2021 (the “$250.0 million Purchase Program”). The common units were purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions. During the six months ended June 30, 2021, the Partnership repurchased 1,115,808 common units on the open market for an aggregate purchase price of $16.2 million. The units were canceled by the Partnership immediately upon receipt. As of ~~September 30,~~December 31, 2021, the ~~Partnership~~entire $250.0 million authorized program had ~~an authorized amount of $113.1 million remaining under the Purchase Program.~~been fulfilled.

Holdings of WES Operating equity. As of ~~September~~June 30, ~~2021,~~2022, (i) the Partnership, directly and indirectly through its ownership of WES Operating GP, owned a 98.0% limited partner interest and the entire non-economic general partner interest in WES Operating and (ii) Occidental, through its ownership of WGRAH, owned a 2.0% limited partner interest in WES Operating, which is reflected as a noncontrolling interest within the consolidated financial statements of the Partnership (see Note 1).

Partnership’s net income (loss) per common unit. The common and general partner unitholders’ allocation of net income (loss) attributable to the Partnership was equal to their cash distributions plus their respective allocations of undistributed earnings or losses in accordance with their weighted-average ownership percentage during each period using the two-class method.

The Partnership’s basic net income (loss) per common unit is calculated by dividing the limited partners’ interest in net income (loss) by the weighted-average number of common units outstanding during the period. Diluted net income (loss) per common unit includes the effect of outstanding units issued under the Partnership’s long-term incentive plans.

2421

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. EQUITY AND PARTNERS’ CAPITAL

The following table provides a reconciliation between basic and diluted net income (loss) per common unit:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands except per-unit amounts	thousands except per-unit amounts	2021		2020		2021		2020		thousands except per-unit amounts	2022		2021		2022		2021
Net income (loss)	Net income (loss)									Net income (loss)
Limited partners’ interest in net income (loss)	Limited partners’ interest in net income (loss)	$	250,198	$	241,479	$	658,291	$	257,659	Limited partners’ interest in net income (loss)	$	299,550	$	226,295	$	601,484	$	408,093
Weighted-average common units outstanding	Weighted-average common units outstanding									Weighted-average common units outstanding
Basic	Basic	411,909		438,857		412,690		442,255		Basic	403,027		413,070		403,140		413,087
Dilutive effect of non-vested phantom units	Dilutive effect of non-vested phantom units	805		69		460		20		Dilutive effect of non-vested phantom units	1,135		650		1,140		470
Diluted	Diluted	412,714		438,926		413,150		442,275		Diluted	404,162		413,720		404,280		413,557
Excluded due to anti-dilutive effect	Excluded due to anti-dilutive effect	4		1,084		700		1,271		Excluded due to anti-dilutive effect	618		240		731		333
Net income (loss) per common unit	Net income (loss) per common unit									Net income (loss) per common unit
Basic	Basic	$	0.61	$	0.55	$	1.60	$	0.58	Basic	$	0.74	$	0.55	$	1.49	$	0.99
Diluted	Diluted	$	0.61	$	0.55	$	1.59	$	0.58	Diluted	$	0.74	$	0.55	$	1.49	$	0.99

WES Operating’s net income (loss) per common unit. Net income (loss) per common unit for WES Operating is not calculated because it has no publicly traded units.

~~Table of Contents~~

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

6. RELATED-PARTY TRANSACTIONS

Summary of related-party transactions. The following tables summarize material related-party transactions included in the Partnership’s consolidated financial statements:


Consolidated statements of operations	Consolidated statements of operations									Consolidated statements of operations

		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands	thousands	2021		2020		2021		2020		thousands	2022		2021		2022		2021
Revenues and other	Revenues and other									Revenues and other
Service revenues – fee based	Service revenues – fee based	$	418,520	$	436,405	$	1,188,679	$	1,344,326	Service revenues – fee based	$	428,631	$	402,684	$	843,530	$	770,159
Service revenues – product based	Service revenues – product based	1,499		2,544		9,662		6,690		Service revenues – product based	21,808		3,658		24,051		8,163
Product sales	Product sales	11,662		16,692		27,034		60,452		Product sales	6,342		9,101		17,909		15,372
Total revenues and other	Total revenues and other	431,681		455,641		1,225,375		1,411,468		Total revenues and other	456,781		415,443		885,490		793,694
Equity income, net �� related parties (1)		48,506		61,026		159,337		176,788
Equity income, net – related parties (1)										Equity income, net – related parties (1)	48,464		58,666		98,071		110,831
Operating expenses	Operating expenses									Operating expenses
Cost of product		17,384		1,483		53,968		85,353
Cost of product (2)										Cost of product (2)	(12,148)		18,937		(31,691)		36,584
Operation and maintenance	Operation and maintenance	3,497		1,303		24,534		35,660		Operation and maintenance	702		2,915		643		21,037
General and administrative (2)		1,808		7,607		13,003		40,456
General and administrative (3)										General and administrative (3)	233		7,102		2,208		11,195
Total operating expenses	Total operating expenses	22,689		10,393		91,505		161,469		Total operating expenses	(11,213)		28,954		(28,840)		68,816

Interest income – Anadarko note receivable		—		3,286		—		11,736

(1)See Note 7.

(2)Includes related-party natural-gas and NGLs imbalances.

(3)Includes (i) amounts charged by Occidental pursuant to the shared services agreement (see Services Agreement within this Note 6) and (ii) equity-based compensation expense allocated to the Partnership by Occidental, which is not reimbursed to Occidental and is reflected as a contribution to partners’ capital in the consolidated statements of equity and partners’ capital (see Incentive Plans within this Note 6).

Consolidated balance sheets
thousands September 30,
2021 December 31,
2020
Assets
Accounts receivable, net $ 289,402 $ 291,253
Other current assets 29,021 5,493
Equity investments (1)
1,181,181 1,224,813
Other assets 76,560 50,967
Total assets 1,576,164 1,572,526
Liabilities
Accounts and imbalance payables 42,384 6,664
Accrued liabilities 19,232 19,195
Other liabilities 189,119 138,796
Total liabilities 250,735 164,655

~~(1)See~~ ~~Note 7~~.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. RELATED-PARTY TRANSACTIONS

Consolidated statements of cash flows
Nine Months Ended
September 30,
thousands 2021 2020
Distributions from equity-investment earnings – related parties
$ 164,772 $ 187,816
Purchases from related parties (2,000) —
Contributions to equity investments – related parties (3,683) (19,017)
Distributions from equity investments in excess of cumulative earnings – related parties 30,075 21,750
Distributions to Partnership unitholders (1)
(195,205) (301,219)
Distributions to WES Operating unitholders (2)
(9,934) (11,545)
Net contributions from (distributions to) related parties 6,673 22,674
Finance lease payments — (6,382)





Consolidated balance sheets
thousands	June 30, 2022		December 31, 2021
Assets
Accounts receivable, net	$	322,715	$	180,205
Other current assets	14,591		12,490

Equity investments (1)	1,148,487		1,167,187
Other assets	45,921		45,494
Total assets	1,531,714		1,405,376
Liabilities
Accounts and imbalance payables	47,175		49,242

Accrued liabilities	4,136		13,914
Other liabilities	237,008		207,365
Total liabilities	288,319		270,521

(1)See Note 7.


Consolidated statements of cash flows

	Six Months Ended June 30,
thousands	2022		2021
Distributions from equity-investment earnings – related parties	$	96,404	$	110,763
Capital expenditures	—		(2,000)

Contributions to equity investments – related parties	(5,040)		(3,508)
Distributions from equity investments in excess of cumulative earnings – related parties	25,407		21,373
Distributions to Partnership unitholders (1)	(165,633)		(130,518)
Distributions to WES Operating unitholders (2)	(8,812)		(5,292)
Net contributions from (distributions to) related parties	784		4,508

(1)Represents distributions paid to Occidental pursuant to the partnership agreement of the Partnership (see Note 4 and Note 5).

(2)Represents distributions paid to ~~a certain subsidiary~~Occidental, through its ownership of ~~Occidental~~WGRAH, pursuant to WES Operating’s partnership agreement (see Note 4 and Note 5).

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. RELATED-PARTY TRANSACTIONS

The following tables summarize material related-party transactions for WES Operating (which are included in the Partnership’s consolidated financial statements) to the extent the amounts differ materially from the Partnership’s consolidated financial statements:


Consolidated statements of operations	Consolidated statements of operations									Consolidated statements of operations

		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands	thousands	2021		2020		2021		2020		thousands	2022		2021		2022		2021
General and administrative (1)	General and administrative (1)	$	2,775	$	8,314	$	15,061	$	41,220	General and administrative (1)	$	919	$	7,699	$	3,867	$	12,286

(1)Includes (i) amounts charged by Occidental pursuant to the shared services agreement (see Services Agreement within this Note 6), (ii) equity-based compensation expense allocated to WES Operating by Occidental, which is not reimbursed to Occidental and is reflected as a contribution to partners’ capital in the consolidated statements of equity and partners’ capital (see Incentive Plans within this Note 6), and (iii) an intercompany service fee between the Partnership and WES Operating.


Consolidated balance sheets	Consolidated balance sheets					Consolidated balance sheets
thousands	thousands	September 30, 2021		December 31, 2020		thousands	June 30, 2022		December 31, 2021
Accounts receivable, net		$	289,402	$	246,083

Other current assets						Other current assets	$	14,475	$	12,490
Other assets						Other assets	45,235		45,494
Accounts and imbalance payables (1)	Accounts and imbalance payables (1)	83,576		6,664		Accounts and imbalance payables (1)	73,392		97,749
Accrued liabilities						Accrued liabilities	3,819		13,597

(1)~~As of September 30, 2021, includes~~Includes balances related to transactions between the Partnership and WES Operating.


Consolidated statements of cash flows	Consolidated statements of cash flows						Consolidated statements of cash flows

		Nine Months Ended September 30,						Six Months Ended June 30,
thousands	thousands		2021		2020		thousands		2022		2021

Distributions to WES Operating unitholders (1)	Distributions to WES Operating unitholders (1)		$	(496,555)	$	(577,122)	Distributions to WES Operating unitholders (1)		$	(440,465)	$	(264,500)

(1)Represents distributions paid to the Partnership and ~~a certain subsidiary~~Occidental, through its ownership of ~~Occidental~~WGRAH, pursuant to WES Operating’s partnership agreement. ~~Includes a distribution made from WES Operating to the Partnership during the quarter ended September 30, 2021, that was used by the Partnership to repurchase common units on the open market.~~ See Note 4 and Note 5.

~~Table of Contents~~

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~6. RELATED-PARTY TRANSACTIONS~~

Related-party revenues. Related-party revenues include ~~(i)~~ amounts earned by the Partnership from services provided to Occidental and from the sale of natural gas, condensate, and NGLs to ~~Occidental and (ii) income from the Partnership’s investments accounted for under the equity method of accounting (see~~ ~~Note 7~~).Occidental.

Gathering and processing agreements. The Partnership has significant gathering, processing, and ~~processing~~produced-water disposal arrangements with affiliates of Occidental on most of its systems. While Occidental is the contracting counterparty of the Partnership, these arrangements with Occidental include not just Occidental-produced volumes, but also, in some instances, the volumes of other working-interest owners of Occidental who rely on the Partnership’s facilities and infrastructure to bring their volumes to market. Natural-gas throughput (excluding equity-investment throughput) attributable to production owned or controlled by Occidental was ~~38%~~35% and 36% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~41%~~36% and ~~42%~~35% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively. Crude-oil and NGLs throughput (excluding equity-investment throughput) attributable to production owned or controlled by Occidental was 88% and 89% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~87%~~90% and ~~88%~~89% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively. Produced-water throughput attributable to production owned or controlled by Occidental was ~~89%~~81% and ~~87%~~82% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~87% and 88%~~86% for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020, respectively.~~2021.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. RELATED-PARTY TRANSACTIONS

The Partnership is currently involved in a dispute with Occidental regarding the calculation of the cost-of-service rates under an oil-gathering contract related to the Partnership’s DJ Basin oil-gathering system. If such dispute is resolved in a manner adverse to the Partnership, such resolution could have a negative impact on the Partnership’s financial condition and results of operations, including a reduction in rates and a non-cash charge to earnings.

In connection with the sale of its Eagle Ford assets in 2017, Anadarko remained the primary counterparty to the Partnership’s Brasada gas processing agreement and entered into an agency relationship with Sanchez Energy Corporation (“Sanchez”), now Mesquite Energy, Inc. (“Mesquite”), that allows Mesquite to process gas under such agreement. In December 2021, the Brasada gas processing agreement was assigned from Anadarko to Mesquite effective July 1, 2023. For this reason, Anadarko continues to be liable under the Brasada gas processing agreement ~~through 2034~~until June 30, 2023, to the extent Mesquite does not perform. For all periods presented, Mesquite has performed Anadarko’s obligations under the Brasada gas processing agreement pursuant to its agency arrangement with Anadarko.

Further, in connection with the sale of its Uinta Basin assets in 2020, Kerr McGee Oil & Gas Onshore LP, a subsidiary of Occidental, retained the deficiency payment obligations under a gas processing agreement at the Chipeta plant. This contingent payment obligation extends through the earlier of October 1, 2022, or the termination of the processing agreement.

~~Commodity purchase and sale agreements.~~ Through December 31, 2020, the Partnership purchased and sold a significant amount of natural gas and NGLs from and to Anadarko Energy Services Company (“AESC”), a marketing affiliate of Occidental. Prior to April 1, 2020, AESC acted as an agent on behalf of either the Partnership or the Partnership’s customers for third-party sales. Where AESC sold natural gas and NGLs on the Partnership’s customers’ behalf, the Partnership recognized associated service revenues and cost of product expense for the marketing services performed by AESC. When product sales were on the Partnership’s behalf, the Partnership recognized product sales revenues based on Occidental’s sales price to the third party and recorded the associated cost of product expense associated with the marketing activities provided by AESC. Effective April 1, 2020, changes to marketing-~~contract terms with AESC terminated AESC’s prior status as an agent of the Partnership for third~~-party sales and established AESC as a customer of the Partnership. Accordingly, the Partnership no longer recognizes service revenues and/or product sales revenues and the equivalent cost of product expense for the marketing services performed by AESC. This change has no impact to Operating income (loss), Net income (loss), the balance sheets, cash flows, or any non-~~GAAP metric used to evaluate the Partnership’s operations (see~~ ~~Key Performance Metrics~~ ~~under Part I, Item 2 of this Form 10-Q).~~

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~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~6. RELATED-PARTY TRANSACTIONS~~

Marketing Transition Services Agreement. Effective December 31, 2019, certain subsidiaries of Anadarko entered into a transition services agreement (the “Marketing Transition Services Agreement”) to provide marketing-related services to certain of the Partnership’s subsidiaries through December 31, 2020, subject to the option to extend such services for an additional six-month period. The Marketing Transition Services Agreement was terminated on December 31, 2020. While the Partnership still has some marketing agreements with affiliates of Occidental, the Partnership began marketing and selling substantially all of its natural gas and NGLs directly to third parties beginning on January 1, 2021.

Operating leases. As a result of the surface-use and salt-water disposal agreements being amended under the CUA (see Related-party ~~Commercial Agreement~~commercial agreement below), these agreements are now classified as operating leases and a $30.0 million right-of-use (“ROU”) asset, included in Other assets on the consolidated balance sheets, was recognized during the first quarter of 2021. The ROU asset ~~will be~~is being amortized to Operation and maintenance expense over the remaining term of the agreements.

Effective December 31, 2019, an affiliate of Occidental and a wholly owned subsidiary of the Partnership, the lessor, entered into an operating and maintenance agreement pursuant to which Occidental ~~provides~~provided operational and maintenance services with respect to a crude-oil gathering system and associated treating facilities owned by the Partnership through December 31, 2021. The agreement and underlying contracts ~~include~~included (i) fixed consideration, which iswas measured as the minimum-volume commitment for both gathering and treating, and (ii) variable consideration, which ~~consists~~consisted of all volumes above the minimum-volume commitment. ~~Subsequent to the initial two~~-~~year term, the agreement provides for automatic one~~-~~year extensions, unless either party exercises its option to terminate the lease with advance notice.~~ In April 2021, the Partnership exercised its option to terminate the operating and maintenance agreement with Occidental effective December 31, 2021. For the three and ~~nine~~six months ended ~~September~~June 30, 2021, ~~the Partnership recognized fixed~~-~~lease revenue of $43.9 million and $131.9 million, respectively, and variable~~-~~lease revenue of $0.6 million and $1.9 million, respectively, related to these agreements. For the three and nine months ended September 30, 2020,~~ the Partnership recognized fixed-lease revenue of $44.0 million and ~~$131.8~~$87.9 million, respectively, and variable-lease revenue of ~~$9.8~~$2.4 million and ~~$42.6~~$1.3 million, respectively, related to these agreements, with such amounts included in Service revenues – fee based in the consolidated statements of operations.

Related-party expenses. Operation and maintenance expense includes amounts accrued for or paid to related parties for field-related costs provided by related parties at certain of the Partnership’s assets. A portion of general and administrative expense is paid by Occidental, which results in related-party transactions pursuant to the reimbursement provisions of the Partnership’s and WES Operating’s agreements with Occidental. Cost of product expense includes amounts related to certain continuing marketing arrangements with affiliates of Occidental, related-party imbalances, and transactions with affiliates accounted for under the equity method of accounting. See~~Commodity purchase and sale agreements~~ ~~and~~ Marketing Transition Services Agreement in the sections above. Related-party expenses do not bear a direct relationship to related-party revenues, and third-party expenses do not bear a direct relationship to third-party revenues.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. RELATED-PARTY TRANSACTIONS

Services Agreement. General and administrative expense includes costs incurred pursuant to the agreement dated as of December 31, 2019, by and among Occidental, Anadarko, and WES Operating GP, under which Occidental has performed certain centralized corporate functions for the Partnership and WES Operating (“Services Agreement”).

Pursuant to the Services Agreement, which was amended and restated on December 31, 2019, specified employees of Occidental were seconded to WES Operating GP to provide, under the direction, supervision, and control Most of the general partner, (i) operating and routine maintenance service and (ii) corporate, administrative, and other services, with respect to the assets owned and operated by the Partnership. Occidental was reimbursed for the services provided by the seconded employees. In January 2020, pursuant to the Services Agreement, Occidental made a one-~~time cash contribution of $20.0 million to WES Operating for anticipated transition costs required to establish stand~~-~~alone human resources and information technology functions. In late March 2020, seconded employees’ employment was transferred to the Partnership. Occidental continues to provide certain limited~~ administrative and operational services ~~to the Partnership, with most services expected to be~~previously provided by Occidental fully transitioned to the Partnership by December 31, ~~2021.~~

~~Table~~2021, with certain limited transition services remaining in place pursuant to the terms of ~~Contents~~the Services Agreement.

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~6. RELATED-PARTY TRANSACTIONS~~

Incentive Plans. General and administrative expense includes non-cash equity-based compensation expense allocated to the Partnership by Occidental for awards granted to the executive officers of the general partner and to other employees prior to their employment with the Partnership under (i) the Anadarko Petroleum Corporation 2012 Omnibus Incentive Compensation Plan, as amended and restated, (ii) Occidental’s 2015 Long-Term Incentive Plan, and (iii) Occidental’s Phantom Share Unit Award Plan (collectively referred to as the “Incentive Plans”). General and administrative expense includes ~~allocated expense~~costs related to the Incentive Plans of ~~$2.3~~$0.2 million and ~~$7.9~~$2.2 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, and ~~$3.5~~$2.4 million and ~~$11.2~~$5.6 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2020,~~2021, respectively. These amounts are reflected as contributions to partners’ capital in the consolidated statements of equity and partners’ capital.

Construction reimbursement agreements and ~~Purchases~~purchases from related parties. From time to time, the Partnership enters into construction reimbursement agreements with Occidental providing that the Partnership will manage the construction of certain midstream infrastructure for Occidental in the Partnership’s areas of operation. Such arrangements generally provide for a reimbursement of costs incurred by the Partnership on a cost or cost-plus basis.

Additionally, from time to time, in support of the Partnership’s business, the Partnership purchases equipment, inventory, and other miscellaneous assets from Occidental or its affiliates. ~~These amounts are included in Purchases from related parties in the consolidated statements of cash flows.~~

Related-party commercial agreement. During the first quarter of 2021, an affiliate of Occidental and certain wholly owned subsidiaries of the Partnership entered into a Commercial Understanding Agreement (“CUA”). Under the CUA, certain West Texas surface-use and salt-water disposal agreements were amended to reduce usage fees owed by the Partnership in exchange for the forgiveness of certain deficiency fees owed by Occidental and other unrelated contractual amendments. The present value of the reduced usage fees under the CUA was $30.0 million at the time the agreement was executed.

~~Anadarko note receivable.~~ ~~In May 2008, WES Operating loaned $260.0 million to Anadarko in exchange for a 30~~-year note that bore interest at a fixed annual rate and was classified as interest income in the consolidated statements of operations. On September 11, 2020, the Partnership and Occidental entered into a Unit Redemption Agreement, pursuant to which WES Operating transferred the note receivable to Anadarko, which Anadarko immediately canceled and retired upon receipt.

Customer concentration. Occidental was the only customer from which revenues exceeded 10% of consolidated revenues for all periods presented in the consolidated statements of operations.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

7. EQUITY INVESTMENTS

The following table presents the financial statement impact of the Partnership’s equity investments for the ~~nine~~six months ended ~~September~~June 30, ~~2021:~~2022:


thousands	thousands	Balance at December 31, 2020		Other-than-temporary impairment expense (1)		Equity income, net		Contributions		Distributions		Distributions in excess of cumulative earnings (2)		Balance at September 30, 2021		thousands	Balance at December 31, 2021		Equity income, net		Contributions		Distributions		Distributions in excess of cumulative earnings (1)		Balance at June 30, 2022
White Cliffs	White Cliffs	$	45,623	$	—	$	701	$	—	$	(266)	$	(4,583)	$	41,475	White Cliffs	$	40,753	$	438	$	—	$	(147)	$	(1,773)	$	39,271
Rendezvous	Rendezvous	28,198		—		(1,560)		—		(884)		(2,058)		23,696		Rendezvous	22,075		(1,304)		—		(326)		(1,063)		19,382
Mont Belvieu JV	Mont Belvieu JV	98,874		—		25,066		—		(25,095)		(2,193)		96,652		Mont Belvieu JV	96,728		14,500		—		(14,605)		(3,288)		93,335
TEG	TEG	16,661		—		3,390		—		(3,409)		(299)		16,343		TEG	16,116		3,111		—		(3,004)		—		16,223
TEP	TEP	195,189		—		27,572		—		(27,623)		(4,491)		190,647		TEP	188,925		21,552		—		(21,678)		(1,457)		187,342
FRP	FRP	199,881		—		28,351		—		(28,482)		(4,004)		195,746		FRP	196,632		21,318		—		(21,584)		(2,195)		194,171
Whitethorn LLC	Whitethorn LLC	156,729		—		6,380		347		(5,736)		(4,018)		153,702		Whitethorn LLC	149,690		63		255		2,950		(1,565)		151,393
Cactus II	Cactus II	173,921		—		14,290		3,336		(14,415)		(3,926)		173,206		Cactus II	171,294		7,265		—		(7,349)		(6,563)		164,647
Saddlehorn	Saddlehorn	111,717		—		26,045		—		(26,157)		—		111,605		Saddlehorn	110,441		11,169		—		(10,934)		(815)		109,861
Panola	Panola	20,867		—		1,629		—		(1,628)		(555)		20,313		Panola	20,044		1,052		—		(1,052)		(864)		19,180
Mi Vida	Mi Vida	55,031		—		7,445		—		(7,334)		(2,245)		52,897		Mi Vida	51,763		7,156		—		(7,209)		(3,104)		48,606
Ranch Westex	Ranch Westex	18,898		(11,805)		9,267		—		(12,517)		(1,624)		2,219		Ranch Westex	979		4,688		—		(4,688)		(2,083)		(1,104)
Red Bluff Express	Red Bluff Express	103,224		—		10,761		—		(11,226)		(79)		102,680		Red Bluff Express	101,747		7,063		4,785		(6,778)		(637)		106,180
Total	Total	$	1,224,813	$	(11,805)	$	159,337	$	3,683	$	(164,772)	$	(30,075)	$	1,181,181	Total	$	1,167,187	$	98,071	$	5,040	$	(96,404)	$	(25,407)	$	1,148,487

(1)~~Recorded in Long-lived asset and other impairments in the consolidated statements of operations.~~

~~(2)~~Distributions in excess of cumulative earnings, classified as investing cash flows in the consolidated statements of cash flows, are calculated on an individual-investment basis.

~~The investment balance in Ranch Westex at September 30, 2021, was $37.1 million less than the Partnership’s underlying equity in Ranch Westex’s net assets.~~ During the ~~nine~~six months ended ~~September~~June 30, 2021, the Partnership recognized an impairment loss on its investment in Ranch Westex of ~~$11.8~~$11.6 million that resulted from a decline in value below the carrying value, which was determined to be other than temporary in nature. This investment was impaired to its estimated fair value of $2.9 million, using the income approach and Level-3 fair value inputs, due to a reduction in estimated future cash flows resulting from lower forecasted producer throughput.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

8. PROPERTY, PLANT, AND EQUIPMENT

A summary of the historical cost of property, plant, and equipment is as follows:


thousands	thousands	Estimated Useful Life	September 30, 2021		December 31, 2020		thousands	Estimated Useful Life	June 30, 2022		December 31, 2021
Land	Land	N/A	$	10,955	$	9,696	Land	N/A	$	10,955	$	10,955
Gathering systems – pipelines	Gathering systems – pipelines	30 years	5,343,971		5,231,212		Gathering systems – pipelines	30 years	5,452,285		5,386,003
Gathering systems – compressors	Gathering systems – compressors	15 years	2,111,639		2,096,905		Gathering systems – compressors	15 years	2,241,600		2,172,953
Processing complexes and treating facilities	Processing complexes and treating facilities	25 years	3,367,933		3,424,368		Processing complexes and treating facilities	25 years	3,386,213		3,375,317
Transportation pipeline and equipment	Transportation pipeline and equipment	6 to 45 years	168,384		168,205		Transportation pipeline and equipment	6 to 45 years	169,365		169,356
Produced-water disposal systems	Produced-water disposal systems	20 years	879,916		831,719		Produced-water disposal systems	20 years	890,723		882,527
Assets under construction	Assets under construction	N/A	123,115		176,834		Assets under construction	N/A	137,600		98,473
Other	Other	3 to 40 years	727,013		702,806		Other	3 to 40 years	769,948		750,494
Total property, plant, and equipment	Total property, plant, and equipment		12,732,926		12,641,745		Total property, plant, and equipment		13,058,689		12,846,078
Less accumulated depreciation	Less accumulated depreciation		4,208,845		3,931,800		Less accumulated depreciation		4,581,122		4,333,171
Net property, plant, and equipment	Net property, plant, and equipment		$	8,524,081	$	8,709,945	Net property, plant, and equipment		$	8,477,567	$	8,512,907

The cost of property classified as “Assets under construction” is excluded from capitalized costs being depreciated. These amounts represent property that is not yet placed into productive service as of the respective balance sheet date.

Long-lived asset and other impairments. During the ~~nine~~six months ended ~~September~~June 30, 2021, the Partnership recognized impairments of ~~$29.2~~$27.6 million, primarily attributable to (i) ~~$14.1~~$14.0 million of impairments at the DJ Basin complex due to cancellation of projects and (ii) an ~~$11.8~~$11.6 million other-than-temporary impairment of the Partnership’s investment in Ranch Westex (see Note 7).

During the nine months ended September 30, 2020, the Partnership recognized impairments of $200.6 million, primarily due to $150.2 million of impairments for assets located in Wyoming and Utah. These assets were impaired to estimated fair values of $112.2 million. The Partnership assesses whether events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. The fair value of assets with impairment triggers were measured using the income approach and Level-3 fair value inputs. The income approach was based on the Partnership’s projected future earnings before interest, taxes, depreciation, and amortization (“EBITDA”) and free cash flows, which requires significant assumptions including, among others, future throughput volumes based on current expectations of producer activity and operating costs. These impairments were primarily triggered by reductions in estimated future cash flows resulting from lower forecasted producer throughput and lower commodity prices. The remaining impairments of $21.0 million were primarily at the DJ Basin complex and DBM water systems due to cancellation of projects and impairments of rights-of-way. Long-lived asset and other impairments on the consolidated statements of operations also includes a $29.4 million other-than-temporary impairment for the nine months ended September 30, 2020, of the Partnership’s investment in Ranch Westex.

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(UNAUDITED)

~~8. PROPERTY, PLANT, AND EQUIPMENT~~9. SELECTED COMPONENTS OF WORKING CAPITAL

~~Potential future long-lived asset impairments.~~ AsA summary of ~~September 30, 2021, it~~accounts receivable, net is ~~reasonably possible that future commodity~~-~~price declines, prolonged depression of commodity prices, changes to producers’ drilling plans in response to lower prices, and potential producer bankruptcies could result in future long~~-lived asset impairments. For example, on April 29, 2020, the Partnership received notice that Sanchez, in its bankruptcy, was seeking to reject a number of midstream and downstream agreements with commercial counterparties, including Sanchez’s Springfield gathering agreements and agreements obligating Sanchez to deliver the gas volumes gathered by the Springfield system to our Brasada processing plant. On May 6, 2021, the Bankruptcy Court issued an opinion determining, among other things, that Sanchez’s Springfield gathering agreements were rejected, but that such agreements contain covenants running with the land that survive rejection, thus preserving the acreage dedication to the Partnership’s Springfield system. Depending on the ultimate outcome of the Partnership’s continuing efforts to defend its contractual rights in the bankruptcy proceeding, as ~~well as the Partnership’s ongoing commercial discussions, the Partnership’s South Texas assets could be impaired.~~follows:


	The Partnership				WES Operating


thousands	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Trade receivables, net	$	710,315	$	431,649	$	710,315	$	431,649
Other receivables, net	6,028		4,864		6,028		4,864
Total accounts receivable, net	$	716,343	$	436,513	$	716,343	$	436,513

A summary of other current assets is as follows:

~~9. GOODWILL~~


	The Partnership				WES Operating


thousands	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
NGLs inventory	$	1,514	$	3,370	$	1,514	$	3,370
Imbalance receivables	25,894		25,309		25,894		25,309
Prepaid insurance	1,550		10,369		276		8,538
Contract assets	16,512		5,307		16,512		5,307
Other	4,196		1,897		4,080		1,897
Total other current assets	$	49,666	$	46,252	$	48,276	$	44,421

~~Goodwill~~A summary of accrued liabilities is recorded when the purchase price of a business acquired exceeds the fair market value of the tangible and separately measurable intangible net assets. Goodwill also includes the allocated historic carrying value of midstream goodwill attributed to the Partnership’s assets previously acquired from Anadarko. The Partnership’s goodwill has been allocated to 2 reporting units: (i) gathering and processing and (ii) transportation.as follows:


	The Partnership				WES Operating


thousands	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Accrued interest expense	$	112,028	$	131,177	$	112,028	$	131,177
Short-term asset retirement obligations	9,541		9,934		9,541		9,934
Short-term remediation and reclamation obligations	7,147		7,454		7,147		7,454
Income taxes payable	2,892		1,516		2,892		1,516
Contract liabilities	9,142		27,763		9,142		27,763
Accrued payroll and benefits	34,072		41,311		—		20
Other	42,995		44,094		38,493		32,829
Total accrued liabilities	$	217,817	$	263,249	$	179,243	$	210,693

~~The Partnership evaluates goodwill for impairment at the reporting~~-unit level on an annual basis, as of October 1, or more often as facts and circumstances warrant. An initial qualitative assessment is performed to determine the likelihood of whether goodwill is impaired and if deemed necessary based on this assessment, a quantitative assessment is then performed. If the quantitative assessment indicates that the carrying value of the reporting unit, including goodwill, exceeds its fair value, a goodwill impairment is recorded for the amount by which the reporting unit’s carrying value exceeds its fair value.

During the three months ended March 31, 2020, the Partnership performed an interim goodwill impairment test due to a significant decline in the trading price of the Partnership’s common units, triggered by the combined impacts from the global outbreak of COVID-~~19 and the oil~~-~~market disruption resulting from significantly lower global demand and corresponding oversupply of crude oil. The Partnership primarily used the market approach and Level~~-3 inputs to estimate the fair value of its two reporting units. The market approach was based on multiples of EBITDA and the Partnership’s projected future EBITDA. The EBITDA multiples were based on current and historic multiples for comparable midstream companies of similar size and business profit to the Partnership. The EBITDA projections require significant assumptions including, among others, future throughput volumes based on current expectations of producer activity and operating costs. The reasonableness of the market approach was tested against an income approach that was based on a discounted cash-~~flow analysis. Key assumptions in this analysis include the use of an appropriate discount rate, terminal~~-year multiples, and estimated future cash flows, including estimates of throughput, capital expenditures, operating, and general and administrative costs. The Partnership also reviewed the reasonableness of the total fair value of both reporting units to the market capitalization as of March 31, 2020, and the reasonableness of an implied acquisition premium. Impairment determinations involve significant assumptions and judgments, and differing assumptions regarding any of these inputs could have a significant effect on the valuations. As a result of the interim impairment test, the Partnership recognized a goodwill impairment of $441.0 million during the first quarter of 2020, which reduced the carrying value of goodwill for the gathering and processing reporting unit to zero. Goodwill allocated to the transportation reporting unit of $4.8 million as of March 31, 2020, was not impaired. Recurring goodwill impairment assessments have indicated no further impairment.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

10. ~~SELECTED COMPONENTS OF WORKING CAPITAL~~

~~A summary of accounts receivable, net is as follows:~~

The Partnership WES Operating
thousands September 30,
2021 December 31,
2020 September 30,
2021 December 31,
2020
Trade receivables, net $ 583,646 $ 452,718 $ 583,646 $ 407,547
Other receivables, net 6 162 6 2
Total accounts receivable, net $ 583,652 $ 452,880 $ 583,652 $ 407,549

~~A summary of other current assets is as follows:~~

The Partnership WES Operating
thousands September 30,
2021 December 31,
2020 September 30,
2021 December 31,
2020
NGLs inventory $ 4,002 $ 882 $ 4,002 $ 882
Imbalance receivables 14,958 12,976 14,958 12,976
Prepaid insurance 14,425 8,131 12,136 6,113
Contract assets 23,766 5,338 23,766 5,338
Other 16,045 17,935 16,045 17,935
Total other current assets $ 73,196 $ 45,262 $ 70,907 $ 43,244

~~A summary of accrued liabilities is as follows:~~

The Partnership WES Operating
thousands September 30,
2021 December 31,
2020 September 30,
2021 December 31,
2020
Accrued interest expense $ 69,570 $ 137,307 $ 69,570 $ 137,307
Short-term asset retirement obligations
14,365 20,215 14,365 20,215
Short-term remediation and reclamation obligations
6,101 2,950 6,101 2,950
Income taxes payable 4,593 3,399 4,593 3,399
Contract liabilities 22,854 31,477 22,854 31,477
Other 73,145 74,599 27,758 35,485
Total accrued liabilities $ 190,628 $ 269,947 $ 145,241 $ 230,833

~~Table of Contents~~

~~WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP~~

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~11.~~ DEBT AND INTEREST EXPENSE

WES Operating is the borrower for all outstanding debt and is expected to be the borrower for all future debt issuances. The following table presents the outstanding debt:


		September 30, 2021						December 31, 2020							June 30, 2022						December 31, 2021
thousands	thousands	Principal		Carrying Value		Fair Value (1)		Principal		Carrying Value		Fair Value (1)		thousands	Principal		Carrying Value		Fair Value (1)		Principal		Carrying Value		Fair Value (1)
Short-term debt	Short-term debt													Short-term debt
4.000% Senior Notes due 2022	4.000% Senior Notes due 2022	$	502,246	$	502,086	$	510,243	$	—	$	—	$	—	4.000% Senior Notes due 2022	$	—	$	—	$	—	$	502,246	$	502,138	$	505,153
5.375% Senior Notes due 2021		—		—		—		431,081		430,606		436,241
RCF		220,000		220,000		220,000		—		—		—

Finance lease liabilities	Finance lease liabilities	4,343		4,343		4,343		8,264		8,264		8,264		Finance lease liabilities	2,613		2,613		2,613		3,794		3,794		3,794
Total short-term debt	Total short-term debt	$	726,589	$	726,429	$	734,586	$	439,345	$	438,870	$	444,505	Total short-term debt	$	2,613	$	2,613	$	2,613	$	506,040	$	505,932	$	508,947

Long-term debt	Long-term debt													Long-term debt
4.000% Senior Notes due 2022		$	—	$	—	$	—	$	580,917	$	580,555	$	597,568
Floating-Rate Senior Notes due 2023	Floating-Rate Senior Notes due 2023	213,138		212,521		212,773		239,978		238,879		235,066		Floating-Rate Senior Notes due 2023	$	213,138	$	212,879	$	212,387	$	213,138	$	212,642	$	213,072
3.100% Senior Notes due 2025	3.100% Senior Notes due 2025	732,106		727,794		774,328		1,000,000		992,900		1,028,614		3.100% Senior Notes due 2025	730,706		727,322		679,964		732,106		728,096		764,815
3.950% Senior Notes due 2025	3.950% Senior Notes due 2025	399,163		395,708		421,970		500,000		494,866		512,807		3.950% Senior Notes due 2025	399,163		396,372		377,181		399,163		395,928		418,506
4.650% Senior Notes due 2026	4.650% Senior Notes due 2026	474,242		471,500		513,758		500,000		496,708		524,880		4.650% Senior Notes due 2026	474,242		471,892		446,852		474,242		471,629		516,473
4.500% Senior Notes due 2028	4.500% Senior Notes due 2028	400,000		396,010		433,214		400,000		395,617		415,454		4.500% Senior Notes due 2028	400,000		396,418		362,556		400,000		396,145		437,673
4.750% Senior Notes due 2028	4.750% Senior Notes due 2028	400,000		396,840		437,005		400,000		396,555		418,786		4.750% Senior Notes due 2028	400,000		397,137		366,112		400,000		396,938		444,550
4.050% Senior Notes due 2030	4.050% Senior Notes due 2030	1,200,000		1,190,102		1,324,159		1,200,000		1,189,407		1,342,996		4.050% Senior Notes due 2030	1,200,000		1,190,835		1,043,296		1,200,000		1,190,339		1,323,595
5.450% Senior Notes due 2044	5.450% Senior Notes due 2044	600,000		593,699		691,067		600,000		593,598		607,234		5.450% Senior Notes due 2044	600,000		593,806		499,525		600,000		593,733		717,804
5.300% Senior Notes due 2048	5.300% Senior Notes due 2048	700,000		687,210		807,613		700,000		687,048		694,172		5.300% Senior Notes due 2048	700,000		687,378		566,236		700,000		687,265		844,223
5.500% Senior Notes due 2048	5.500% Senior Notes due 2048	350,000		342,629		409,945		350,000		342,543		343,928		5.500% Senior Notes due 2048	350,000		342,720		288,601		350,000		342,659		418,907
5.250% Senior Notes due 2050	5.250% Senior Notes due 2050	1,000,000		983,659		1,176,283		1,000,000		983,512		1,100,375		5.250% Senior Notes due 2050	1,000,000		983,824		809,805		1,000,000		983,709		1,183,514
RCF														RCF	255,000		255,000		255,000		—		—		—
Finance lease liabilities	Finance lease liabilities	2,202		2,202		2,202		23,644		23,644		23,644		Finance lease liabilities	540		540		540		1,533		1,533		1,533
Total long-term debt	Total long-term debt	$	6,470,851	$	6,399,874	$	7,204,317	$	7,494,539	$	7,415,832	$	7,845,524	Total long-term debt	$	6,722,789	$	6,656,123	$	5,908,055	$	6,470,182	$	6,400,616	$	7,284,665

(1)Fair value is measured using the market approach and Level-2 fair value inputs.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

~~11.~~10. DEBT AND INTEREST EXPENSE

Debt activity. The following table presents the debt activity for the ~~nine~~six months ended ~~September~~June 30, ~~2021:~~2022:


thousands	Carrying Value













Balance at December 31, ~~2020~~2021	$	~~7,854,702~~6,906,548
RCF borrowings	~~400,000~~635,000
Repayments of RCF borrowings	~~(180,000)~~(380,000)
~~Repayment of 5.375% Senior Notes due 2021~~	~~(431,081)~~
Repayment of 4.000% Senior Notes due 2022	~~(78,671)~~(502,246)
~~Repayment of Floating-Rate Senior Notes due 2023~~	~~(26,840)~~
Repayment of 3.100% Senior Notes due 2025	~~(267,894)~~(1,400)
~~Repayment of 3.950% Senior Notes due 2025~~	~~(100,837)~~
~~Repayment of 4.650% Senior Notes due 2026~~	~~(25,758)~~
Finance lease liabilities	~~(25,364)~~(2,172)
Other	~~8,046~~3,006
Balance at ~~September~~June 30, ~~2021~~2022	$	~~7,126,303~~6,658,736

WES Operating Senior Notes. In mid-January 2020, WES Operating issued the Fixed-Rate 3.100% Senior Notes due 2025, 4.050% Senior Notes due 2030, and 5.250% Senior Notes due 2050 (collectively referred to as the “Fixed-Rate Senior Notes”) and the Floating-Rate Senior Notes due 2023 (the “Floating-Rate Senior Notes”). Including the effects of the issuance prices, underwriting discounts, and interest-rate adjustments, the effective interest rates of the Senior Notes due 2025, 2030, and 2050, were 3.790%, 4.671%, and 5.869%, respectively, at June 30, 2022, and were 4.542%, 5.424%, and 6.629%, respectively, at ~~September~~June 30, ~~2021, and were 4.291%, 5.173%, and 6.375%, respectively, at September 30, 2020.~~2021. The interest rate on the Floating-Rate Senior Notes was ~~2.23%~~2.12% and ~~2.12%~~2.29% at ~~September~~June 30, ~~2021~~2022 and ~~2020,~~2021, respectively. The effective interest rate of these notes is subject to adjustment from time to time due to a change in credit rating.

During the ~~third~~second quarter of ~~2021,~~2022, WES Operating (i) redeemed the total principal amount outstanding of the 4.000% Senior Notes due 2022 at par value and (ii) purchased and retired ~~$500.0~~$1.4 million of ~~certain of its senior notes~~the 3.100% Senior Notes due 2025 via ~~a tender offer (see~~ ~~Debt activity~~ ~~above). For the three months ended September 30, 2021, losses of $24.7 million were recognized for the early retirement of these notes.~~open-market repurchases. During the first quarter of 2021, WES Operating redeemed the total principal amount outstanding of the 5.375% Senior Notes due 2021 at par value, pursuant to the optional redemption terms in WES Operating’s indenture.

As of ~~September~~June 30, ~~2021,~~2022, the ~~4.000%~~Floating-Rate Senior Notes ~~due 2022~~ were classified as ~~short-term~~long-term debt on the consolidated balance ~~sheet.~~sheet as WES Operating has the ability and intent to refinance these obligations using long-term debt. At ~~September~~June 30, ~~2021,~~2022, WES Operating was in compliance with all covenants under the relevant governing indentures.

Revolving credit facility.In June 2022, WES ~~Operating’s~~Operating entered into an amendment to its $2.0 billion senior unsecured revolving credit facility (“RCF”), which is expandable to a maximum of $2.5 billion, to, among other things, (i) extend the maturity date applicable to the loans and ~~matures in~~commitments of certain lenders totaling $1.6 billion to February ~~2025~~2026, (ii) provide for ~~each extending lender.~~the ability of WES Operating to extend the maturity date by one year on up to two additional occasions, (iii) provide that loans under the RCF with a fixed interest rate for a specified period bear interest based on the Secured Overnight Financing Rate (“SOFR”) instead of the London Interbank Offered Rate (“LIBOR”), and (iv) include an additional level of pricing if WES Operating’s senior unsecured debt rating is less than or equal to BB/Ba2/BB (Standard and Poor’s / Moody’s Investors Service / Fitch Ratings). The non-extending lender’s commitments mature in February ~~2024~~2025 and represent ~~$100.0~~$400.0 million out of $2.0 billion of total commitments from all lenders.

As of ~~September~~June 30, ~~2021,~~2022, there were ~~$220.0~~$255.0 million of outstanding borrowings and ~~$5.1~~$5.2 million of outstanding letters of credit, resulting in ~~$1.8~~$1.7 billion of available borrowing capacity under the RCF. As of ~~September~~June 30, ~~2021~~2022 and ~~2020,~~2021, the interest rate on any outstanding RCF borrowings was ~~1.58%~~3.12% and ~~1.65%~~1.60%, respectively. The facility-fee rate was 0.25% at ~~September~~June 30, ~~2021~~2022 and ~~2020.~~2021. At ~~September~~June 30, ~~2021,~~2022, WES Operating was in compliance with all covenants under the RCF. ~~Any outstanding RCF borrowings are classified as short-term debt on the consolidated balance sheet due to management’s intent to repay within the next twelve months.~~

~~Term loan facility.~~ ~~In January 2020, WES Operating repaid the outstanding borrowings with proceeds from the issuance of the Fixed~~-~~Rate Senior Notes and Floating~~-~~Rate Senior Notes and terminated its $3.0 billion senior unsecured credit facility (“Term loan facility”), see~~ ~~WES Operating Senior Notes~~ ~~above. During the first quarter of 2020, a loss of $2.3 million was recognized for the early termination of the Term loan facility.~~

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

~~11.~~10. DEBT AND INTEREST EXPENSE

~~Finance lease liabilities.~~ The Partnership subleased equipment from Occidental via finance leases through April 2020. During the first quarter of 2020, the Partnership entered into finance leases with third parties for equipment and vehicles extending through 2029. Certain equipment leases were amended during the third quarter of 2021 requiring reassessment of lease classification. As a result, these leases are now classified as operating leases resulting in a reduction of $19.6 million in Net property, plant, and equipment and $20.3 million in Short-term and Long-term debt. The operating leases resulted in additions of $4.8 million in Other assets, $3.1 million in Accrued liabilities, and $2.4 million in Other liabilities, on the consolidated balance sheet. The Partnership has future payments for its finance leases of $6.7 million as of September 30, 2021.

Interest expense. The following table summarizes the amounts included in interest expense:


		Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended June 30,				Six Months Ended June 30,
thousands	thousands	2021		2020		2021		2020		thousands	2022		2021		2022		2021
Third parties

Long-term and short-term debt	Long-term and short-term debt	$	(90,913)	$	(94,201)	$	(279,122)	$	(273,620)	Long-term and short-term debt	$	(78,577)	$	(92,487)	$	(162,005)	$	(188,209)
Finance lease liabilities	Finance lease liabilities	(218)		(369)		(808)		(1,162)		Finance lease liabilities	(31)		(292)		(73)		(590)
Commitment fees and amortization of debt-related costs	Commitment fees and amortization of debt-related costs	(3,147)		(3,463)		(9,664)		(10,052)		Commitment fees and amortization of debt-related costs	(3,068)		(3,179)		(6,100)		(6,517)
Capitalized interest	Capitalized interest	1,021		2,462		2,554		6,066		Capitalized interest	904		668		1,951		1,533
Total interest expense – third parties		(93,257)		(95,571)		(287,040)		(278,768)
Related parties

Finance lease liabilities		—		—		—		(43)
Total interest expense – related parties		—		—		—		(43)

Interest expense	Interest expense	$	(93,257)	$	(95,571)	$	(287,040)	$	(278,811)	Interest expense	$	(80,772)	$	(95,290)	$	(166,227)	$	(193,783)

~~12.~~11. COMMITMENTS AND CONTINGENCIES

Environmental obligations. The Partnership is subject to various environmental-remediation obligations arising from federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal, and other environmental matters. As of ~~September~~June 30, ~~2021,~~2022 and December 31, ~~2020,~~2021, the consolidated balance sheets included ~~$12.0~~$9.0 million and ~~$8.2~~$10.1 million, respectively, of liabilities for remediation and reclamation obligations. The current portion of these amounts is included in Accrued liabilities, and the long-term portion of these amounts is included in Other liabilities. The majority of payments related to these obligations are expected to be made over the next ~~five years.~~year.

Litigation and legal proceedings. From time to time, the Partnership is involved in legal, tax, regulatory, and other proceedings in various forums regarding performance, contracts, and other matters that arise in the ordinary course of business. Management is not aware of any such proceeding for which the final disposition could have a material adverse effect on the Partnership’s financial condition, results of operations, or cash flows.

Other commitments. The Partnership has payment obligations, or commitments, that include, among other things, a revolving credit facility, other third-party long-term debt, obligations related to the Partnership’s capital spending programs, pipeline and offload commitments, and various operating and finance leases. The payment obligations related to the Partnership’s capital spending programs, the majority of which is expected to be paid in the next ~~twelve~~12 months, primarily relate to construction, expansion, and asset-integrity projects at the West Texas complex, DBM water systems, DBM oil system, and DJ Basin ~~complex, and DBM oil system.~~complex.

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

The following discussion analyzes our financial condition and results of operations and should be read in conjunction with the Consolidated Financial Statements and Notes to Consolidated Financial Statements, wherein WES Operating is fully consolidated, and which are included under Part I, Item 1 of this quarterly report, and the historical consolidated financial statements, and the notes thereto, which are included under Part II, Item 8 of the ~~2020~~2021 Form 10-K as filed with the SEC on February ~~26, 2021.~~23, 2022.

The Partnership’s assets include assets owned and ownership interests accounted for by us under the equity method of accounting, through our 98.0% partnership interest in WES Operating, as of ~~September~~June 30, ~~2021~~2022 (see Note 7—Equity Investments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q). We also own and control the entire non-economic general partner interest in WES Operating GP, and our general partner is owned by Occidental.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

We have made in this Form 10-Q, and may make in other public filings, press releases, and statements by management, forward-looking statements concerning our operations, economic performance, and financial condition. These forward-looking statements include statements preceded by, followed by, or that otherwise include the words “believes,” “expects,” “anticipates,” “intends,” “estimates,” “projects,” “target,” “goal,” “plans,” “objective,” “should,” or similar expressions or variations on such expressions. These statements discuss future expectations, contain projections of results of operations or financial condition, or include other “forward-looking” information.

Although we and our general partner believe that the expectations reflected in our forward-looking statements are reasonable, neither we nor our general partner can provide any assurance that such expectations will prove correct. These forward-looking statements involve risks and uncertainties. Important factors that could cause actual results to differ materially from expectations include, but are not limited to, the following:

•our ability to pay distributions to our unitholders;

•our assumptions about the energy market;

•future throughput (including Occidental production) that is gathered or processed by, or transported through, our assets;

•our operating results;

•competitive conditions;

•technology;

•the availability of capital resources to fund acquisitions, capital expenditures, and other contractual obligations, and our ability to access financing through the debt or equity capital markets;

•the supply of, demand for, and price of oil, natural gas, NGLs, and related products or services;

•commodity-price risks inherent in percent-of-proceeds, percent-of-product, ~~and~~ keep-whole, and fixed-recovery processing contracts;

•weather and natural disasters;

•inflation;

•the availability of goods and services;

•general economic conditions, internationally, domestically, or in the jurisdictions in which we are doing business;

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•federal, state, and local laws and state-approved voter ballot initiatives, including those laws or ballot initiatives that limit producers’ hydraulic-fracturing activities or other oil and natural-gas development or operations;

•environmental liabilities;

•legislative or regulatory changes, including changes affecting our status as a partnership for federal income tax purposes;

•changes in the financial or operational condition of Occidental;

•the creditworthiness of Occidental or our other counterparties, including financial institutions, operating partners, and other parties;

•changes in Occidental’s capital program, corporate strategy, or other desired areas of focus;

•our commitments to capital projects;

•our ability to access liquidity under the RCF;

•our ability to repay debt;

•the ~~impact from disruptions caused by winter storm Uri or the blizzard in the state of Colorado or~~ resolution of litigation or other disputes;

•conflicts of interest among us and our general partner and its related parties, including Occidental, with respect to, among other things, the allocation of capital and operational and administrative costs and our future business opportunities;

•our ability to maintain and/or obtain rights to operate our assets on land owned by third parties;

•our ability to acquire assets on acceptable terms from third parties;

•non-payment or non-performance of significant customers, including under gathering, processing, transportation, and disposal agreements;

•the timing, amount, and terms of future issuances of equity and debt securities;

•the outcome of pending and future regulatory, legislative, or other proceedings or investigations, and continued or additional disruptions in operations that may occur as we and our customers comply with any regulatory orders or other state or local changes in laws or regulations;

•the economic uncertainty from the worldwide outbreak of the coronavirus (“COVID-19”);

•cyber attacks or security breaches; and

•other factors discussed below, in “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates” included in the ~~2020~~2021 Form 10-K, in our quarterly reports on Form 10-Q, and in our other public filings and press releases.

Risk factors and other factors noted throughout or incorporated by reference in this Form 10-Q could cause actual results to differ materially from those contained in any forward-looking statement. Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events, or otherwise.

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EXECUTIVE SUMMARY

We are a midstream energy company organized as a publicly traded partnership, engaged in the business of gathering, compressing, treating, processing, and transporting natural gas; gathering, stabilizing, and transporting condensate, NGLs, and crude oil; and gathering and disposing of produced water. In our capacity as a natural-gas processor, we also buy and sell natural gas, NGLs, and condensate on behalf of ourselves and as an agent for our customers under certain contracts. To provide superior midstream service, we focus on ensuring the reliability and performance of our systems, creating sustainable cost efficiencies, enhancing our safety culture, and protecting the environment. We own or have investments in assets located in Texas, New Mexico, the Rocky Mountains (Colorado, Utah, and Wyoming), and North-central Pennsylvania. As of ~~September~~June 30, ~~2021,~~2022, our assets and investments consisted of the following:


		Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests		Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems (1)	Gathering systems (1)	17	2	3	1	Gathering systems (1)	17	2	3	1
Treating facilities	Treating facilities	36	3	—	—	Treating facilities	37	3	—	—
Natural-gas processing plants/trains	Natural-gas processing plants/trains	24	3	—	5	Natural-gas processing plants/trains	24	3	—	5
NGLs pipelines	NGLs pipelines	2	—	—	5	NGLs pipelines	2	—	—	5
Natural-gas pipelines	Natural-gas pipelines	5	—	—	1	Natural-gas pipelines	5	—	—	1
Crude-oil pipelines	Crude-oil pipelines	3	1	—	4	Crude-oil pipelines	3	1	—	4

(1)Includes the DBM water systems.

Significant financial and operational events during the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, included the following:

•WES Operating redeemed the $502.2 million total principal amount outstanding of the ~~5.375%~~4.000% Senior Notes due ~~2021~~2022 at par ~~value, pursuant to the optional redemption terms in WES Operating’s indenture.~~

•~~WES Operating purchased and retired $500.0 million of certain of its senior notes via a tender offer.~~value.

•We repurchased ~~5,586,419~~3,314,562 common units on the open market for an aggregate purchase price of ~~$104.4~~$79.2 million.

•Our ~~third~~second-quarter ~~2021~~2022 per-unit distribution ~~of $0.32300 increased $0.004~~is unchanged from the ~~second~~-~~quarter 2021 per~~-~~unit~~first-quarter 2022 per-unit distribution of ~~$0.31900.~~$0.50000.

•Natural-gas throughput attributable to WES totaled ~~4,081~~4,270 MMcf/d and ~~4,132~~4,165 MMcf/d for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing a ~~4% decrease and 6% decrease~~5% increase compared to the three months ended March 31, 2022, and no changecompared to the six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively.

•Crude-oil and NGLs throughput attributable to WES totaled ~~641~~666 MBbls/d and ~~645~~670 MBbls/d for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing a 7%1% decrease and ~~11% decrease~~a 4% increase compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively.

•Produced-water throughput attributable to WES totaled ~~735~~864 MBbls/d and ~~673~~808 MBbls/d for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing a 7%15% increase and ~~5% decrease~~a 26% increase compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively.

•Gross margin was ~~$541.6~~$588.8 million and ~~$1.5 billion~~$1,139.7 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing ~~an 8%~~a 7% increase and ~~5% decrease~~a 19% increase compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively. See Key Performance Metrics within this Item 2.

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•Adjusted gross margin for natural-gas assets (as defined under the caption Key Performance Metrics within this Item 2) averaged ~~$1.31~~$1.36 per Mcf and ~~$1.24~~$1.35 per Mcf for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing ~~an 8%~~a 1% increase and a 13% increase compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020.~~respectively.

•Adjusted gross margin for crude-oil and NGLs assets (as defined under the caption Key Performance Metrics within this Item 2) averaged ~~$2.52~~$2.57 per Bbl and ~~$2.46~~$2.50 per Bbl for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing a 5% increase and ~~2% decrease~~a 3% increase compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively.

•Adjusted gross margin for produced-water assets (as defined under the caption Key Performance Metrics within this Item 2) averaged ~~$0.94~~$0.90 per Bbl and ~~$0.93~~$0.95 per Bbl for the three and ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, respectively, representing a 2%10% decrease and a 3% increase ~~and 5%~~ ~~decrease~~ compared to the three months ended March 31, 2022, and six months ended June 30, 2021, ~~and nine months ended September 30, 2020,~~ respectively.

The following table provides additional information on throughput for the periods presented below:

Three Months Ended Nine Months Ended
September 30, 2021 June 30,
2021 Inc/
(Dec) September 30, 2021 September 30, 2020 Inc/
(Dec)
Throughput for natural-gas assets (MMcf/d)
Delaware Basin 1,274 1,244 2 % 1,217 1,330 (8) %
DJ Basin 1,368 1,413 (3) % 1,375 1,342 2 %
Equity investments 443 457 (3) % 447 451 (1) %
Other 1,152 1,310 (12) % 1,248 1,416 (12) %
Total throughput for natural-gas assets
4,237 4,424 (4) % 4,287 4,539 (6) %
Throughput for crude-oil and NGLs assets (MBbls/d)
Delaware Basin 185 184 1 % 177 192 (8) %
DJ Basin 87 98 (11) % 89 109 (18) %
Equity investments 350 386 (9) % 358 395 (9) %
Other 32 33 (3) % 34 42 (19) %
Total throughput for crude-oil and NGLs assets
654 701 (7) % 658 738 (11) %
Throughput for produced-water assets (MBbls/d)
Delaware Basin 750 702 7 % 687 726 (5) %
Total throughput for produced-water assets
750 702 7 % 687 726 (5) %

~~Weather-related impacts.~~ In February 2021, the U.S. experienced winter storm Uri, bringing extreme cold temperatures, ice, and snow to the central U.S., including Texas, and in March 2021, Colorado experienced a historic blizzard. Winter storm Uri adversely affected our volumes for approximately ten days and the blizzard in Colorado likewise disrupted our assets in that state. We estimate the impact of these weather events to have reduced net income and Adjusted EBITDA (as defined under the caption ~~Key Performance Metrics~~ within this Item 2) for the nine months ended September 30, 2021, by approximately $30 million due to lower volumes, the impact of commodity-prices, and higher operating expenses related to utilities. The estimated impact of the adverse winter weather on our operations and financial results may change and those changes may be material. Any additional inclement weather in the future, or other adverse conditions, including resolution of litigation and other legal disputes and the COVID-~~19 pandemic and resulting mitigation factors, may have an adverse impact on our operations and financial results.~~



	Three Months Ended				Six Months Ended

	June 30, 2022	March 31, 2022	Inc/ (Dec)		June 30, 2022	June 30, 2021	Inc/ (Dec)
Throughput for natural-gas assets (MMcf/d)
Delaware Basin	1,493	1,326	13	%	1,410	1,189	19	%
DJ Basin	1,336	1,321	1	%	1,329	1,379	(4)	%
Equity investments	516	479	8	%	498	448	11	%
Other	1,082	1,084	—	%	1,082	1,296	(17)	%
Total throughput for natural-gas assets	4,427	4,210	5	%	4,319	4,312	—	%
Throughput for crude-oil and NGLs assets (MBbls/d)
Delaware Basin	198	192	3	%	195	173	13	%
DJ Basin	83	88	(6)	%	85	90	(6)	%
Equity investments	360	374	(4)	%	367	361	2	%
Other	39	35	11	%	37	34	9	%
Total throughput for crude-oil and NGLs assets	680	689	(1)	%	684	658	4	%
Throughput for produced-water assets (MBbls/d)
Delaware Basin	882	766	15	%	824	655	26	%



Total throughput for produced-water assets	882	766	15	%	824	655	26	%

~~Table of Contents~~

~~COVID-19.~~ ~~During 2020, the global outbreak of COVID~~-~~19 caused a sharp decline in the worldwide demand for oil, natural gas, and NGLs, which contributed significantly to commodity~~-price declines and oversupplied commodities markets. These market dynamics have had an adverse impact on producers that provide throughput into our systems, and we have experienced decreased throughput at many of our locations.

~~Additionally, many of our employees have been and may continue to be subject to pandemic~~-~~related work~~-~~from~~-~~home requirements, which require us to take additional actions to ensure that the number of personnel accessing our network remotely does not lead to excessive cyber~~-security risk levels. Similarly, we are working continually to ensure operational changes that we have made to promote the health and safety of our personnel during this pandemic do not unduly disrupt intracompany communications and key business processes. We consider our risk-~~mitigation efforts adequate; however, the ultimate impact of the ongoing pandemic is unpredictable, with direct and indirect impacts to our business.~~

~~WES continues to monitor the COVID~~-19 situation closely, and as state and federal governments issue additional guidance, we will update our own policies in response to ensure the safety and health of our workforce and communities. The federal government has provided guidance to states on how to safely return personnel to the workplace, which we are following as our workforce returns to WES locations. All WES facilities, including field locations, have been conducting enhanced routine cleaning and disinfecting of common areas and frequently touched surfaces using CDC- ~~and EPA~~-~~approved products. Our return~~-to-~~work protocols include daily required application~~-~~based health self~~-~~assessments that must be completed prior to accessing WES work locations.~~

~~Commodity purchase and sale agreements.~~ ~~Effective April 1, 2020, changes to marketing~~-~~contract terms with AESC terminated AESC’s prior status as an agent of the Partnership for third~~-party sales and established AESC as a customer of the Partnership. Accordingly, we no longer recognize service revenues and/or product sales revenues and the equivalent cost of product expense for the marketing services performed by AESC. Year-~~over~~-~~year variances for the nine months ended September 30, 2021, include the following impacts related to this change (i) decrease of $45.9 million in Service revenues~~ – fee based, (ii) decrease of $21.2 million in Product sales, and (iii) decrease of $67.1 million in Cost of product expense. These changes had no impact to Operating income (loss), Net income (loss), the balance sheets, cash flows, or any non-~~GAAP metric used to evaluate our operations (see~~ ~~Key Performance Metrics~~ ~~within this Item 2). See~~ ~~Note 6—Related-Party Transactions~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q.~~

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OUTLOOK

We expect our business to continue to be affected by the below-described key trends and uncertainties. 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 incorrect, our actual results may vary materially from expected results.

Impact of crude-oil, natural-gas, and NGLs prices. Crude-oil, natural-gas, and NGLs prices can fluctuate significantly, and have done so over time. Commodity-price fluctuations affect the level of our customers’ activities and our customers’ allocations of capital within their own asset portfolios. During ~~the first quarter of~~ 2020, oil and natural-gas prices ~~decreased significantly, driven~~were negatively impacted by ~~the expectation of increased supply and sharp declines in demand resulting from~~ the worldwide macroeconomic downturn that followed the global outbreak of COVID-19. In 2021, prices began to increase and in the first quarter of 2022, commodity prices increased significantly in connection with the war in Ukraine. For example, NYMEX West Texas Intermediate crude-oil daily settlement prices during 2021 ranged from a ~~high~~low of ~~$63.27~~$47.62 per barrel in January ~~2020~~2021 to a ~~low below $20.00~~high of $84.65 per barrel in ~~April 2020. Although commodity~~October 2021, and prices ~~have rebounded~~during the six months ended June 30, 2022, ranged from a low of $76.08 per barrel in January 2022 to ~~pre-pandemic levels, the~~a high of $123.70 per barrel in March 2022. The extent and duration of the recent commodity-price volatility cannot be ~~predicted, and potential impacts to our business include the following:~~

•~~We have exposure to increased credit risk to the extent any of our customers, including Occidental, is in financial distress. See~~ ~~Liquidity and Capital Resources—Credit risk~~ ~~within this Item 2 for additional information.~~

•~~An extended period of diminished earnings may restrict our ability to fully access our RCF, which contains~~ ~~various customary covenants, certain events of default, and a maximum consolidated leverage ratio based on Adjusted EBITDA (as defined in the covenant) related to the trailing twelve~~-~~month period.~~ ~~Further, any future waivers or amendments to the RCF also may trigger pricing increases for available credit. See~~ ~~Liquidity and Capital Resources—Debt and credit facilities~~ ~~within this Item 2 for additional information.~~

•~~As of September 30, 2021, it is reasonably possible that future commodity~~-~~price declines, prolonged depression of commodity prices, changes to producers’ drilling plans in response to lower prices, and potential producer bankruptcies could result in future long~~-~~lived asset impairments.~~

predicted.

To the extent producers continue with development plans in our areas of operation, we ~~will~~intend to continue to connect new wells or production facilities to our systems to maintain or increase throughput on our systems and mitigate the impact of production declines. However, our success in connecting additional wells or production facilities is dependent on the activity levels of our ~~customers.~~customers, any capacity constraints, and the availability of downstream-takeaway alternatives. In some cases, we take ownership of volumes at the tailgate of our plants based on certain contractual arrangements with our producer customers, which introduces additional commodity-price exposure. Additionally, we ~~will~~intend to continue to evaluate the crude-oil, NGLs, and natural-gas price environments and adjust our capital spending plans to reflect our customers’ anticipated activity levels, while maintaining appropriate liquidity and financial flexibility.

Impact of inflation and supply-chain disruptions. Although inflation in the United States has been relatively low in recent years, the U.S. economy currently is experiencing significant inflation relative to historical precedent, from, among other things, supply-chain disruptions caused by, or governmental stimulus or fiscal policies adopted in response to, the COVID-19 crisis and in connection with the war in Ukraine. More specifically, the bottlenecks and disruptions from the lingering effects of the COVID-19 crisis have caused difficulties within the U.S. and global supply chains, creating logistical delays along with labor shortages. Continued increases in inflation will raise our costs for labor, materials, fuel, and services, which will increase our operating costs and capital expenditures materially and negatively impact our financial results. To the extent permitted by regulations and escalation provisions in certain of our existing agreements, we have the ability to recover a portion of increased costs in the form of higher fees.

Impact of interest rates. Overall, short- and long-term interest rates increased during 2021 and have continued to increase during 2022. Any future increases in interest rates likely will result in an increase in financing costs. Additionally, as with other yield-oriented securities, our unit price could be impacted by our implied distribution yield relative to market interest rates. Therefore, changes in interest rates, either positive or negative, may affect the yield requirements of investors who invest in our units, and a rising interest-rate environment could have an adverse impact on our unit price and our ability to issue additional equity, or increase the cost of issuing equity, to make acquisitions, to reduce debt, or for other purposes. However, we expect our cost of capital to remain competitive, as our competitors face similar interest-rate dynamics.

ACQUISITIONS AND DIVESTITURES

~~Fort Union and~~ Bison ~~facilities.~~facility. In October 2020, we ~~(i) sold our 14.81% interest in Fort Union, which was accounted for under the equity method of accounting, and (ii)~~ entered into an option agreement to sell the Bison treating facility, located in Northeast Wyoming, to a third party.

During the second quarter of 2021, the third party exercised its option to purchase the Bison treating facility and the sale closed. We received total proceeds of $8.0 million, $7.0 million in the fourth quarter of 2020 and $1.0 million when the sale closed in the second quarter of 2021, resulting in a net gain on sale of $5.4 million that was recorded as Gain (loss) on divestiture and other, net in the consolidated statements of operations. See Note 3—Acquisitions and Divestitures in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for further information.

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RESULTS OF OPERATIONS

OPERATING RESULTS

~~In November 2020, the SEC issued a final rule to modernize and simplify Management’s Discussion and Analysis and certain financial disclosure requirements in SEC Regulation S~~-~~K. As permitted by this final rule, the analysis herein reflects the optional approach to discuss results of operations on a sequential~~-quarter basis, which we believe will provide information that is most useful to investors in assessing our quarterly results of operations going forward. In addition, as required by the final rule, we have continued to include a comparison of the current year-to-date period to the prior year-to-date period.

For purposes of the following discussion, any increases or decreases “for the three months ended September 30, 2021” refer to the comparison of the three months ended September 30, 2021, to the three months ended June 30, 2021; and any increases or decreases “for the nine months ended September 30, 2021” refer to the comparison of the nine months ended September 30, 2021, to the nine months ended September 30, 2020.

The following tables and discussion present a summary of our results of operations:


		Three Months Ended				Nine Months Ended				Three Months Ended				Six Months Ended

thousands	thousands	September 30, 2021		June 30, 2021		September 30, 2021		September 30, 2020			thousands	June 30, 2022		March 31, 2022		June 30, 2022		June 30, 2021
Total revenues and other (1)	Total revenues and other (1)	$	763,840	$	719,131	$	2,157,945	$	2,125,112		Total revenues and other (1)	$	876,419	$	758,297	$	1,634,716	$	1,394,105
Equity income, net – related parties	Equity income, net – related parties	48,506		58,666		159,337		176,788			Equity income, net – related parties	48,464		49,607		98,071		110,831
Total operating expenses (1)	Total operating expenses (1)	428,716		444,074		1,307,010		1,792,290			Total operating expenses (1)	526,345		403,450		929,795		878,294
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(364)		1,225		278		(3,651)			Gain (loss) on divestiture and other, net	(1,150)		370		(780)		642
Operating income (loss)	Operating income (loss)	383,266		334,948		1,010,550		505,959			Operating income (loss)	397,388		404,824		802,212		627,284
Interest income – Anadarko note receivable		—		—		—		11,736

Interest expense	Interest expense	(93,257)		(95,290)		(287,040)		(278,811)			Interest expense	(80,772)		(85,455)		(166,227)		(193,783)
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	(24,655)		—		(24,944)		10,372			Gain (loss) on early extinguishment of debt	91		—		91		(289)
Other income (expense), net	Other income (expense), net	110		84		(1,013)		612			Other income (expense), net	(45)		106		61		(1,123)
Income (loss) before income taxes	Income (loss) before income taxes	265,464		239,742		697,553		249,868			Income (loss) before income taxes	316,662		319,475		636,137		432,089
Income tax expense (benefit)	Income tax expense (benefit)	1,826		1,465		4,403		3,792			Income tax expense (benefit)	1,491		1,805		3,296		2,577
Net income (loss)	Net income (loss)	263,638		238,277		693,150		246,076			Net income (loss)	315,171		317,670		632,841		429,512
Net income (loss) attributable to noncontrolling interests	Net income (loss) attributable to noncontrolling interests	7,913		7,018		20,375		(17,045)			Net income (loss) attributable to noncontrolling interests	8,854		8,953		17,807		12,462
Net income (loss) attributable to Western Midstream Partners, LP (2)	Net income (loss) attributable to Western Midstream Partners, LP (2)	$	255,725	$	231,259	$	672,775	$	263,121		Net income (loss) attributable to Western Midstream Partners, LP (2)	$	306,317	$	308,717	$	615,034	$	417,050
Key performance metrics (3)
Adjusted gross margin		$	705,407	$	677,236	$	1,997,267	$	2,069,801
Adjusted EBITDA		531,580		491,126		1,465,816		1,546,386
Free cash flow		320,031		379,776		913,629		762,364

(1)Total revenues and other includes amounts earned from services provided to related parties and from the sale of natural gas, condensate, and NGLs to related parties. Total operating expenses includes amounts charged by related parties for services received. See Note 6—Related-Party Transactions in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

(2)For reconciliations to comparable consolidated results of WES Operating, see Items Affecting the Comparability of Financial Results with WES Operating within this Item 2.

~~(3)Adjusted gross margin, Adjusted EBITDA, and Free cash flow are defined under the caption~~ ~~Key Performance Metrics~~ ~~within this Item 2. For reconciliations of these non~~-~~GAAP financial measures to their most directly comparable financial measures calculated and presented in accordance with GAAP, see~~ ~~Key Performance Metrics—Reconciliation of non-GAAP financial measures~~ ~~within this Item 2.~~

For purposes of the following discussion, any increases or decreases “for the three months ended June 30, 2022” refer to the comparison of the three months ended June 30, 2022, to the three months ended March 31, 2022; and any increases or decreases “for the six months ended June 30, 2022” refer to the comparison of the six months ended June 30, 2022, to the six months ended June 30, 2021.

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Throughput


		Three Months Ended				Nine Months Ended						Three Months Ended				Six Months Ended

		September 30, 2021	June 30, 2021	Inc/ (Dec)		September 30, 2021	September 30, 2020	Inc/ (Dec)				June 30, 2022	March 31, 2022	Inc/ (Dec)		June 30, 2022	June 30, 2021	Inc/ (Dec)
Throughput for natural-gas assets (MMcf/d)	Throughput for natural-gas assets (MMcf/d)									Throughput for natural-gas assets (MMcf/d)
Gathering, treating, and transportation	Gathering, treating, and transportation	378	534	(29)	%	477	551	(13)	%		Gathering, treating, and transportation	410	406	1	%	408	527	(23)	%
Processing	Processing	3,416	3,433	—	%	3,363	3,537	(5)	%		Processing	3,501	3,325	5	%	3,413	3,337	2	%
Equity investments (1)	Equity investments (1)	443	457	(3)	%	447	451	(1)	%		Equity investments (1)	516	479	8	%	498	448	11	%
Total throughput	Total throughput	4,237	4,424	(4)	%	4,287	4,539	(6)	%		Total throughput	4,427	4,210	5	%	4,319	4,312	—	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	156	159	(2)	%	155	162	(4)	%		Throughput attributable to noncontrolling interests (2)	157	152	3	%	154	155	(1)	%
Total throughput attributable to WES for natural-gas assets	Total throughput attributable to WES for natural-gas assets	4,081	4,265	(4)	%	4,132	4,377	(6)	%		Total throughput attributable to WES for natural-gas assets	4,270	4,058	5	%	4,165	4,157	—	%
Throughput for crude-oil and NGLs assets (MBbls/d)	Throughput for crude-oil and NGLs assets (MBbls/d)									Throughput for crude-oil and NGLs assets (MBbls/d)
Gathering, treating, and transportation	Gathering, treating, and transportation	304	315	(3)	%	300	343	(13)	%		Gathering, treating, and transportation	320	315	2	%	317	297	7	%
Equity investments (3)	Equity investments (3)	350	386	(9)	%	358	395	(9)	%		Equity investments (3)	360	374	(4)	%	367	361	2	%
Total throughput	Total throughput	654	701	(7)	%	658	738	(11)	%		Total throughput	680	689	(1)	%	684	658	4	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	13	14	(7)	%	13	15	(13)	%		Throughput attributable to noncontrolling interests (2)	14	14	—	%	14	13	8	%
Total throughput attributable to WES for crude-oil and NGLs assets	Total throughput attributable to WES for crude-oil and NGLs assets	641	687	(7)	%	645	723	(11)	%		Total throughput attributable to WES for crude-oil and NGLs assets	666	675	(1)	%	670	645	4	%
Throughput for produced-water assets (MBbls/d)	Throughput for produced-water assets (MBbls/d)									Throughput for produced-water assets (MBbls/d)
Gathering and disposal	Gathering and disposal	750	702	7	%	687	726	(5)	%		Gathering and disposal	882	766	15	%	824	655	26	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	15	14	7	%	14	15	(7)	%		Throughput attributable to noncontrolling interests (2)	18	15	20	%	16	13	23	%
Total throughput attributable to WES for produced-water assets	Total throughput attributable to WES for produced-water assets	735	688	7	%	673	711	(5)	%		Total throughput attributable to WES for produced-water assets	864	751	15	%	808	642	26	%

(1)Represents the ~~14.81% share of average Fort Union throughput (until divested in October 2020),~~ 22% share of average Rendezvous throughput, 50% share of average Mi Vida and Ranch Westex throughput, and 30% share of average Red Bluff Express throughput.

(2)For all periods presented, includes (i) the 2.0% Occidental subsidiary-owned limited partner interest in WES Operating and (ii) for natural-gas assets, the 25% third-party interest in Chipeta, which collectively represent WES’s noncontrolling interests.

(3)Represents the 10% share of average White Cliffs throughput; 25% share of average Mont Belvieu JV throughput; 20% share of average TEG, TEP, Whitethorn, and Saddlehorn throughput; 33.33% share of average FRP throughput; and 15% share of average Panola and Cactus II throughput.

Natural-gas assets

Gathering, treating, and transportation throughput decreased by ~~156~~119 MMcf/d for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) decreased volumes at the Bison treating facility, which was sold to a third party during the second quarter of 2021, and (ii) production declines in areas around the Marcellus Interest and Springfield ~~gas~~-~~gathering~~gas-gathering systems.

~~Gathering, treating, and transportation~~Processing throughput ~~decreased~~increased by 74176 MMcf/d for the ~~nine~~three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) ~~decreased~~higher volumes at the ~~Bison treating facility, which was sold~~West Texas complex due to increased production in the area and the impacts of inclement weather in the first quarter of 2022 and (ii) higher volumes at the DJ Basin complex due to a ~~third party during~~third-party contract amendment effective in March 2022.

Processing throughput increased by 76 MMcf/d for the ~~second quarter of 2021 and (ii)~~six months ended June 30, 2022, primarily due to higher volumes at the West Texas complex due to increased production ~~declines~~in the area and the impact of winter storm Uri atduring the ~~Springfield gas~~-~~gathering system. These decreases were~~first quarter of 2021. This increase was offset partially by ~~increased production in areas around the Marcellus Interest systems.~~

~~Processing throughput decreased by 17 MMcf/d for the three months ended September 30, 2021, primarily due to decreased production in areas around~~lower volumes at the DJ Basin, ~~complex, partially offset by increased~~Granger, and Brasada complexes due to production declines in ~~areas around~~ the ~~West Texas complex.~~areas.

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Processing throughput decreased by 174 MMcf/d for the nine months ended September 30, 2021, primarily due to (i) lower production and the impact of winter storm Uri at the West Texas complex, (ii) the Granger straddle plant being held idle beginning in the third quarter of 2020, and (iii) lower volumes at the Granger complex due to production declines in the area. These decreases were offset partially by higher volumes at the DJ Basin complex primarily due to an additional third-party connection to Latham Train II beginning January 1, 2021.

Equity-investment throughput ~~decreased~~increased by 1437 MMcf/d for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increased volumes on Red Bluff Express, partially offset by decreased volumes at the ~~Mi Vida and~~ Ranch Westex ~~plants and the Rendezvous system.~~plant.

Equity-investment throughput ~~decreased~~increased by 450 MMcf/d for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increased volumes on Red Bluff Express and at the Mi Vida plant resulting from the impact of winter storm Uri during the first quarter of 2021. These increases were offset partially by (i) decreased volumes at the Ranch Westex plant and (ii) decreased volumes at the Rendezvous system due to production declines in the area and (ii) decreased volumes at the Fort Union system, which was sold to a third party during the fourth quarter of 2020. These decreases were offset partially by increased volumes on Red Bluff Express resulting from increased pipeline commitments.area.

Crude-oil and NGLs assets

Gathering, treating, and transportation throughput ~~decreased~~increased by 1120 MBbls/d for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~decreased production in areas around the DJ Basin oil system.~~

Gathering, treating, and transportation throughput decreased by 43 MBbls/d for the nine months ended September 30, 2021, primarily due to (i) lower volumes at the DJ Basin oil system resulting from production declines in the area and (ii) lowerhigher volumes at the DBM oil system ~~due to lower~~resulting from increased production in the area and the impact of winter storm ~~Uri.~~Uri during the first quarter of 2021.

Equity-investment throughput decreased by 3614 MBbls/d for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to decreased volumes on the Whitethorn ~~pipeline~~ and ~~TEP,~~Cactus II pipelines, partially offset by increased volumes on ~~the Cactus II pipeline resulting from an incentive rate implemented in the second quarter of 2021.~~FRP.

Equity-investment throughput ~~decreased~~increased by 376 MBbls/d for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increased volumes on FRP resulting from increased pipeline commitments, partially offset by decreased volumes on the Whitethorn ~~pipeline, partially offset by increased volumes on the Saddlehorn~~ pipeline.

Produced-water assets

Gathering and disposal throughput increased by 48116 MBbls/d for the three months ended ~~September~~June 30, ~~2021,~~2022, due to ~~increased volumes~~(i) new third-party connections brought online at the ~~DBM water systems resulting from~~end of the first quarter and during the second quarter of 2022, (ii) higher production, and (iii) the impacts of inclement weather in the ~~area.~~first quarter of 2022.

Gathering and disposal throughput ~~decreased~~increased by 39169 MBbls/d for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, due to ~~decreased volumes at~~(i) higher production, (ii) new third-party connections brought online during the ~~DBM water systems resulting from lower production~~fourth quarter of 2021 and in 2022, and (iii) the impact of winter storm ~~Uri.~~Uri during the first quarter of 2021.

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Service Revenues


		Three Months Ended						Nine Months Ended							Three Months Ended						Six Months Ended

thousands except percentages	thousands except percentages	September 30, 2021		June 30, 2021		Inc/ (Dec)		September 30, 2021		September 30, 2020		Inc/ (Dec)		thousands except percentages	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
Service revenues – fee based	Service revenues – fee based	$	650,482	$	618,985	5	%	$	1,841,742	$	1,980,546	(7)	%	Service revenues – fee based	$	655,952	$	631,598	4	%	$	1,287,550	$	1,191,260	8	%
Service revenues – product based	Service revenues – product based	28,812		27,803		4	%	88,267		35,237		150	%	Service revenues – product based	70,498		40,867		73	%	111,365		59,455		87	%
Total service revenues	Total service revenues	$	679,294	$	646,788	5	%	$	1,930,009	$	2,015,783	(4)	%	Total service revenues	$	726,450	$	672,465	8	%	$	1,398,915	$	1,250,715	12	%

Service revenues – fee based

Service revenues – fee based increased by ~~$31.5~~$24.4 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of (i) ~~$18.9~~$19.7 million ~~due to revenue recorded in the third quarter of 2021 that was previously constrained (see~~ ~~Note 2—Revenue from Contracts with Customers~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q)~~ and ~~(ii) $14.2~~$3.2 million at the West Texas complex ~~resulting from~~and DBM oil system, respectively, attributable to increased ~~throughput.~~throughput and (ii) $3.0 million at the DBM water systems due to increased throughput, partially offset by a decrease in deficiency fees.

Service revenues – fee based ~~decreased~~increased by ~~$138.8~~$96.3 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~decreases~~increases of (i) ~~$45.9 million, resulting from a change in accounting for the marketing contracts with AESC effective April 1, 2020 (see~~ ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2), (ii) $37.9~~$46.9 million at the ~~DBM oil system~~West Texas complex due to ~~decreased~~increased throughput, including the impact of winter storm Uri during the first quarter of 2021, partially offset by a lower average fee resulting from a cost-of-service rate redetermination effective January 1, 2022, and ~~lower lease revenue under the operating~~(ii) $30.4 million and ~~maintenance agreement with Occidental, (iii) $23.8~~$29.8 million at the DBM oil and DBM water systems, ~~resulting from decreased~~respectively, due to increased throughput, including the impact of winter storm Uri during the first quarter of 2021, and increased deficiency fees. These increases were offset partially by a ~~lower average fee resulting from a cost~~-decrease of-~~service rate redetermination effective January 1, 2021, (iv) $20.9~~ $11.1 million at the DJ Basin complex due to decreased throughput, on certain fee-based contracts, (v) $12.1 million at the Bison treating facility due to the expiration of a minimum-volume commitment contract in the fourth quarter of 2020, decreased throughput, and the sale of the facility to a third party during the second quarter of 2021, and (vi) $9.6 million at the West Texas complex from decreased throughput, including the impact of winter storm Uri. These decreases werepartially offset ~~partially~~ by ~~an increase of $18.9 million due to revenue recorded in the third quarter of 2021 that was previously constrained (see~~ ~~Note 2—Revenue from Contracts with Customers~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q).~~increased deficiency fees.

Service revenues – product based

Service revenues – product based increased by ~~$1.0~~$29.6 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~increased pricing across several systems, partially offset by a decrease~~increases of ~~$4.7~~(i) $19.1 million at the West Texas complex ~~primarily~~ due to ~~a decrease~~increased prices, change in ~~electricity~~-~~related fees charged~~contract mix, and increased electricity-related rates billed to ~~customers.~~

~~Service revenues – product based increased by $53.0 million for the nine months ended September 30, 2021, primarily due to increases of (i) $15.6~~customers, and (ii) $10.2 million at the DJ Basin complex due to change in contract mix.

Service revenues – product based increased ~~third~~-~~party volumes~~by $51.9 million for the six months ended June 30, 2022, primarily due to increases of (i) $21.2 million and ~~average prices, (ii) $15.1~~$19.4 million at the West Texas and DJ Basin complexes, respectively, attributable to increased prices and changes in contract mix during the second quarter of 2022, and (ii) $3.4 million at the Chipeta complex, ~~due to an increase in electricity~~-~~related fees charged to customers during winter storm Uri,~~$2.8 million at the DBM water systems, $2.6 million at the MGR assets, and ~~(iii) $6.5~~$2.3 million at the Granger complex ~~$6.3 million at the Hilight system, and $4.7 million at the Chipeta complex~~ due to increased prices.

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Product Sales

Three Months Ended Nine Months Ended
thousands except percentages and per-unit amounts September 30, 2021 June 30,
2021 Inc/
(Dec) September 30, 2021 September 30, 2020 Inc/
(Dec)
Natural-gas sales
$ 32,151 $ 14,195 126 % $ 67,765 $ 23,934 183 %
NGLs sales 52,147 58,061 (10) % 159,594 84,557 89 %
Total Product sales $ 84,298 $ 72,256 17 % $ 227,359 $ 108,491 110 %
Per-unit gross average sales price:
Natural gas (per Mcf) $ 4.10 $ 2.65 55 % $ 4.20 $ 1.32 NM
NGLs (per Bbl) 36.96 27.16 36 % 30.81 12.25 152 %

NM—~~Not meaningful~~



	Three Months Ended						Six Months Ended

thousands except percentages and per-unit amounts	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
Natural-gas sales	$	47,292	$	19,071	148	%	$	66,363	$	35,614	86	%
NGLs sales	102,444		66,518		54	%	168,962		107,447		57	%
Total Product sales	$	149,736	$	85,589	75	%	$	235,325	$	143,061	64	%
Per-unit gross average sales price:
Natural gas (per Mcf)	$	7.02	$	4.38	60	%	$	5.76	$	4.26	35	%
NGLs (per Bbl)	46.57		46.48		—	%	46.53		27.73		68	%

Natural-gas sales

Natural-gas sales increased by ~~$18.0~~$28.2 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of ~~(i) $13.1~~$25.8 million and $4.1 million at the West Texas complex and MGR assets, respectively, attributable to ~~an increase in~~increased average prices and volumes ~~sold and (ii) $2.3 million at the DJ Basin complex and $2.1 million at the MGR assets attributable to an increase in average prices.~~sold.

Natural-gas sales increased by ~~$43.8~~$30.7 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~increases~~an increase of ~~(i) $37.2~~$36.6 million at the West Texas complex ~~and $7.4 million at the MGR assets~~ attributable to ~~increases in~~increased average prices and ~~(ii) $1.8 million resulting from~~volumes sold. This increase was partially offset by a ~~change in accounting for the marketing contracts with AESC effective April 1, 2020 (see~~ ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2). These increases were offset partially by decreases~~decrease of ~~$4.9~~$6.5 million at the DJ Basin complex ~~and $4.3 million at the Granger complex attributable~~due to ~~decreases in~~decreased volumes sold, partially offset by ~~increases~~an increase in average prices.

NGLs sales

NGLs sales ~~decreased~~increased by ~~$5.9~~$35.9 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~a decrease~~an increase of ~~$8.7~~$40.7 million at the West Texas complex ~~attributable~~due to ~~net changes in contract mix. This decrease was partially offset by an increase of $2.2 million at the Chipeta complex attributable to an increase in~~increased average prices and volumes sold.

NGLs sales increased by ~~$75.0~~$61.5 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of (i) ~~$65.4~~$31.7 million at the West Texas complex, $13.3 million at the Chipeta complex, $2.8 million at the DBM water systems, and $2.8 million at the MGR assets attributable to increased average prices and volumes sold, and (ii) $4.4 million and $3.2 million at the Granger and DJ Basin complexes, respectively, due to an increase in average prices, partially offset by ~~decreased volumes sold and (ii) $15.9 million at the Chipeta complex and $8.7 million at the Granger complex attributable to increases in average prices. These increases were offset partially by~~ a decrease ~~of $23.0 million resulting from a change~~ in ~~accounting for the marketing contracts with AESC effective April 1, 2020 (see~~ ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2).~~volumes sold.

Equity Income, Net – Related Parties


		Three Months Ended						Nine Months Ended							Three Months Ended						Six Months Ended

thousands except percentages	thousands except percentages	September 30, 2021		June 30, 2021		Inc/ (Dec)		September 30, 2021		September 30, 2020		Inc/ (Dec)		thousands except percentages	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
Equity income, net – related parties	Equity income, net – related parties	$	48,506	$	58,666	(17)	%	$	159,337	$	176,788	(10)	%	Equity income, net – related parties	$	48,464	$	49,607	(2)	%	$	98,071	$	110,831	(12)	%

Equity income, net – related parties decreased by ~~$10.2~~$12.8 million for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) decreases of ~~$5.9~~$6.7 million and $6.0 million at Saddlehorn and Cactus II, respectively, and ~~$4.1~~(ii) $4.5 million at ~~Mont Belvieu JV resulting from electricity credits received~~Whitethorn LLC due to decreases in ~~the second quarter~~revenues and volumes. These decreases were offset partially by an increase of ~~2021 related~~$8.7 million at Mi Vida, FRP, and TEP due to ~~winter storm Uri.~~higher volumes.

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Equity income, net – related parties decreased by $17.5 million for the nine months ended September 30, 2021, primarily due to decreases of (i) $24.1 million at Whitethorn LLC related to commercial activities and lower volumes and (ii) $4.8 million and $4.2 million at Cactus II and White Cliffs, respectively, due to lower volumes. These decreases were offset partially by increases of (i) $6.4 million and $5.1 million at Saddlehorn and Red Bluff Express, respectively, due to higher volumes and (ii) $4.4 million at Mont Belvieu JV from a load-reduction electricity credit received in the second quarter of 2021 related to winter storm Uri.

Cost of Product and Operation and Maintenance Expenses


		Three Months Ended						Nine Months Ended							Three Months Ended						Six Months Ended

thousands except percentages	thousands except percentages	September 30, 2021		June 30, 2021		Inc/ (Dec)		September 30, 2021		September 30, 2020		Inc/ (Dec)		thousands except percentages	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
Residue purchases	Residue purchases	$	32,123	$	23,019	40	%	$	113,046	$	43,998	157	%	Residue purchases	$	65,168	$	34,992	86	%	$	100,160	$	77,682	29	%
NGLs purchases	NGLs purchases	51,440		42,305		22	%	124,664		111,809		11	%	NGLs purchases	102,650		70,404		46	%	173,054		73,219		136	%
Other	Other	(331)		12,720		(103)	%	12,535		(2,196)		NM		Other	(19,262)		(32,548)		(41)	%	(51,810)		16,112		NM
Cost of product	Cost of product	83,232		78,044		7	%	250,245		153,611		63	%	Cost of product	148,556		72,848		104	%	221,404		167,013		33	%
Operation and maintenance	Operation and maintenance	140,838		153,028		(8)	%	434,198		436,670		(1)	%	Operation and maintenance	168,153		128,976		30	%	297,129		293,360		1	%
Total Cost of product and Operation and maintenance expenses	Total Cost of product and Operation and maintenance expenses	$	224,070	$	231,072	(3)	%	$	684,443	$	590,281	16	%	Total Cost of product and Operation and maintenance expenses	$	316,709	$	201,824	57	%	$	518,533	$	460,373	13	%

NM—Not meaningful

Residue purchases

Residue purchases increased by ~~$9.1~~$30.2 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of (i) ~~$4.0~~$25.6 million at the West Texas complex attributable to ~~an increase in average prices and~~increased volumes purchased and average prices, as well as a change in contract mix, and (ii) ~~$2.2~~$2.6 million at the MGR assets attributable to ~~an increase in~~increased volumes purchased and average prices.

Residue purchases increased by ~~$69.0~~$22.5 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of ~~$45.4~~(i) $17.1 million at the West Texas complex ~~$7.7~~attributable to increased volumes purchased and average prices, as well as a change in contract mix during the second quarter of 2022, and (ii) $5.8 million at the ~~Chipeta~~DJ Basin complex ~~$6.6 million at the MGR assets, $5.4 million at the Granger complex, and $5.3 million at the Hilight system~~ attributable to ~~increases in~~increased volumes purchased and average prices. ~~These increases were offset partially by a decrease of $5.2 million resulting from a change in accounting for the marketing contracts with AESC effective April 1, 2020 (see~~ ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2).~~

NGLs purchases

NGLs purchases increased by ~~$9.1~~$32.2 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of (i) ~~$5.5~~$23.1 million at the West Texas complex attributable to increased volumes purchased and average prices, as well as a change in contract mix, and (ii) $10.1 million at the DJ Basin complex due to a change in contract mix.

NGLs purchases increased by $99.8 million for the six months ended June 30, 2022, primarily due to increases of (i) $52.9 million at the West Texas complex attributable to increased volumes purchased and average prices, as well as a change in contract mix during the second quarter of 2022, and (ii) $34.3 million at the DJ Basin complex attributable to ~~an increase in~~increased average prices and ~~(ii) $2.2~~a change in contract mix during the second quarter of 2022, and (iii) $5.7 million at the Chipeta complex attributable to ~~an increase in~~increased average ~~prices and volumes purchased.~~

NGLs purchases increased by $12.9 million for the nine months ended September 30, 2021, primarily due to increases of $31.5 million at the West Texas complex, $24.7 million at the DJ Basin complex, $9.4 million at the Chipeta complex, and $5.8 million at the Granger complex attributable to increases in average prices. ~~These increases were offset partially by a decrease of $61.1 million resulting from a change in accounting for the marketing contracts with AESC effective April 1, 2020 (see~~ ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2).~~

Other items

Other items ~~decreased~~increased by ~~$13.1~~$13.3 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~decreases~~an increase of ~~$8.1~~$20.8 million at the West Texas complex ~~and $3.1~~attributable to changes in imbalance positions, partially offset by a decrease of $7.9 million at the DJ Basin complex ~~primarily~~ attributable to changes in imbalance positions.

Other items ~~increased~~decreased by ~~$14.7~~$67.9 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~an increase~~decreases of ~~$31.2~~$40.8 million and $31.6 million at the West Texas ~~complex,~~and DJ Basin complexes, respectively, attributable to changes in imbalance positions. The decreases were offset partially ~~offset~~ by ~~a decrease~~an increase of ~~$16.7~~$3.8 million at the ~~DJ Basin complex, both primarily~~MGR assets attributable to changes in imbalance positions.

Operation and maintenance expense

Operation and maintenance expense increased by $39.2 million for the three months ended June 30, 2022, primarily due to increases of (i) $13.4 million attributable to higher utility expense, (ii) $8.4 million due to higher maintenance and repair expense, (iii) $5.8 million in regulatory and environmental expense, and (iv) $3.8 million in contract labor and consulting expense.

Table of Contents

Operation and maintenance expense

~~Operation and maintenance expense decreased~~ increased by ~~$12.2~~$3.8 million for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~decreases~~increases of (i) ~~$5.9~~$8.0 million ~~at the West Texas complex attributable to reduced utilities expense and surface maintenance and plant repairs and (ii) $4.8 million at the DJ Basin complex~~ due to an ~~environmental liability of~~increase in chemicals and treating services, (ii) $6.1 million attributable to land related costs, and (iii) $4.1 million ~~recorded in the second quarter of 2021.~~

~~Operation and maintenance expense decreased by $2.5 million for the nine months ended September 30, 2021, primarily~~ due to ~~decreases of (i) $7.5 million at the West Texas complex, primarily attributable to reduced salaries and wages, surface~~higher maintenance and plant repairs, and safety expense; partially offset by increased utilities expense primarily resulting from the impact of winter storm Uri, (ii) $5.8 million at the DJ Basin complex attributable to reduced surface maintenance and plant repairs, and (iii) $3.8 million at the DBM water systems attributable to lower disposal fees resulting from reduced volumes and lower surface-use fees, partially offset by increased utilities expense and surface maintenance and plant repairs, including the impact of winter storm Uri.repair expense. These ~~decreases~~increases were offset partially by ~~an increase~~decreases of ~~$10.2~~(i) $9.1 million ~~at the DBM oil system, primarily~~ attributable to ~~increases in field-related expenses, chemicals~~lower contract labor and ~~treating services, and~~consulting expense, (ii) $7.6 million attributable to lower utilities expense, ~~primarily resulting from the impact of winter storm Uri.~~and (iii) $5.0 million attributable to lower field area costs.

Other Operating Expenses


		Three Months Ended						Nine Months Ended							Three Months Ended						Six Months Ended

thousands except percentages	thousands except percentages	September 30, 2021		June 30, 2021		Inc/ (Dec)		September 30, 2021		September 30, 2020		Inc/ (Dec)		thousands except percentages	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
General and administrative	General and administrative	$	50,409	$	44,448	13	%	$	139,973	$	118,466	18	%	General and administrative	$	47,848	$	48,602	(2)	%	$	96,450	$	89,564	8	%
Property and other taxes	Property and other taxes	13,641		17,967		(24)	%	45,992		57,263		(20)	%	Property and other taxes	22,662		18,442		23	%	41,104		32,351		27	%
Depreciation and amortization	Depreciation and amortization	139,002		137,849		1	%	407,404		384,688		6	%	Depreciation and amortization	139,036		134,582		3	%	273,618		268,402		2	%
Long-lived asset and other impairments	Long-lived asset and other impairments	1,594		12,738		(87)	%	29,198		200,575		(85)	%	Long-lived asset and other impairments	90		—		100	%	90		27,604		(100)	%
Goodwill impairment		—		—		—	%	—		441,017		(100)	%

Total other operating expenses	Total other operating expenses	$	204,646	$	213,002	(4)	%	$	622,567	$	1,202,009	(48)	%	Total other operating expenses	$	209,636	$	201,626	4	%	$	411,262	$	417,921	(2)	%

General and administrative expenses

General and administrative expenses increased by ~~$6.0~~$6.9 million for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~increases~~an increase of ~~(i) $4.4~~$7.9 million in personnel costs, ~~and (ii) $2.0 million in contract and consulting costs.~~

~~General and administrative expenses increased by $21.5 million for the nine months ended September 30, 2021, primarily due to increases of (i) $16.2 million in personnel costs primarily related to~~including increased bonus-related ~~contributions under our~~expenses and other miscellaneous employee ~~savings plan and equity-based compensation expense, and (ii) $6.3 million in contract and consulting costs primarily related to information technology services and fees.~~expenses.

Property and other taxes

Property and other taxes ~~decreased~~increased by ~~$4.3~~$4.2 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to expected valuation increases at the DJ Basin complex.

Property and other taxes increased by $8.8 million for the six months ended June 30, 2022, primarily due to ad valorem tax ~~decreases~~increases and expected valuation increases at the ~~West Texas complex and DBM oil system due to favorable differences between actual and estimated tax payments related to the 2021 fiscal year.~~

Property and other taxes decreased by $11.3 million for the nine months ended September 30, 2021, primarily due to ad valorem tax decreases at the West Texas complex due to favorable differences between actual and estimated tax payments related to the 2020 fiscal year.DJ Basin complex.

~~Table of Contents~~

Depreciation and amortization expense

Depreciation and amortization expense increased by ~~$22.7~~$4.5 million for the ~~nine~~three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to increases of ~~(i) $16.9~~$2.3 million and $1.9 million at the ~~DJ Basin complex, primarily as a result of a change in estimate for asset retirement obligations~~Hilight system and MGR assets.

Depreciation and amortization expense increased by $5.2 million for the Third Creek gathering system in the comparative prior period, (ii) $7.1 million related to depreciation for capitalized information technology implementation costs related to the stand-up of WES as an independent organization, (iii) $6.3 million at the West Texas complex resulting from capital projects being placed into service, and (iv) $3.8 million at the Springfield systemsix months ended June 30, 2022, primarily due to (i) an ~~acceleration~~increase of ~~depreciation expense for revised service life assumptions. These increases were offset partially by decreases of (i) $13.4 million due to the sale of the Bison treating facility and (ii)~~ $3.3 million at a transportation asset in Southwest Wyoming primarily as a result of ~~downward~~a change in estimate for asset retirement ~~obligation revisions made~~obligations and (ii) an increase of $2.3 million resulting from capital projects being placed into service. These increases were offset partially by a net decrease in depreciation of $2.2 million at the ~~first quarter of 2021.~~Hilight system and MGR assets.

Long-lived asset and other impairment expense

Long-lived asset and other impairment expense for the ~~three~~six months ended June 30, 2021, was primarily due to (i) an $11.6 million other-than-temporary impairment of our investment in Ranch ~~Westex.~~

~~Long~~-~~lived asset~~Westex and ~~other impairment expense for the three months ended March 31, 2021, was primarily due to $13.5~~(ii) $14.0 million of impairments at the DJ Basin complex due to cancellation of projects.

~~Long~~-lived asset and other impairment expense for the nine months ended September 30, 2020, was primarily due to (i) $150.2 million of impairments for assets located in Wyoming and Utah, (ii) impairments of $14.8 million primarily at the DJ Basin complex, DBM water systems, and West Texas complex due to cancellation of projects, and (iii) impairments of rights-of-~~way for $6.2 million at the DJ Basin complex.~~

For further information on Long-lived asset and other impairment expense, see Note 8—Property, Plant, and Equipment in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

~~Goodwill impairment expense~~

~~During the three months ended March 31, 2020, an interim goodwill impairment test was performed due to significant unit~~-~~price declines triggered by the combined impacts from the global outbreak of COVID~~-~~19 and the oil~~-~~market disruption. As a result of the interim impairment test, a goodwill impairment of $441.0 million was recognized for the gathering and processing reporting unit. For additional information, see~~ ~~Note 9—Goodwill~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q.~~

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Interest ~~Income – Anadarko Note Receivable and Interest~~ Expense

Three Months Ended Nine Months Ended
thousands except percentages September 30, 2021 June 30,
2021 Inc/
(Dec) September 30, 2021 September 30, 2020 Inc/
(Dec)
Interest income – Anadarko note receivable $ — $ — — % $ — $ 11,736 (100) %
Third parties
Long-term and short-term debt
$ (90,913) $ (92,487) (2) % $ (279,122) $ (273,620) 2 %
Finance lease liabilities (218) (292) (25) % (808) (1,162) (30) %
Commitment fees and amortization of debt-related costs (3,147) (3,179) (1) % (9,664) (10,052) (4) %
Capitalized interest 1,021 668 53 % 2,554 6,066 (58) %
Related parties
Finance lease liabilities — — — % — (43) (100) %
Interest expense $ (93,257) $ (95,290) (2) % $ (287,040) $ (278,811) 3 %

~~Interest income~~

Interest income - Anadarko note receivable decreased by $11.7 million for the nine months ended September 30, 2021, due to the exchange of the Anadarko note receivable under the Unit Redemption Agreement in September 2020. See ~~Note 6—Related-Party Transactions~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q.~~



	Three Months Ended						Six Months Ended

thousands except percentages	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)



Long-term and short-term debt	$	(78,577)	$	(83,428)	(6)	%	$	(162,005)	$	(188,209)	(14)	%
Finance lease liabilities	(31)		(42)		(26)	%	(73)		(590)		(88)	%
Commitment fees and amortization of debt-related costs	(3,068)		(3,032)		1	%	(6,100)		(6,517)		(6)	%
Capitalized interest	904		1,047		(14)	%	1,951		1,533		27	%



Interest expense	$	(80,772)	$	(85,455)	(5)	%	$	(166,227)	$	(193,783)	(14)	%

Interest expense

Interest expense decreased by ~~$2.0~~$4.7 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~lower outstanding balances as a result~~the redemption of the ~~purchase and retirement of portions of certain~~total principal amount outstanding of the ~~senior notes.~~4.000% Senior Notes due 2022 during the second quarter of 2022.

Interest expense ~~increased~~decreased by ~~$8.2~~$27.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to decreases of (i) ~~$27.4~~$10.7 million primarily due to the redemption of ~~additional~~the total principal amount outstanding of the 4.000% Senior Notes due 2022 and 5.375% Senior Notes due 2021 during the second quarter of 2022 and first quarter of 2021, respectively, (ii) $8.1 million due to credit-rating related interest ~~incurred from higher effective interest rates resulting from credit~~-~~rating downgrades~~rate changes and a lower outstanding balance on the 3.100% Senior Notes due 2025, (iii) $6.4 million due to credit-rating related interest rate changes on the 4.050% Senior Notes due 2030 and 5.250% Senior Notes due 2050, and ~~(ii) a decrease of $3.5 million in capitalized interest due to decreased capital expenditures. These increases were offset partially by decreases of (i) $18.4~~(iv) $2.1 million due to a lower outstanding ~~balances~~balance on the ~~5.375%~~3.950% Senior Notes due ~~2021 that were called on March 1, 2021 and the purchase and retirement~~2025, a portion of ~~portions of certain of the senior notes~~which was repaid during the third quarter of ~~2021 and (ii) $3.9 million due to lower outstanding borrowings under the RCF in~~ 2021.

See Liquidity and Capital Resources—Debt and credit facilities within this Item 2.

Income Tax Expense (Benefit)


		Three Months Ended								Nine Months Ended									Three Months Ended								Six Months Ended

thousands except percentages	thousands except percentages	September 30, 2021			June 30, 2021			Inc/ (Dec)		September 30, 2021			September 30, 2020			Inc/ (Dec)		thousands except percentages	June 30, 2022			March 31, 2022			Inc/ (Dec)		June 30, 2022			June 30, 2021			Inc/ (Dec)
Income (loss) before income taxes	Income (loss) before income taxes	$	265,464		$	239,742		11	%	$	697,553		$	249,868		179	%	Income (loss) before income taxes	$	316,662		$	319,475		(1)	%	$	636,137		$	432,089		47	%
Income tax expense (benefit)	Income tax expense (benefit)	1,826			1,465			25	%	4,403			3,792			16	%	Income tax expense (benefit)	1,491			1,805			(17)	%	3,296			2,577			28	%
Effective tax rate	Effective tax rate	1		%	1		%			1		%	2		%			Effective tax rate	—		%	1		%			1		%	1		%

We are not a taxable entity for U.S. federal income tax purposes; therefore, our federal statutory rate is zero percent. However, income apportionable to Texas is subject to Texas margin tax.

For all periods presented, the variance from the federal statutory rate was primarily ~~was~~ due to our Texas margin tax liability.

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KEY PERFORMANCE METRICS


		Three Months Ended						Nine Months Ended							Three Months Ended						Six Months Ended

thousands except percentages and per-unit amounts	thousands except percentages and per-unit amounts	September 30, 2021		June 30, 2021		Inc/ (Dec)		September 30, 2021		September 30, 2020		Inc/ (Dec)		thousands except percentages and per-unit amounts	June 30, 2022		March 31, 2022		Inc/ (Dec)		June 30, 2022		June 30, 2021		Inc/ (Dec)
Adjusted gross margin for natural-gas assets	Adjusted gross margin for natural-gas assets	$	492,708	$	469,409	5	%	$	1,394,506	$	1,384,632	1	%	Adjusted gross margin for natural-gas assets	$	528,983	$	488,909	8	%	$	1,017,892	$	901,798	13	%
Adjusted gross margin for crude-oil and NGLs assets	Adjusted gross margin for crude-oil and NGLs assets	148,939		150,317		(1)	%	432,401		494,481		(13)	%	Adjusted gross margin for crude-oil and NGLs assets	155,686		148,247		5	%	303,933		283,462		7	%
Adjusted gross margin for produced-water assets	Adjusted gross margin for produced-water assets	63,760		57,510		11	%	170,360		190,688		(11)	%	Adjusted gross margin for produced-water assets	71,002		67,594		5	%	138,596		106,600		30	%
Adjusted gross margin	Adjusted gross margin	705,407		677,236		4	%	1,997,267		2,069,801		(4)	%	Adjusted gross margin	755,671		704,750		7	%	1,460,421		1,291,860		13	%
Per-Mcf Adjusted gross margin for natural-gas assets (1)	Per-Mcf Adjusted gross margin for natural-gas assets (1)	1.31		1.21		8	%	1.24		1.15		8	%	Per-Mcf Adjusted gross margin for natural-gas assets (1)	1.36		1.34		1	%	1.35		1.20		13	%
Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (2)	Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (2)	2.52		2.40		5	%	2.46		2.50		(2)	%	Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (2)	2.57		2.44		5	%	2.50		2.43		3	%
Per-Bbl Adjusted gross margin for produced-water assets (3)	Per-Bbl Adjusted gross margin for produced-water assets (3)	0.94		0.92		2	%	0.93		0.98		(5)	%	Per-Bbl Adjusted gross margin for produced-water assets (3)	0.90		1.00		(10)	%	0.95		0.92		3	%
Adjusted EBITDA	Adjusted EBITDA	531,580		491,126		8	%	1,465,816		1,546,386		(5)	%	Adjusted EBITDA	548,318		539,050		2	%	1,087,368		934,236		16	%
Free cash flow	Free cash flow	320,031		379,776		(16)	%	913,629		762,364		20	%	Free cash flow	372,107		200,342		86	%	572,449		591,598		(3)	%

(1)Average for period. Calculated as Adjusted gross margin for natural-gas assets, divided by total throughput (MMcf/d) attributable to WES for natural-gas assets.

(2)Average for period. Calculated as Adjusted gross margin for crude-oil and NGLs assets, divided by total throughput (MBbls/d) attributable to WES for crude-oil and NGLs assets.

(3)Average for period. Calculated as Adjusted gross margin for produced-water assets, divided by total throughput (MBbls/d) attributable to WES for produced-water assets.

Adjusted gross margin. We define Adjusted gross margin attributable to Western Midstream Partners, LP (“Adjusted gross margin”) as total revenues and other (less reimbursements for electricity-related expenses recorded as revenue), less cost of product, plus distributions from equity investments, and excluding the noncontrolling interest owners’ proportionate share of revenues and cost of product. We believe Adjusted gross margin is an important performance measure of our operations’ profitability and performance as compared to other companies in the midstream industry. Cost of product expenses include (i) costs associated with the purchase of natural gas and NGLs pursuant to our percent-of-proceeds, percent-of-product, and keep-whole contracts, (ii) costs associated with the valuation of gas and NGLs imbalances, and (iii) costs associated with our obligations under certain contracts to redeliver a volume of natural gas to shippers, which is thermally equivalent to condensate retained by us and sold to third parties. The electricity-related expenses included in our Adjusted gross margin definition relate to pass-through expenses that are reimbursed by certain customers (recorded as revenue with an offset recorded as Operation and maintenance expense).

To facilitate investor and industry analyst comparisons between us and our peers, we also disclose per-Mcf Adjusted gross margin for natural-gas assets, per-Bbl Adjusted gross margin for crude-oil and NGLs assets, and per-Bbl Adjusted gross margin for produced-water assets.

~~Table of Contents~~

Adjusted gross margin increased by ~~$28.2~~$50.9 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) strong plant performance and contract mix leading to increased product recoveries, coupled with high commodity prices and increased throughput at the West Texas complex, ~~and DBM water systems and~~ (ii) ~~revenue recorded in the third quarter of 2021 that was previously constrained (see~~ ~~Note 2—Revenue from Contracts with Customers~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q). These increases were offset partially by (i) a decrease in distributions from Mont Belvieu JV and (ii) decreased~~increased throughput at the DJ Basin ~~complex.~~complex and DBM oil system, (iii) increased distributions from equity investments, and (iv) increased throughput, partially offset by a decrease in deficiency fees, at the DBM water systems.

Adjusted gross margin ~~decreased~~increased by ~~$72.5~~$168.6 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) ~~decreased~~strong plant performance and contract mix leading to increased product recoveries, coupled with higher commodity prices and increased throughput ~~and lower lease revenue under the operating and maintenance agreement with Occidental~~ at the ~~DBM oil system, (ii) a decrease in distributions from Whitethorn LLC, (iii) decreased throughput and~~West Texas complex, partially offset by a lower average fee resulting from a cost-of-service rate redetermination effective January 1, ~~2021,~~2022, and (ii) increased throughput and deficiency fees at the DBM water systems ~~(iv) decreased throughput on certain fee-based contracts at the DJ Basin complex,~~ and (v) the expiration of a minimum-volume commitment contract in the fourth quarter of 2020 and decreased throughput at the Bison treating facility, which was sold to a third party during the second quarter of 2021.DBM oil system. These ~~decreases~~increases were offset partially by ~~(i) revenue recorded in the third quarter of 2021 that was previously constrained, (ii) higher average commodity prices at the MGR assets, and (iii) an increase~~a decrease in distributions from ~~Red Bluff Express and Saddlehorn.~~Whitethorn LLC.

Table of Contents

Per-Mcf Adjusted gross margin for natural-gas assets increased by ~~$0.10~~$0.02 for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~(i) revenue recorded in the third quarter of 2021 that was previously constrained at the Springfield gas-gathering system~~strong plant performance and ~~(ii)~~contract mix leading to increased product recoveries, coupled with high commodity prices and increased throughput at the West Texas complex, which has a ~~higher~~-~~than~~-~~average per~~-~~Mcf margin as compared to our other natural-gas assets. These increases were offset partially by decreased throughput at the DJ Basin complex, which has a higher~~-~~than~~-~~average per~~-~~Mcf~~higher-than-average per-Mcf margin as compared to our other natural-gas assets.

Per-Mcf Adjusted gross margin for natural-gas assets increased by ~~$0.09~~$0.15 for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~(i) a~~strong plant performance and contract mix leading to increased product recoveries, coupled with higher ~~cost~~-of-~~service rate effective January 1, 2021,~~commodity prices and increased throughput at the West Texas complex and (ii) revenue recorded in the third quarter of 2021 that was previously constrained at the Springfield gas-gathering system. These increases were offset partially by decreased throughput on certain fee-based contracts at the DJ Basin complex, which has a higher-than-average per-Mcf margin as compared to our other natural-gas assets.

Per-Bbl Adjusted gross margin for crude-oil and NGLs assets increased by ~~$0.12~~$0.13 for the three months ended ~~September~~June 30, ~~2021, primarily due to (i) revenue recorded in the third quarter of 2021 that was previously constrained and (ii) decreased volumes on the Whitethorn pipeline, which has a lower~~-~~than~~-~~average per~~-~~Bbl margin as compared to our other crude~~-oil and NGLs assets. These increases were offset partially by (i) lower lease revenue under the operating and maintenance agreement with Occidental at the DBM oil system and (ii) a decrease in distributions from Mont Belvieu JV.

~~Per~~-~~Bbl Adjusted gross margin for crude~~-~~oil and NGLs assets decreased by $0.04 for the nine months ended September 30, 2021,~~2022, primarily due to (i) decreased throughput and ~~lower lease revenue under~~increased distributions from the ~~operating~~Whitethorn and ~~maintenance agreement with Occidental~~Cactus II pipelines and (ii) increased throughput at the DBM oil system, which has a higher-than-average per-Bbl margin as compared to our other crude-oil and NGLs assets. These increases were offset partially by (i) increased throughput on FRP, which has a lower-than-average per-Bbl margin as compared to our other crude-oil and NGLs assets and (ii) a decrease in distributions from ~~FRP~~Mont Belvieu JV.

Per-Bbl Adjusted gross margin for crude-oil and ~~Cactus II. These decreases were~~NGLs assets increased by $0.07 for the six months ended June 30, 2022, primarily due to increased throughput and increased deficiency fees at the DBM oil system, which has a higher-than-average per-Bbl margin as compared to our other crude-oil and NGLs assets. This increase was offset partially by (i) increased throughput on FRP, which has a ~~higher cost~~lower-ofthan-~~service rate effective January 1, 2021, at the DJ Basin~~ average per-Bbl margin as compared to our other crude-oil ~~system~~and NGLs assets and (ii) ~~revenue recorded~~a decrease in distributions from Saddlehorn.

Per-Bbl Adjusted gross margin for produced-water assets decreased by $0.10 for the ~~third quarter of 2021 that was previously constrained.~~three months ended June 30, 2022, primarily due to a decrease in deficiency fees and contract mix.

Per-Bbl Adjusted gross margin for produced-water assets increased by ~~$0.02~~$0.03 for the ~~three~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~increased throughput on volumes with higher-than-average per-Bbl margins.~~

~~Per~~-~~Bbl Adjusted gross margin for produced~~-~~water assets decreased by $0.05 for the nine months ended September 30, 2021, primarily due to a lower average fee resulting from a cost~~-of-~~service rate redetermination effective January 1, 2021.~~deficiency fees recorded in 2022.

~~Table of Contents~~

Adjusted EBITDA. We define Adjusted EBITDA attributable to Western Midstream Partners, LP (“Adjusted EBITDA”) as net income (loss), plus (i) distributions from equity investments, (ii) non-cash equity-based compensation expense, (iii) interest expense, (iv) income tax expense, (v) depreciation and amortization, (vi) impairments, and (vii) other expense (including lower of cost or market inventory adjustments recorded in cost of product), less (i) gain (loss) on divestiture and other, net, (ii) gain (loss) on early extinguishment of debt, (iii) income from equity investments, (iv) interest income, (v) income tax benefit, (vi) other income, and (vii) the noncontrolling interest owners’ proportionate share of revenues and expenses. We believe the presentation of Adjusted EBITDA provides information useful to investors in assessing our financial condition and results of operations and that Adjusted EBITDA is a widely accepted financial indicator of a company’s ability to incur and service debt, fund capital expenditures, and make distributions. Adjusted EBITDA is a supplemental financial measure that management and external users of our consolidated financial statements, such as industry analysts, investors, commercial banks, and rating agencies, use, among other measures, to assess the following:

•our operating performance as compared to other publicly traded partnerships in the midstream industry, without regard to financing methods, capital structure, or historical cost basis;

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

•the viability of acquisitions and capital expenditures and the returns on investment of various investment opportunities.

Adjusted EBITDA increased by ~~$40.5~~$9.3 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~(i)~~ a ~~$44.7~~$118.1 million increase in total revenues and other and a $10.2 million increase in distributions from equity investments. These amounts were offset partially by (i) a $75.6 million increase in cost of product (net of lower of cost or market inventory adjustments), (ii) a ~~$12.2~~$39.2 million ~~decrease~~increase in operation and maintenance expenses, and (iii) a ~~$4.3~~$4.2 million ~~decrease~~increase in property taxes. ~~These amounts were~~

Adjusted EBITDA increased by $153.1 million for the six months ended June 30, 2022, primarily due to a $240.6 million increase in total revenues and other. This amount was offset partially by (i) ~~an $8.2~~a $54.3 million increase in cost of product (net of lower of cost or market inventory adjustments), (ii) a $10.3 million decrease in distributions from equity investments, ~~(ii)~~(iii) an $8.8 million increase in property taxes, and (iv) a ~~$6.1~~$6.0 million increase in general and administrative expenses excluding non-cash equity-based compensation ~~expense, and (iii) a $5.2 million increase in cost~~expense.

Table of ~~product (net of lower of cost or market inventory adjustments).~~Contents

Adjusted EBITDA decreased by $80.6 million for the nine months ended September 30, 2021, primarily due to (i) a $96.8 million increase in cost of product (net of lower of cost or market inventory adjustments), (ii) a $17.2 million increase in general and administrative expenses excluding non
-~~cash equity~~-based compensation expense, and (iii) a $14.7 million decrease in distributions from equity investments. These amounts were offset partially by (i) a $32.8 million increase in total revenues and other and (ii) an $11.3 million decrease in property taxes. The above-described variances in cost of product and total revenues and other include the impacts resulting from a change in accounting for the marketing contracts with AESC effective April 1, 2020, which had no net impact on Adjusted EBITDA (see ~~Executive Summary—Commodity purchase and sale agreements~~ ~~within this Item 2).~~

Free cash flow. We define “Free cash flow” as net cash provided by operating activities less total capital expenditures and contributions to equity investments, plus distributions from equity investments in excess of cumulative earnings. Management considers Free cash flow an appropriate metric for assessing capital discipline, cost efficiency, and balance-sheet strength. Although Free cash flow is the metric used to assess WES’s ability to make distributions to unitholders, this measure should not be viewed as indicative of the actual amount of cash that is available for distributions or planned for distributions for a given period. Instead, Free cash flow should be considered indicative of the amount of cash that is available for distributions, debt repayments, and other general partnership purposes.

Free cash flow ~~decreased~~increased by ~~$59.7~~$171.8 million for the three months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~a decrease~~(i) an increase of ~~$60.8~~$190.5 million in net cash provided by operating activities ~~partially offset by a decrease of $3.2 million in contributions~~related to ~~equity investments.~~

~~Free cash flow increased by $151.3 million for the nine months ended September 30, 2021, primarily due to (i) a decrease of $154.5 million in~~working capital ~~expenditures,~~fluctuations and timing, and (ii) a ~~decrease of $15.3 million in contributions to equity investments, and (iii) an $8.3~~$5.6 million increase in distributions from equity investments in excess of cumulative earnings. These amounts were offset partially by ~~a decrease~~an increase of ~~$26.9~~$23.4 million in capital expenditures.

Free cash flow decreased by $19.1 million for the six months ended June 30, 2022, primarily due to an increase of $51.4 million in capital expenditures, partially offset by (i) an increase of $29.8 million in net cash provided by operating ~~activities.~~activities and (ii) a $4.0 million increase in distributions from equity investments in excess of cumulative earnings.

See Capital Expenditures and Historical Cash Flow within this Item 2 for further information.

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Reconciliation of non-GAAP financial measures. Adjusted gross margin, Adjusted EBITDA, and Free cash flow are not defined in GAAP. The GAAP measure ~~used by us~~ that is most directly comparable to Adjusted gross margin is gross margin. Net income (loss) and net cash provided by operating activities are the GAAP measures ~~used by us~~ that are most directly comparable to Adjusted EBITDA. The GAAP measure ~~used by us~~ that is most directly comparable to Free cash flow is net cash provided by operating activities. Our non-GAAP financial measures of Adjusted gross margin, Adjusted EBITDA, and Free cash flow should not be considered as alternatives to the GAAP measures of gross margin, net income (loss), net cash provided by operating activities, or any other measure of financial performance presented in accordance with GAAP. Adjusted gross margin, Adjusted EBITDA, and Free cash flow have important limitations as analytical tools because they exclude some, but not all, items that affect gross margin, net income (loss), and net cash provided by operating activities. Adjusted gross margin, Adjusted EBITDA, and Free cash flow should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP. Our definitions of Adjusted gross margin, Adjusted EBITDA, and Free cash flow may not be comparable to similarly titled measures of other companies in our industry, thereby diminishing their utility as comparative measures.

Management compensates for the limitations of Adjusted gross margin, Adjusted EBITDA, and Free cash flow as analytical tools by reviewing the comparable GAAP measures, understanding the differences between Adjusted gross margin, Adjusted EBITDA, and Free cash flow compared to (as applicable) gross margin, net income (loss), and net cash provided by operating activities, and incorporating this knowledge into its decision-making processes. We believe that investors benefit from having access to the same financial measures that our management considers in evaluating our operating results.

The following tables present (i) a reconciliation of the GAAP financial measure of gross margin to the non-GAAP financial measure of Adjusted gross margin, (ii) a reconciliation of the GAAP financial measures of net income (loss) and net cash provided by operating activities to the non-GAAP financial measure of Adjusted EBITDA, and (iii) a reconciliation of the GAAP financial measure of net cash provided by operating activities to the non-GAAP financial measure of Free cash flow:


		Three Months Ended				Nine Months Ended				Three Months Ended				Six Months Ended

thousands	thousands	September 30, 2021		June 30, 2021		September 30, 2021		September 30, 2020			thousands	June 30, 2022		March 31, 2022		June 30, 2022		June 30, 2021
Reconciliation of Gross margin to Adjusted gross margin	Reconciliation of Gross margin to Adjusted gross margin										Reconciliation of Gross margin to Adjusted gross margin
Total revenues and other	Total revenues and other	$	763,840	$	719,131	$	2,157,945	$	2,125,112		Total revenues and other	$	876,419	$	758,297	$	1,634,716	$	1,394,105
Less:	Less:										Less:
Cost of product	Cost of product	83,232		78,044		250,245		153,611			Cost of product	148,556		72,848		221,404		167,013
Depreciation and amortization	Depreciation and amortization	139,002		137,849		407,404		384,688			Depreciation and amortization	139,036		134,582		273,618		268,402
Gross margin	Gross margin	541,606		503,238		1,500,296		1,586,813			Gross margin	588,827		550,867		1,139,694		958,690
Add:	Add:										Add:
Distributions from equity investments	Distributions from equity investments	62,711		70,947		194,847		209,566			Distributions from equity investments	66,016		55,795		121,811		132,136
Depreciation and amortization	Depreciation and amortization	139,002		137,849		407,404		384,688			Depreciation and amortization	139,036		134,582		273,618		268,402
Less:	Less:										Less:
Reimbursed electricity-related charges recorded as revenues	Reimbursed electricity-related charges recorded as revenues	19,725		17,585		54,622		61,100			Reimbursed electricity-related charges recorded as revenues	19,042		18,404		37,446		34,897
Adjusted gross margin attributable to noncontrolling interests (1)	Adjusted gross margin attributable to noncontrolling interests (1)	18,187		17,213		50,658		50,166			Adjusted gross margin attributable to noncontrolling interests (1)	19,166		18,090		37,256		32,471
Adjusted gross margin	Adjusted gross margin	$	705,407	$	677,236	$	1,997,267	$	2,069,801		Adjusted gross margin	$	755,671	$	704,750	$	1,460,421	$	1,291,860
Adjusted gross margin for natural-gas assets	Adjusted gross margin for natural-gas assets	$	492,708	$	469,409	$	1,394,506	$	1,384,632		Adjusted gross margin for natural-gas assets	$	528,983	$	488,909	$	1,017,892	$	901,798
Adjusted gross margin for crude-oil and NGLs assets	Adjusted gross margin for crude-oil and NGLs assets	148,939		150,317		432,401		494,481			Adjusted gross margin for crude-oil and NGLs assets	155,686		148,247		303,933		283,462
Adjusted gross margin for produced-water assets	Adjusted gross margin for produced-water assets	63,760		57,510		170,360		190,688			Adjusted gross margin for produced-water assets	71,002		67,594		138,596		106,600

(1)For all periods presented, includes (i) the 25% third-party interest in Chipeta and (ii) the 2.0% Occidental subsidiary-owned limited partner interest in WES Operating, which collectively represent WES’s noncontrolling interests.

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		Three Months Ended				Nine Months Ended					Three Months Ended				Six Months Ended

thousands	thousands	September 30, 2021		June 30, 2021		September 30, 2021		September 30, 2020				thousands	June 30, 2022		March 31, 2022		June 30, 2022		June 30, 2021
Reconciliation of Net income (loss) to Adjusted EBITDA	Reconciliation of Net income (loss) to Adjusted EBITDA									Reconciliation of Net income (loss) to Adjusted EBITDA
Net income (loss)	Net income (loss)	$	263,638	$	238,277	$	693,150	$	246,076			Net income (loss)	$	315,171	$	317,670	$	632,841	$	429,512
Add:	Add:											Add:
Distributions from equity investments	Distributions from equity investments	62,711		70,947		194,847		209,566				Distributions from equity investments	66,016		55,795		121,811		132,136
Non-cash equity-based compensation expense	Non-cash equity-based compensation expense	6,979		7,121		20,834		16,527				Non-cash equity-based compensation expense	7,038		7,743		14,781		13,855
Interest expense	Interest expense	93,257		95,290		287,040		278,811				Interest expense	80,772		85,455		166,227		193,783
Income tax expense	Income tax expense	1,826		1,465		4,403		8,072				Income tax expense	1,491		1,805		3,296		2,577
Depreciation and amortization	Depreciation and amortization	139,002		137,849		407,404		384,688				Depreciation and amortization	139,036		134,582		273,618		268,402
Impairments ~~(1)~~	Impairments ~~(1)~~	1,594		12,738		29,198		641,592				Impairments ~~(1)~~	90		—		90		27,604
Other expense	Other expense	4		30		1,252		1,953				Other expense	181		—		181		1,248
Less:	Less:											Less:
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(364)		1,225		278		(3,651)				Gain (loss) on divestiture and other, net	(1,150)		370		(780)		642
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	(24,655)		—		(24,944)		10,372				Gain (loss) on early extinguishment of debt	91		—		91		(289)
Equity income, net – related parties	Equity income, net – related parties	48,506		58,666		159,337		176,788				Equity income, net – related parties	48,464		49,607		98,071		110,831
Interest income – Anadarko note receivable		—		—		—		11,736

Other income	Other income	109		84		193		2,373				Other income	—		106		106		84
Income tax benefit		—		—		—		4,280

Adjusted EBITDA attributable to noncontrolling interests ~~(2)~~(1)	Adjusted EBITDA attributable to noncontrolling interests ~~(2)~~(1)	13,835		12,616		37,448		39,001				Adjusted EBITDA attributable to noncontrolling interests ~~(2)~~(1)	14,072		13,917		27,989		23,613
Adjusted EBITDA	Adjusted EBITDA	$	531,580	$	491,126	$	1,465,816	$	1,546,386			Adjusted EBITDA	$	548,318	$	539,050	$	1,087,368	$	934,236
Reconciliation of Net cash provided by operating activities to Adjusted EBITDA	Reconciliation of Net cash provided by operating activities to Adjusted EBITDA									Reconciliation of Net cash provided by operating activities to Adjusted EBITDA
Net cash provided by operating activities	Net cash provided by operating activities	$	391,333	$	452,111	$	1,104,994	$	1,131,893			Net cash provided by operating activities	$	466,981	$	276,458	$	743,439	$	713,661
Interest (income) expense, net	Interest (income) expense, net	93,257		95,290		287,040		267,075				Interest (income) expense, net	80,772		85,455		166,227		193,783

Accretion and amortization of long-term obligations, net	Accretion and amortization of long-term obligations, net	(1,871)		(1,914)		(5,873)		(6,482)				Accretion and amortization of long-term obligations, net	(1,804)		(1,782)		(3,586)		(4,002)
Current income tax expense (benefit)	Current income tax expense (benefit)	824		749		2,128		1,399				Current income tax expense (benefit)	703		673		1,376		1,304
Other (income) expense, net	Other (income) expense, net	(110)		(84)		1,013		(612)				Other (income) expense, net	45		(106)		(61)		1,123
Cash paid to settle interest-rate swaps		—		—		—		19,181

Distributions from equity investments in excess of cumulative earnings – related parties	Distributions from equity investments in excess of cumulative earnings – related parties	8,702		9,232		30,075		21,750				Distributions from equity investments in excess of cumulative earnings – related parties	15,482		9,925		25,407		21,373
Changes in assets and liabilities:	Changes in assets and liabilities:											Changes in assets and liabilities:
Accounts receivable, net	Accounts receivable, net	61,609		38,982		130,773		192,338				Accounts receivable, net	114,696		165,134		279,830		69,164
Accounts and imbalance payables and accrued liabilities, net	Accounts and imbalance payables and accrued liabilities, net	(17,204)		(55,758)		(56,495)		(37,814)				Accounts and imbalance payables and accrued liabilities, net	(97,201)		14,292		(82,909)		(39,291)
Other items, net	Other items, net	8,875		(34,866)		9,609		(3,341)				Other items, net	(17,284)		2,918		(14,366)		734
Adjusted EBITDA attributable to noncontrolling interests (2)		(13,835)		(12,616)		(37,448)		(39,001)
Adjusted EBITDA attributable to noncontrolling interests (1)												Adjusted EBITDA attributable to noncontrolling interests (1)	(14,072)		(13,917)		(27,989)		(23,613)
Adjusted EBITDA	Adjusted EBITDA	$	531,580	$	491,126	$	1,465,816	$	1,546,386			Adjusted EBITDA	$	548,318	$	539,050	$	1,087,368	$	934,236
Cash flow information	Cash flow information									Cash flow information
Net cash provided by operating activities	Net cash provided by operating activities	$	391,333	$	452,111	$	1,104,994	$	1,131,893			Net cash provided by operating activities	$	466,981	$	276,458	$	743,439	$	713,661
Net cash used in investing activities	Net cash used in investing activities	(80,883)		(59,932)		(187,287)		(426,670)				Net cash used in investing activities	(99,330)		(71,617)		(170,947)		(106,404)
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(516,161)		(142,982)		(1,262,767)		(667,140)				Net cash provided by (used in) financing activities	(518,466)		(158,591)		(677,057)		(746,606)

(1)~~Includes goodwill impairment for the nine months ended September 30, 2020. See~~ ~~Note 9—Goodwill~~ ~~in the~~ ~~Notes to Consolidated Financial Statements~~ ~~under Part I, Item 1 of this Form 10-Q.~~

~~(2)~~For all periods presented, includes (i) the 25% third-party interest in Chipeta and (ii) the 2.0% Occidental subsidiary-owned limited partner interest in WES Operating, which collectively represent WES’s noncontrolling interests.

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		Three Months Ended				Nine Months Ended						Three Months Ended				Six Months Ended

thousands	thousands	September 30, 2021		June 30, 2021		September 30, 2021		September 30, 2020			thousands	June 30, 2022		March 31, 2022		June 30, 2022		June 30, 2021
Reconciliation of Net cash provided by operating activities to Free cash flow	Reconciliation of Net cash provided by operating activities to Free cash flow									Reconciliation of Net cash provided by operating activities to Free cash flow
Net cash provided by operating activities	Net cash provided by operating activities	$	391,333	$	452,111	$	1,104,994	$	1,131,893		Net cash provided by operating activities	$	466,981	$	276,458	$	743,439	$	713,661
Less:	Less:										Less:
Capital expenditures	Capital expenditures	79,829		78,145		217,757		372,262			Capital expenditures	107,386		83,971		191,357		139,928
Contributions to equity investments – related parties	Contributions to equity investments – related parties	175		3,422		3,683		19,017			Contributions to equity investments – related parties	2,970		2,070		5,040		3,508
Add:	Add:										Add:
Distributions from equity investments in excess of cumulative earnings – related parties	Distributions from equity investments in excess of cumulative earnings – related parties	8,702		9,232		30,075		21,750			Distributions from equity investments in excess of cumulative earnings – related parties	15,482		9,925		25,407		21,373
Free cash flow	Free cash flow	$	320,031	$	379,776	$	913,629	$	762,364		Free cash flow	$	372,107	$	200,342	$	572,449	$	591,598
Cash flow information	Cash flow information										Cash flow information
Net cash provided by operating activities	Net cash provided by operating activities	$	391,333	$	452,111	$	1,104,994	$	1,131,893		Net cash provided by operating activities	$	466,981	$	276,458	$	743,439	$	713,661
Net cash used in investing activities	Net cash used in investing activities	(80,883)		(59,932)		(187,287)		(426,670)			Net cash used in investing activities	(99,330)		(71,617)		(170,947)		(106,404)
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(516,161)		(142,982)		(1,262,767)		(667,140)			Net cash provided by (used in) financing activities	(518,466)		(158,591)		(677,057)		(746,606)

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LIQUIDITY AND CAPITAL RESOURCES

Our primary cash uses include ~~quarterly distributions,~~equity and debt service, customary operating expenses, and capital expenditures. Our sources of liquidity as of ~~September~~June 30, ~~2021,~~2022, included cash and cash equivalents, cash flows generated from operations, available borrowing capacity under the RCF, and potential issuances of additional equity or debt securities. We believe that cash flows generated from these sources will be sufficient to satisfy our short-term working capital requirements and long-term capital-expenditure and ~~debt service~~debt-service requirements. The amount of future distributions to unitholders will depend on our results of operations, financial condition, capital requirements, and other factors, and will be determined by the Board ~~of Directors~~ on a quarterly basis. We may rely on external financing sources, including equity and debt issuances, to fund capital expenditures and future acquisitions. However, we also may use operating cash flows to fund capital expenditures or acquisitions, which could result in borrowings under the RCF to ~~pay distributions~~fund equity or ~~to fund~~ other short-term working capital requirements.

Under our partnership agreement, we distribute all of our available cash (beyond proper reserves as defined in our partnership agreement) within 55 days following each quarter’s end. Our cash flow and resulting ability to make cash distributions are dependent on our ability to generate cash flow from operations. Generally, our available cash is our cash on hand at the end of a quarter after the payment of our expenses and the establishment of cash reserves and cash on hand resulting from working capital borrowings made after the end of the quarter. The general partner establishes cash reserves to provide for the proper conduct of our business, including (i) ~~reserves~~ to fund future capital expenditures, (ii) to comply with applicable laws, debt instruments, or other agreements, or (iii) to provide funds for unitholder distributions for any one or more of the next four quarters. We have made cash distributions to our unitholders each quarter since our initial public offering in 2012. The Board ~~of Directors~~ declared a cash distribution to unitholders for the ~~third~~second quarter of ~~2021~~2022 of ~~$0.32300~~$0.50000 per unit, or ~~$134.9~~$197.7 million in the aggregate. The cash distribution is payable on ~~November~~August 12, ~~2021,~~2022, to our unitholders of record at the close of business on ~~November~~August 1, ~~2021.~~2022.

In ~~November 2020,~~February 2022, we announced a buyback program of up to ~~$250.0 million~~$1.0 billion of our common units through December 31, ~~2021.~~2024. The common units may be purchased from time to time in the open market at prevailing market prices or in privately negotiated transactions. The timing and amount of purchases under the program will be determined based on ongoing assessments of capital needs, our financial performance, the market price of ~~the~~our common units, and other factors, including organic growth and acquisition opportunities and general market conditions. The program does not obligate us to purchase any specific dollar amount or number of units and may be suspended or discontinued at any time. During the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, we repurchased ~~5,586,419~~3,314,562 common units on the open market for an aggregate purchase price of ~~$104.4~~$79.2 million. WeFrom July 1, 2022, through July 29, 2022, we repurchased 13,800,805 common units, which includes 10,000,000 common units repurchased from Occidental, for an aggregate purchase price of $346.1 million. The units were canceled ~~the units~~ immediately upon receipt. AsInclusive of ~~September 30, 2021,~~the unit repurchases through July 29, 2022, we had an authorized amount of ~~$113.1~~$574.6 million remaining under the $1.0 billion Purchase Program.

Management continuously monitors our leverage position and coordinates our capital expenditures and ~~quarterly distributions~~equity requirements with expected cash inflows and projected ~~debt service~~debt-service requirements. We will continue to evaluate funding alternatives, including additional borrowings and the issuance of debt or equity securities, to secure funds as needed or to refinance maturing debt balances with longer-term debt issuances. Our ability to generate cash flows is subject to a number of factors, some of which are beyond our control. Read Risk Factors under Part II, Item 1A of this Form 10-Q.

Working capital. Working capital is an indication of liquidity and potential needs for short-term funding. Working capital requirements are driven by changes in accounts receivable and accounts payable and other factors such as credit extended to, and the timing of collections from, our customers, and the level and timing of our spending for acquisitions, maintenance, and other capital activities. As of ~~September~~June 30, ~~2021,~~2022, we had a ~~$550.6~~$108.8 million working capital ~~deficit,~~surplus, which we define as the amount by which current ~~liabilities~~assets exceed current assets. Our working capital deficit was primarily due to (i) the 4.000% Senior Notes due 2022 of $502.1 million and (ii) $220.0 million of outstanding borrowings under the RCF being classified as short-term debt on the consolidated balance sheet as of September 30, 2021.liabilities. As of ~~September~~June 30, ~~2021,~~2022, there was ~~$1.8~~$1.7 billion available for borrowing under the RCF. See Note ~~10—~~9—Selected Components of Working Capital and Note ~~11—~~10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

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Capital expenditures. Our business is capital intensive, requiring significant investment to maintain and improve existing facilities or to develop new midstream infrastructure. Capital expenditures ~~includes~~include maintenance capital expenditures, which include those expenditures required to maintain existing operating capacity and service capability of our assets, such as to replace system components and equipment that have been subject to significant use over time, become obsolete, or reached the end of their useful lives, to remain in compliance with regulatory or legal requirements, or to complete additional well connections to maintain existing system throughput and related cash flows; and expansion capital expenditures, which include expenditures to construct new midstream infrastructure and expenditures incurred to ~~extend the useful lives of our assets,~~ reduce costs, increase revenues, or increase system throughput or capacity from current ~~levels, including well connections that increase existing system throughput.~~levels.

Capital expenditures in the consolidated statements of cash flows reflect capital expenditures on a cash basis, when payments are made. Capital incurred is presented on an accrual basis. ~~Capital~~Acquisitions and capital expenditures as presented in the consolidated statements of cash flows and capital incurred were as follows:


		Nine Months Ended September 30,				Six Months Ended June 30,

thousands	thousands	2021		2020			thousands	2022		2021

Capital expenditures (1)	Capital expenditures (1)	$	217,757	$	372,262		Capital expenditures (1)	$	191,357	$	139,928
Capital incurred (1)	Capital incurred (1)	224,080		251,315			Capital incurred (1)	207,996		142,758

(1)For the ~~nine~~six months ended ~~September~~June 30, 2022 and 2021, ~~and 2020,~~ included ~~$2.6~~$2.0 million and ~~$6.1~~$1.5 million, respectively, of capitalized interest.

Capital expenditures ~~decreased~~increased by ~~$154.5~~$51.4 million for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to ~~decreases~~increases of (i) ~~$66.8~~$63.2 million at the West Texas complex primarily attributable to ~~decreases in~~ facility expansion and pipeline projects and (ii) $41.0 million at the DJ Basin complex primarily related to the completion of Latham Train II that commenced operations in the first quarter of 2020, and decreases in pipeline, well connection, and compression projects, (iii) $19.5$8.4 million at the DBM oil system primarily related to ~~the completion of the Loving ROTF Trains III and IV that commenced operations during the first and third quarters of 2020, respectively, and decreases~~an increase in pipeline, ~~and~~ well connection, ~~projects,~~oil treating, and ~~(iv) $11.0~~oil pumping projects. These increases were offset partially by decreases of (i) $8.4 million at the DBM water systems primarily due to reduced construction of additional water-disposal facilities and ~~gathering~~well connection projects and (ii) $4.4 million at the DJ Basin oil system primarily related to a decrease in pipeline projects.

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Historical cash flow. The following table and discussion present a summary of our net cash flows provided by (used in) operating, investing, and financing activities:


		Nine Months Ended September 30,					Six Months Ended June 30,

thousands	thousands	2021		2020		thousands	2022		2021
Net cash provided by (used in):	Net cash provided by (used in):					Net cash provided by (used in):
Operating activities	Operating activities	$	1,104,994	$	1,131,893	Operating activities	$	743,439	$	713,661
Investing activities	Investing activities	(187,287)		(426,670)		Investing activities	(170,947)		(106,404)
Financing activities	Financing activities	(1,262,767)		(667,140)		Financing activities	(677,057)		(746,606)
Net increase (decrease) in cash and cash equivalents	Net increase (decrease) in cash and cash equivalents	$	(345,060)	$	38,083	Net increase (decrease) in cash and cash equivalents	$	(104,565)	$	(139,349)

Operating activities. Net cash provided by operating activities ~~decreased~~increased for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily due to (i) ~~lower~~higher cash operating income and (ii) lower ~~distributions from equity investments, (iii) lower interest income, and (iv) higher~~ interest expense. These ~~decreases~~increases were partially offset ~~partially~~ by (i) the impact of changes in assets and liabilities and (ii) ~~cash paid during the nine months ended September 30, 2020, to settle interest-rate swaps.~~lower distributions from equity investments. Refer to Operating Results within this Item 2 for a discussion of our results of operations as compared to the prior ~~period.~~periods.

Investing activities. Net cash used in investing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily included the following:

•$~~217.8~~191.4 million of capital expenditures, primarily related to construction, expansion, and asset-integrity projects at the West Texas complex, DBM water systems, DJ Basin complex, and DBM oil system;

•$~~3.7~~5.0 million of capital contributions primarily paid to Red Bluff Express; and

•$25.4 million of distributions received from equity investments in excess of cumulative earnings.

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Net cash used in investing activities for the six months ended June 30, 2021, primarily included the following:

•$139.9 million of capital expenditures, primarily related to construction, expansion, and asset-integrity projects at the West Texas complex, DBM water systems, DJ Basin complex, and DBM oil system;

•$3.5 million of capital contributions primarily paid to Cactus II;

•$~~2.0 million of purchases from related parties;~~

•~~$30.1~~21.4 million of distributions received from equity investments in excess of cumulative earnings; ~~and~~

•$8.0 million related to the sale of the Bison treating ~~facility.~~

~~Net cash used in investing activities for the nine months ended September 30, 2020, included the following:~~

•~~$372.3 million of capital expenditures, primarily related to construction and expansion at the West Texas and DJ Basin complexes, DBM water systems, and DBM oil system;~~

•~~$57.1 million of increases to materials and supplies inventory;~~

•~~$19.0 million of capital contributions primarily paid to Cactus II and FRP for construction activities;~~facility; and

•$~~21.8~~7.7 million of ~~distributions received from equity investments in excess of cumulative earnings.~~decreases to materials and supplies inventory.

Financing activities. Net cash used in financing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2021,~~2022, primarily included the following:

•$~~521.9~~883.5 million to ~~purchase~~redeem the total principal amount outstanding of WES Operating’s 4.000% Senior Notes due 2022 and ~~retire~~repay borrowings under the RCF;

•$340.9 million of distributions paid to WES unitholders;

•$79.2 million of unit repurchases;

•$8.8 million of distributions paid to the noncontrolling interest owner of WES Operating;

•$3.2 million of distributions paid to the noncontrolling interest owner of Chipeta;

•$634.0 million of borrowings under the RCF, which were used for general partnership purposes and to redeem portions of certain of WES Operating’s senior ~~notes via a tender offer;~~notes; and

•$~~431.1~~13.0 million of increases in outstanding checks.

Net cash used in financing activities for the six months ended June 30, 2021, primarily included the following:

•$531.1 million to redeem the total principal amount outstanding of WES Operating’s 5.375% Senior Notes due ~~2021;~~2021 and repay borrowings under the RCF;

•$~~398.9~~264.2 million of distributions paid to WES unitholders;

•$~~180.0 million of repayments of outstanding borrowings under the RCF;~~

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•~~$104.4 million of unit repurchases;~~

•~~$11.8~~29.1 million of decreases in outstanding checks due mostly to ad valorem tax payments made at the end of 2020;

•$~~9.9~~16.2 million of unit repurchases;

•$5.3 million of distributions paid to the noncontrolling interest owner of WES Operating;

•$~~5.3~~3.6 million of finance lease payments;

•$~~2.7~~1.5 million of distributions paid to the noncontrolling interest owner of Chipeta;

•$~~400.0 million of borrowings under the RCF, which were used for general partnership purposes and to purchase and retire portions of certain of WES Operating’s senior notes via a tender offer; and~~

•~~$6.7 million of contributions from related parties.~~

~~Net cash used in financing activities for the nine months ended September 30, 2020, included the following:~~

•~~$3.0 billion of repayments of outstanding borrowings under the Term loan facility;~~

•~~$600.0 million of repayments of outstanding borrowings under the RCF;~~

•~~$563.6 million of distributions paid to WES unitholders;~~

•~~$180.4 million to purchase and retire portions of WES Operating’s 5.375% Senior Notes due 2021, 4.000% Senior Notes due 2022, and Floating-Rate Senior Notes via open~~-~~market repurchases;~~

•~~$12.2 million of finance lease payments;~~

•~~$11.5 million of distributions paid to the noncontrolling interest owner of WES Operating;~~

•~~$3.9 million of distributions paid to the noncontrolling interest owner of Chipeta;~~

•~~$3.5 billion of net proceeds from the Fixed~~-~~Rate Senior Notes and Floating~~-Rate Senior Notes issued in January 2020, which were used to repay the $3.0 billion outstanding borrowings under the Term loan facility, repay outstanding amounts under the RCF, and for general partnership purposes;

•~~$220.0~~100.0 million of borrowings under the RCF, which were used for general partnership purposes; and

•$~~20.0~~4.5 million of ~~a one~~-~~time cash contribution~~contributions from ~~Occidental received in January 2020, pursuant to the Services Agreement, for anticipated transition costs required to establish stand~~-~~alone human resources and information technology functions.~~related parties.

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Debt and credit facilities. As of ~~September~~June 30, ~~2021,~~2022, the carrying value of outstanding debt was ~~$7.1~~$6.7 billion. See Note ~~11—~~10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

WES Operating Senior Notes. In mid-January 2020, WES Operating issued the Fixed-Rate 3.100% Senior Notes due 2025, 4.050% Senior Notes due 2030, and 5.250% Senior Notes due 2050 and the Floating-Rate Senior Notes due 2023. Including the effects of the issuance prices, underwriting discounts, and interest-rate adjustments, the effective interest rates of the Senior Notes due 2025, 2030, and 2050, were ~~4.542%~~3.790%, ~~5.424%~~4.671%, and ~~6.629%~~5.869%, respectively, at ~~September~~June 30, ~~2021.~~2022. The interest rate on the Floating-Rate Senior Notes was ~~2.23%~~2.12% at ~~September~~June 30, ~~2021.~~2022. The effective interest rate of these notes is subject to adjustment from time to time due to a change in credit rating. In ~~August 2021,~~January 2022, Standard and Poor’s (“S&P”) upgraded WES Operating’s long-term debt from ~~“BB”~~“BB+” to ~~“BB+.~~“BBB-.” As a result of ~~the S&P~~this upgrade, annualized borrowing costs ~~will decrease~~decreased by $7.9 million.

During the ~~third~~second quarter of ~~2021,~~2022, WES Operating purchased and retired $500.0 million of certain of its senior notes via a tender offer. For the three months ended September 30, 2021, losses of $24.7 million were recognized for the early retirement of these notes. During the first quarter of 2021, WES Operating(i) redeemed the total principal amount outstanding of the ~~5.375% Senior Notes due 2021 at par value, pursuant to the optional redemption terms in WES Operating’s indenture.~~

~~As of September 30, 2021, the~~ 4.000% Senior Notes due 2022 at par value and (ii) purchased and retired $1.4 million of the 3.100% Senior Notes due 2025 via open-market repurchases.

As of June 30, 2022, the Floating-Rate Senior Notes were classified as ~~short-term~~long-term debt on the consolidated balance ~~sheet.~~sheet as WES Operating has the ability and intent to refinance these obligations using long-term debt. At ~~September~~June 30, ~~2021,~~2022, WES Operating was in compliance with all covenants under the relevant governing indentures.

We may, from time to time, seek to retire, rearrange, or amend some or all of our outstanding debt or debt agreements through cash purchases, exchanges, open-market repurchases, privately negotiated transactions, tender offers, or otherwise. Such transactions, if any, will depend on prevailing market conditions, our liquidity position and requirements, contractual restrictions, and other factors. The amounts involved may be material.

Revolving credit facility.In June 2022, WES ~~Operating’s~~Operating entered into an amendment to its $2.0 billion ~~senior unsecured revolving credit facility~~RCF, which is expandable to a maximum of $2.5 billion, to, among other things, (i) extend the maturity date applicable to the loans and ~~matures in~~commitments of certain lenders totaling $1.6 billion to February ~~2025~~2026, (ii) provide for ~~each extending lender.~~the ability of WES Operating to extend the maturity date by one year on up to two additional occasions, (iii) provide that loans under the RCF with a fixed interest rate for a specified period bear interest based on SOFR instead of LIBOR, and (iv) include an additional level of pricing if WES Operating’s senior unsecured debt rating is less than or equal to BB/Ba2/BB (S&P / Moody’s Investors Service / Fitch Ratings). The non-extending lender’s commitments mature in February ~~2024~~2025 and represent ~~$100.0~~$400.0 million out of $2.0 billion of total commitments from all lenders.

The RCF contains certain covenants that limit, among other things, WES Operating’s ability, and that of certain of its subsidiaries, to incur additional indebtedness, grant certain liens, merge, consolidate, or allow any material change in the character of its business, enter into certain related-party transactions and use proceeds other than for partnership purposes. The RCF also contains various customary covenants, certain events of default, and a maximum consolidated leverage ratio as of the end of each fiscal quarter (which is defined as the ratio of consolidated indebtedness as of the last day of a fiscal quarter to Consolidated EBITDA for the most-recent four-consecutive fiscal quarters ending on such day) of 5.0 to 1.0, or a consolidated leverage ratio of 5.5 to 1.0 with respect to quarters ending in the 270-day period immediately following certain acquisitions. As a result of certain covenants contained in the RCF, our capacity to borrow under the RCF may be limited. At September 30, 2021, WES Operating was in compliance with all covenants under the RCF. Any outstanding RCF borrowings are classified as short-term debt on the consolidated balance sheet due to management’s intent to repay within the next twelve months.

~~Finance lease liabilities.~~Offload commitments. During the ~~first quarter of 2020, WES~~six months ended June 30, 2022, we entered into ~~finance leases~~offload agreements with third parties ~~for equipment and vehicles extending~~providing firm-processing capacity through 2029. Certain equipment leases were amended during the third quarter of 2021 requiring reassessment of lease classification. As a result, these leases are now classified as operating leases resulting in a reduction of $19.6 million in Net property, plant, and equipment and $20.3 million in Short-term and Long-term debt. The operating leases resulted in additions of $4.8 million in Other assets, $3.1 million in Accrued liabilities, and $2.4 million in Other liabilities, on the consolidated balance sheet.2025. As of ~~September~~June 30, ~~2021,~~2022, we have future ~~lease~~minimum payments ~~of $1.3~~under offload agreements totaling $6.3 million for the remainder of ~~2021~~2022 and a total of ~~$5.4~~$29.3 million in years thereafter.

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Credit risk. We bear credit risk through exposure to non-payment or non-performance by our counterparties, including Occidental, financial institutions, customers, and other parties. Generally, non-payment or non-performance results from a customer’s inability to satisfy payables to us for services rendered, minimum-volume-commitment deficiency payments owed, or volumes owed pursuant to ~~gas~~-~~imbalance~~gas- or NGLs-imbalance agreements. We examine and monitor the creditworthiness of customers and may establish credit limits for customers. ~~A substantial portion of our throughput is sourced from producers, including Occidental, that recently received credit~~-~~rating downgrades.~~ We are subject to the risk of non-payment or late payment by producers for gathering, processing, transportation, and disposal fees. Additionally, we continue to evaluate counterparty credit risk and, in certain circumstances, are exercising our rights to request adequate assurance.

We expect our exposure to the concentrated risk of non-payment or non-performance to continue for as long as our commercial relationships with Occidental generate a significant portion of our revenues. While Occidental is our contracting counterparty, gathering and processing arrangements with affiliates of Occidental on most of our systems include not just Occidental-produced volumes, but also, in some instances, the volumes of other working-interest owners of Occidental who rely on our facilities and infrastructure to bring their volumes to market. ~~We also are party to agreements with Occidental under which Occidental is required to indemnify us for certain environmental claims, losses arising from rights~~-of-~~way claims, failures to obtain required consents or governmental permits, and income taxes with respect to the assets previously acquired from Anadarko.~~ See Note 6—Related-Party Transactions in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Our ability to make cash distributions to our unitholders may be adversely impacted if Occidental becomes unable to perform under the terms of gathering, processing, transportation, and disposal agreements; the contribution agreements; or the Services Agreement.

ITEMS AFFECTING THE COMPARABILITY OF FINANCIAL RESULTS WITH WES OPERATING

Our consolidated financial statements include the consolidated financial results of WES Operating. Our results of operations do not differ materially from the results of operations and cash flows of WES Operating, which are reconciled below.

Reconciliation of net income (loss). The differences between net income (loss) attributable to WES and WES Operating are reconciled as follows:


		Three Months Ended				Nine Months Ended				Three Months Ended				Six Months Ended

thousands	thousands	September 30, 2021		June 30, 2021		September 30, 2021		September 30, 2020			thousands	June 30, 2022		March 31, 2022		June 30, 2022		June 30, 2021
Net income (loss) attributable to WES	Net income (loss) attributable to WES	$	255,725	$	231,259	$	672,775	$	263,121		Net income (loss) attributable to WES	$	306,317	$	308,717	$	615,034	$	417,050
Limited partner interests in WES Operating not held by WES (1)	Limited partner interests in WES Operating not held by WES (1)	5,214		4,754		13,779		5,426			Limited partner interests in WES Operating not held by WES (1)	6,267		6,317		12,584		8,565
General and administrative expenses (2)	General and administrative expenses (2)	(280)		1,600		2,206		2,683			General and administrative expenses (2)	621		741		1,362		2,486
Other income (expense), net	Other income (expense), net	(4)		(2)		(9)		(6)			Other income (expense), net	(4)		(3)		(7)		(5)

Income taxes		3		—		3		—

Net income (loss) attributable to WES Operating	Net income (loss) attributable to WES Operating	$	260,658	$	237,611	$	688,754	$	271,224		Net income (loss) attributable to WES Operating	$	313,201	$	315,772	$	628,973	$	428,096

(1)Represents the portion of net income (loss) allocated to the limited partner interests in WES Operating not held by WES. A subsidiary of Occidental held a 2.0% limited partner interest in WES Operating for all periods presented.

(2)Represents general and administrative expenses incurred by WES separate from, and in addition to, those incurred by WES Operating.

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Reconciliation of net cash provided by (used in) operating and financing activities. The differences between net cash provided by (used in) operating and financing activities for WES and WES Operating are reconciled as follows:


		Nine Months Ended September 30,					Six Months Ended June 30,
thousands	thousands	2021		2020		thousands	2022		2021
WES net cash provided by operating activities	WES net cash provided by operating activities	$	1,104,994	$	1,131,893	WES net cash provided by operating activities	$	743,439	$	713,661
General and administrative expenses (1)	General and administrative expenses (1)	2,206		2,683		General and administrative expenses (1)	1,362		2,486
Non-cash equity-based compensation expense	Non-cash equity-based compensation expense	7,040		(5,372)		Non-cash equity-based compensation expense	(276)		7,169
Changes in working capital	Changes in working capital	(10,045)		4,774		Changes in working capital	(7,835)		(9,336)
Other income (expense), net	Other income (expense), net	(9)		(6)		Other income (expense), net	(7)		(5)
Income taxes		3		—

WES Operating net cash provided by operating activities	WES Operating net cash provided by operating activities	$	1,104,189	$	1,133,972	WES Operating net cash provided by operating activities	$	736,683	$	713,975

WES net cash provided by (used in) financing activities	WES net cash provided by (used in) financing activities	$	(1,262,767)	$	(667,140)	WES net cash provided by (used in) financing activities	$	(677,057)	$	(746,606)
Distributions to WES unitholders (2)	Distributions to WES unitholders (2)	398,896		563,579		Distributions to WES unitholders (2)	340,946		264,234
Distributions to WES from WES Operating (3)	Distributions to WES from WES Operating (3)	(486,621)		(565,577)		Distributions to WES from WES Operating (3)	(431,653)		(259,208)
Increase (decrease) in outstanding checks	Increase (decrease) in outstanding checks	58		316		Increase (decrease) in outstanding checks	104		(8)
Unit repurchases	Unit repurchases	104,366		—		Unit repurchases	79,217		16,241
Other	Other	3,492		—		Other	7,007		—

WES Operating net cash provided by (used in) financing activities	WES Operating net cash provided by (used in) financing activities	$	(1,242,576)	$	(668,822)	WES Operating net cash provided by (used in) financing activities	$	(681,436)	$	(725,347)

(1)Represents general and administrative expenses incurred by WES separate from, and in addition to, those incurred by WES Operating.

(2)Represents distributions to WES common unitholders paid under WES’s partnership agreement. See Note 4—Partnership Distributions and Note 5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

(3)Difference attributable to elimination in consolidation of WES Operating’s distributions on partnership interests owned by WES. See Note 4—Partnership Distributions and Note 5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Noncontrolling interest. WES Operating’s noncontrolling interest consists of the 25% third-party interest in Chipeta. See Note 1—Description of Business and Basis of Presentation in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

WES Operating distributions. WES Operating distributes all of its available cash on a quarterly basis to WES Operating unitholders in proportion to their share of limited partner interests in WES Operating. See Note 4—Partnership Distributions in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

CRITICAL ACCOUNTING ESTIMATES

The preparation of consolidated financial statements in accordance with GAAP requires management to make informed judgments and estimates that affect the amounts of assets and liabilities as of the date of the financial statements and the amounts of revenues and expenses recognized during the periods reported. There have been no significant changes to our critical accounting estimates from those disclosed in our annual report on Form 10-K for the fiscal year ended December 31, ~~2020.~~

2021.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity-price risk. Certain of our processing services are provided under percent-of-proceeds and keep-whole agreements. Under percent-of-proceeds agreements, we receive a specified percentage of the net proceeds from the sale of residue and/or NGLs. Under keep-whole agreements, we keep 100% of the NGLs produced, and the processed natural gas, or value of the natural gas, is returned to the producer, and because some of the gas is used and removed during processing, we compensate the producer for the amount of gas used and removed in processing by supplying additional gas or by paying an agreed-upon value for the gas used.

For the ~~nine~~six months ended ~~September~~June 30, ~~2021, 92%~~2022, 93% of our wellhead natural-gas volume (excluding equity investments) and 100% of our crude-oil and produced-water throughput (excluding equity investments) were serviced under fee-based contracts. A 10% increase or decrease in commodity prices would not have a material impact on our operating income (loss), financial condition, or cash flows for the next ~~twelve~~12 months, excluding the effect of the below-described imbalances.

We bear a limited degree of commodity-price risk with respect to settlement of natural-gas and NGLs imbalances that arise from differences in gas volumes received into our systems and gas volumes delivered by us to customers, and for instances where actual liquids recovery or fuel usage varies from contractually stipulated amounts. Natural-gas and NGLs volumes owed to or by us that are subject to monthly cash settlement are valued according to the terms of the contract as of the balance sheet dates and generally reflect market-index prices. Other natural-gas and NGLs volumes owed to or by us are valued at our weighted-average cost ~~of natural gas~~ as of the balance sheet dates and are settled in-kind. Our exposure to the impact of changes in commodity prices on outstanding imbalances depends on the settlement timing of the imbalances. See Outlook under Part I, Item 2 and Risk Factors under Part II, Item 1A of this Form 10-Q.

Interest-rate risk. The Federal Open Market Committee ~~decreased~~made no changes to its target range for the federal funds rate ~~twice~~ in ~~2020~~2021 and ~~as of September 30, 2021, there have been no changes to the~~increased its target range ~~in 2021.~~three times during the six months ended June 30, 2022. Any future increases in the federal funds rate likely will result in an increase in short-term financing costs. As of ~~September~~June 30, ~~2021,~~2022, we had (i) ~~$220.0~~$255.0 million of outstanding borrowings under the RCF that bear interest at a rate based on ~~LIBOR~~SOFR or an alternative base rate at WES Operating’s option, and (ii) the Floating-Rate Senior Notes that bear interest at a rate based on LIBOR. While a 10% change in the applicable benchmark interest rate would not materially impact interest expense on our outstanding borrowings, it would impact the fair value of the senior notes at ~~September~~June 30, ~~2021.~~2022. In addition, the transition from LIBOR to SOFR as a result of reference rate reform is not expected to materially impact interest expense on our outstanding borrowings.

Additional variable-rate debt may be issued in the future, either under the RCF or other financing sources, including commercial bank borrowings or debt issuances.

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures. The Chief Executive Officer and Chief Financial Officer of WES’s general partner and WES Operating GP (for purposes of this Item 4, “Management”) performed an evaluation of WES’s and WES Operating’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act. WES’s and WES Operating’s disclosure controls and procedures are designed to ensure that information required to be disclosed in the reports that are filed or submitted under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the rules and forms of the SEC, and to ensure that the information required to be disclosed in the reports that are filed or submitted under the Exchange Act is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, Management concluded that WES’s and WES Operating’s disclosure controls and procedures were effective as of ~~September~~June 30, ~~2021.~~2022.

Changes in Internal Control Over Financial Reporting. There were no changes in WES’s or WES Operating’s internal control over financial reporting during the quarter ended ~~September~~June 30, ~~2021,~~2022, that have materially affected, or are reasonably likely to materially affect, WES’s or WES Operating’s internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

On July 1, 2020, the U.S. Department of Justice, on behalf of the U.S. Environmental Protection Agency (the “EPA”), and the State of Colorado commenced an enforcement action in the United States District Court for the District of Colorado against Kerr-McGee Gathering LLC (“KMG”), a wholly owned subsidiary of WES, for alleged non-compliance with the leak detection and repair requirements of the federal Clean Air Act (“LDAR requirements”) at its Fort Lupton facility in the DJ Basin complex. KMG previously had been in negotiations with the EPA and the State of Colorado to resolve the alleged non-compliance at the Fort Lupton facility. Per the complaint, plaintiffs pray for injunctive relief, remedial action, and civil penalties. ~~Management cannot reasonably estimate the outcome of this action at this time.~~

~~On August 12, 2019, Sanchez Energy Corporation and certain of its affiliated companies (collectively, “Sanchez”) filed a voluntary petition for relief under Chapter 11~~We are currently exploring global resolution of the ~~U.S. Bankruptcy Code in~~claims. While such resolution would likely include an injunctive relief component and payment of a civil penalty, which may exceed the ~~United States Bankruptcy Court for~~disclosure threshold amount required by Item 103 of Regulation S-K, management believes the Southern District of Texas. While Sanchez holds a working interest in the acreage dedicated to our Springfield system, Sanchez also was the upstream operator for substantially all of the natural gas, crude oil, and NGLs that the Springfield system gathers and that WES processes in the Eagle Ford Shale Play. On April 29, 2020, we received notice that Sanchez filed a motion to reject a number of midstream and downstream agreements with commercial counterparties, including Sanchez’s Springfield gathering agreements and agreements obligating Sanchez to deliver the gas volumes gathered by the Springfield system to our Brasada processing plant. We objected to Sanchez’s rejection and instituted an adversary proceeding regarding such rejection. On May 6, 2021, the Bankruptcy Court issued an opinion determining, among other things, that Sanchez’s Springfield gathering agreements were rejected, but that such agreements contain covenants running with the land that survive rejection, thus preserving the acreage dedication to our Springfield system. We intend to continue defending our contractual rights in the bankruptcy proceeding and any other appropriate venue.

On May 15, 2020, Gavilan Resources LLC (“Gavilan”), an entity that owns a 25% working interest in the acreage where the Springfield gathering system and Brasada processing plant are located, also filed for Chapter 11 bankruptcy protection. As a part of this bankruptcy, Mesquite Energy, Inc. (the successor to Sanchez) (“Mesquite”) purchased Gavilan’s assets at auction. Gavilan did not assume and assign its agreements with Springfield as part of its asset sale. Instead, the assets sold to Mesquite remain subject to any covenants, servitudes, or similar agreements that could be equitable servitudes or covenants running with the land, pending a further order of the bankruptcy court.

The parties to the Sanchez and Gavilan proceedings discussed above are currently working toward a comprehensive legal and commercial settlement of the matters in dispute. Nevertheless, we cannot make any assurances regarding the ultimate outcomeresolution of these ~~negotiations or the Sanchez and Gavilan proceedings themselves, and any resulting~~claims will not have a material impact on ~~WES due to the uncertainties associated with the ongoing process.~~WES’s results of operations, cash flows, or financial condition.

On October 29, 2020, WGR Operating, LP (“WGR”), on behalf of itself and derivatively on behalf of Mont Belvieu JV, filed suit against Enterprise Products Operating, LLC (“Enterprise”) and Mont Belvieu JV (as a nominal defendant) in the District Court of Harris County, Texas. Our lawsuit seeks a declaratory judgment regarding proper revenue allocation as set forth in the Operating Agreement between Mont Belvieu JV (of which WGR is a 25% owner) and Enterprise (the “Operating Agreement”) related to fractionation trains at the Mont Belvieu complex in Chambers County, Texas. Specifically, the Operating Agreement sets forth a revenue allocation structure, whereby revenue would be allocated to the various fracs at the Mont Belvieu complex in sequential order, with Fracs VII and VIII (which are owned by Mont Belvieu JV) following Fracs I through VI, but preceding any “Later Frac Facilities.” Subsequent to the construction of Fracs VII and VIII, Enterprise built Fracs IX, X, and XI, which it wholly owns, and has signaled its intention to treat such subsequent fracs as outside the Mont Belvieu revenue allocation. We do not believe Enterprise’s attempt to bypass the agreed-to revenue allocation is proper under the parties’ agreements and now seek judicial determination. We currently sue only for declaratory judgment to avoid potential future damages. We cannot make any assurances regarding the ultimate outcome of this proceeding and its resulting impact on WGR or WES.

Except as discussed above, we are not a party to any legal, regulatory, or administrative proceedings other than proceedings arising in the ordinary course of business. Management believes that there are no such proceedings for which a final disposition could have a material adverse effect on results of operations, cash flows, or financial condition, or for which disclosure is otherwise required by Item 103 of Regulation S-K.

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Item 1A. Risk Factors

Security holders and potential investors in our securities should carefully consider the risk ~~factors~~factor included below and those set forth under Part I, Item 1A in our Form 10-K for the year ended December 31, ~~2020,~~2021, together with all of the other information included in this document, and in our other public filings, press releases, and public discussions with management. Additionally, for a full discussion of the risks associated with Occidental’s business, see Item 1A under Part I in Occidental’s Form 10-K for the year ended December 31, ~~2020,~~2021, Occidental’s quarterly reports on Form 10-Q and Occidental’s other public filings, press releases, and public discussions with Occidental management. We have identified the below risk factors as important factors that could cause our actual results to differ materially from those contained in any written or oral forward-looking statements made by us or on our behalf.

~~Because we are dependent on Occidental as our largest customer and the owner~~Certain of our ~~general partner, any development~~natural-gas processing agreements provide our producer customers with contractually specified NGL recoveries that, ~~materially~~under expected operating conditions, may generate commodity price exposure and ~~adversely affects Occidental’s operations,~~could, under certain circumstances, generate financial ~~condition,~~ or ~~market reputation could have a material and adverse impact on~~physical-delivery obligations for us. ~~Material adverse changes at Occidental could restrict our access to capital, make it more expensive to access the capital markets, or increase the costs~~

Under certain of our ~~borrowings.~~

~~We are dependent on Occidental as~~natural-gas processing agreements, we provide our largest customer and the owner of our general partner, and we expect to derive significant revenue from Occidental for the foreseeable future. As a result, any event, whether in our area of operations or otherwise, that adversely affects Occidental’s production, financial condition, leverage, market reputation, liquidity, results of operations, or cash flows may adversely affect our revenues and cash available for distribution. Accordingly, we are indirectly subject to the business risks of Occidental, including, but not limited to, the volatility of oil and natural-~~gas prices, the availability of capital on favorable terms to fund Occidental’s exploration and development activities, the political and economic uncertainties associated~~producer customers with ~~Occidental’s foreign operations, transportation~~-~~capacity constraints, and shareholder activism.~~

~~Further, we are subject to the risk of non~~-~~payment or non~~-performance by Occidental, including with respect to our gathering and transportation agreements. For example, we are currently involved in a dispute with Occidental regarding the calculation of the cost-of-service rate under a gathering contract related to our DJ Basin oil system. If such dispute is resolved in a manner adverse to us, such resolution could have a negative impact on our financial condition and results of operations, including a reduction in rates and a non-~~cash charge to earnings. In addition, we cannot predict~~contractually specified NGL recoveries. To the extent ~~to which Occidental’s business would be impacted if conditions in~~actual recoveries exceed the ~~energy industry were to deteriorate further, nor can~~contractually specified recoveries, we ~~estimate~~retain the ~~impact~~excess NGL volumes and sell such ~~conditions would have on Occidental’s ability to perform~~volumes for our own account along with NGL and natural-gas volumes retained by us under our ~~gathering~~percent-of-proceeds and ~~transportation~~keep-whole processing agreements, ~~with Occidental. Accordingly, any material non~~-~~payment or non~~-~~performance by Occidental~~bearing commodity-price risk on these volumes.

Conversely, if actual plant recoveries are below the contractually specified recoveries, we would still be obligated to deliver the contractually fixed amount of NGLs (or in some cases, the financial equivalent thereof) to such customers. For this reason, our inability to efficiently operate our natural-gas processing facilities could ~~reduce~~result in diminished NGL sale proceeds for our ~~ability to make distributions to our unitholders.~~

~~Any material limitations to our ability to access capital as a result of adverse changes at Occidental could limit our ability to obtain future financing on favorable terms, or at all,~~account, or could result in ~~increased financing costs in~~losses when we settle shortfalls between actual and contractually specified recoveries with our customers. Accordingly, the ~~future. Similarly, material adverse changes at Occidental~~failure to achieve operational plant efficiency to support the contractually specified recoveries could adversely impact our unit price, thereby limiting our ability to raise capital through equity issuances or debt financing, or adversely affect our ability to engage in or expand or pursue our business activities, and also prevent us from engaging in certain transactions that might otherwise be considered beneficial to us.

See Occidental’s reports filed under the Securities and Exchange Act of 1934, as amended, with the SEC (which are not, and shall not be deemed to be, incorporated by reference herein), for a full discussion of the risks associated with Occidental’s business.

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

The current U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative, or judicial interpretation at any time. From time to time, members of Congress propose and consider substantive changes to the existing U.S. federal income tax laws that would affect publicly traded partnerships. On April 21, 2021, Senator Wyden introduced the Clean Energy for America Act, which would eliminate the exception upon which we rely for our treatment as a publicly traded partnership for U.S. federal income tax purposes.

~~Table of Contents~~

Any modification to the U.S. federal income tax laws and interpretations thereof may or may not be retroactively applied and could make it more difficult or impossible to meet the exception for certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax purposes or increase the amount of taxes payable by unitholders in publicly traded partnerships. You are urged to consult with your own tax advisor with respect to the status of regulatory or administrative developments and proposals and their potential effect on your investment in our common units.

~~Our profitability may be negatively impacted by inflation in the cost of labor, materials, and services.~~

Although inflation in the United States has been relatively low in recent years, the U.S. economy could experience a significant inflationary effect from, among other things, supply chain disruptions caused by, or governmental stimulus or fiscal policies adopted in response to, the COVID-19 crisis. While we cannot predict any future trends in the rate of inflation, the global COVID-19 pandemic has brought unprecedented uncertainty to the near-term economic outlook. A significant increase in inflation would raise our costs for labor, materials and services, and to the extent we are unable to recover higher costs through our commercial agreements, would negatively impact our profitability and cash flows available for distribution to unitholders.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The following table sets forth information with respect to repurchases made by WES of its common units in the open market under the $1.0 billion Purchase Program during the ~~third~~second quarter of ~~2021:~~2022:

Period Total number of units purchased Average price paid per unit
Total number of units purchased as part of publicly announced plans or programs (1)
Approximate dollar value of units that may yet be purchased under the plans or programs (1)
July 1-31, 2021
— $ — — 201,224,786
August 1-31, 2021
1,608,154 19.21 1,608,154 170,339,655
September 1-30, 2021
2,862,457 20.00 2,862,457 113,099,523
Total 4,470,611 19.71 4,470,611


Period	Total number of units purchased	Average price paid per unit		Total number of units purchased as part of publicly announced plans or programs (1)	Approximate dollar value of units that may yet be purchased under the plans or programs (1)
April 1-30, 2022	—	$	—	—	$	994,851,000
May 1-31, 2022	300,100	26.16		300,100	987,000,000
June 1-30, 2022	2,789,107	23.74		2,789,107	920,783,000
Total	3,089,207	23.98		3,089,207

(1)In ~~November 2020,~~February 2022, WES announced the $1.0 billion Purchase Program, pursuant to which we may purchase up to ~~$250.0 million~~$1.0 billion in aggregate value of our common units through December 31, ~~2021.~~2024. See Note 5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional details.

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Item 6. Exhibits

Exhibits designated by an asterisk (*) are filed herewith and those designated with asterisks (**) are furnished herewith; all exhibits not so designated are incorporated herein by reference to a prior filing as indicated.

Exhibit Index


Exhibit Number			Description
#	2.	1	Contribution Agreement and Agreement and Plan of Merger, dated as of November 7, 2018, by and among Anadarko Petroleum Corporation, Anadarko E&P Onshore LLC, APC Midstream Holdings, LLC, Western Gas Equity Partners, LP, Western Gas Equity Holdings, LLC, Western Gas Partners, LP, Western Gas Holdings, LLC, Clarity Merger Sub, LLC, WGR Asset Holding Company LLC, WGR Operating, LP, Kerr-McGee Gathering LLC, Kerr-McGee Worldwide Corporation and Delaware Basin Midstream, LLC (incorporated by reference to Exhibit 2.1 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on November 8, 2018, File No. 001-35753).
	3.	1	Certificate of Limited Partnership of Western Gas Equity Partners, LP (incorporated by reference to Exhibit 3.1 to the Registration Statement on Form S-1 of Western Gas Equity Partners, LP filed on November 5, 2012, File No. 333-184763).
	3.	2	Certificate of Amendment to Certificate of Limited Partnership of Western Gas Equity Partners, LP, effective as of February 28, 2019 (incorporated by reference to Exhibit 3.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	3	Second Amended and Restated Agreement of Limited Partnership of Western Midstream Partners, LP, dated as of December 31, 2019 (incorporated by reference to Exhibit 3.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on January 6, 2020, File No. 001-35753).
	3.	4	Certificate of Formation of Western Gas Equity Holdings, LLC (incorporated by reference to Exhibit 3.3 to Western Gas Equity Partners, LP’s Registration Statement on Form S-1 filed on November 5, 2012, File No. 333-184763).
	3.	5	Certificate of Amendment to Certificate of Formation of Western Gas Equity Holdings, LLC, effective as of February 28, 2019 (incorporated by reference to Exhibit 3.2 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	6	Second Amended and Restated Limited Liability Company Agreement of Western Midstream Holdings, LLC, dated as of February 28, 2019 (incorporated by reference to Exhibit 3.7 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	7	Amendment No. 1 to Second Amended and Restated Limited Liability Company Agreement of Western Midstream Holdings, LLC, dated February 28, 2019 (incorporated by reference to Exhibit 3.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on March 26, 2019, File No. 001-35753).
	3.	8	Certificate of Limited Partnership of Western Gas Partners, LP (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Registration Statement on Form S-1 filed on October 15, 2007, File No. 333-146700).
	3.	9	Third Amended and Restated Agreement of Limited Partnership of Western Midstream Operating, LP, dated as of February 28, 2019 (incorporated by reference to Exhibit 3.5 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	10	Certificate of Formation of Western Gas Holdings, LLC (incorporated by reference to Exhibit 3.3 to Western Gas Partners, LP’s Registration Statement on Form S-1 filed on October 15, 2007, File No. 333-146700).
	3.	11	Certificate of Amendment to Certificate of Formation of Western Gas Holdings, LLC, effective as of February 28, 2019 (incorporated by reference to Exhibit 3.4 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	12	Third Amended and Restated Limited Liability Company Agreement of Western Midstream Operating GP, LLC, dated as of February 28, 2019 (incorporated by reference to Exhibit 3.8 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	13	Certificate of Merger of Clarity Merger Sub, LLC with and into Western Gas Partners, LP, effective as of February 28, 2019 (incorporated by reference to Exhibit 3.3 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).

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Exhibit
Number Description
4. 1
Specimen Unit Certificate for the Common Units (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Quarterly Report on Form 10-Q filed on June 13, 2008, File No. 001-34046).
4. 2
Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 3
First Supplemental Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 4
Form of 5.375% Senior Notes due 2021 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A to Exhibit 4.2, to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 5
Fourth Supplemental Indenture, dated as of June 28, 2012, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).
4. 6
Form of 4.000% Senior Notes due 2022 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).
4. 7
Sixth Supplemental Indenture, dated as of March 20, 2014, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
4. 8
Form of 5.450% Senior Notes due 2044 (incorporated by reference to Exhibit 4.4, which is included as Exhibit A to Exhibit 4.2, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
4. 9
Seventh Supplemental Indenture, dated as of June 4, 2015, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
4. 10
Form of 3.950% Senior Notes due 2025 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
4. 11
Eighth Supplemental Indenture, dated as of July 12, 2016, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
4. 12
Form of 4.650% Senior Notes due 2026 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
4. 13
Ninth Supplemental Indenture, dated as of March 2, 2018, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 14
Form of 4.500% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 15
Form of 5.300% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 16
Tenth Supplemental Indenture, dated as of August 9, 2018, by and between Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
4. 17
Form of 4.750% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
4. 18
Form of 5.500% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).


Exhibit Number			Description
	4.	1	Specimen Unit Certificate for the Common Units (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Quarterly Report on Form 10-Q filed on June 13, 2008, File No. 001-34046).
	4.	2	Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
	4.	3	First Supplemental Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
	4.	4	Fourth Supplemental Indenture, dated as of June 28, 2012, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).
	4.	5	Form of 4.000% Senior Notes due 2022 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).
	4.	6	Sixth Supplemental Indenture, dated as of March 20, 2014, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
	4.	7	Form of 5.450% Senior Notes due 2044 (incorporated by reference to Exhibit 4.4, which is included as Exhibit A to Exhibit 4.2, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
	4.	8	Seventh Supplemental Indenture, dated as of June 4, 2015, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
	4.	9	Form of 3.950% Senior Notes due 2025 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
	4.	10	Eighth Supplemental Indenture, dated as of July 12, 2016, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
	4.	11	Form of 4.650% Senior Notes due 2026 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
	4.	12	Ninth Supplemental Indenture, dated as of March 2, 2018, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
	4.	13	Form of 4.500% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
	4.	14	Form of 5.300% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
	4.	15	Tenth Supplemental Indenture, dated as of August 9, 2018, by and between Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
	4.	16	Form of 4.750% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
	4.	17	Form of 5.500% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
	4.	18	Eleventh Supplemental Indenture, dated as of January 13, 2020, by and between Western Midstream Operating, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

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Exhibit
Number

Description

Exhibit
Number

Description

Eleventh Supplemental Indenture, dated as of January 13, 2020, by and between Western Midstream Operating, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

Form of Floating Rate Senior Notes due 2023 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

Form of 3.100% Senior Notes due 2025 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

Form of 4.050% Senior Notes due 2030 (incorporated by reference to Exhibit 4.4, which is included as Exhibit A-3 to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

Form of 5.250% Senior Notes due 2050 (incorporated by reference to Exhibit 4.5, which is included as Exhibit A-4 to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on January 13, 2020, File No. 001-34046).

10.

Third Amendment to Third Amended and Restated Revolving Credit Agreement, dated as of June 14, 2022, among Western Midstream Operating, LP (f/k/a Western Gas Partners, LP), as the Borrower, Wells Fargo Bank, National Association, as Administrative Agent, and the Lenders party thereto (incorporated by reference to Exhibit 10.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on June 21, 2022, File No. 001-35753).

31.

Certification of Chief Executive Officer and Chief Financial Officer, pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Western Midstream Partners, LP.

31.

Certification of Chief Executive Officer, pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Western Midstream Partners, LP.

31.

Certification of Chief Financial Officer, pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Western Midstream Partners, LP.

31.

Certification of Chief Executive Officer, pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Western Midstream Operating, LP.

31.

Certification of Chief Financial Officer, pursuant to Rule 13a-14(a)/15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 - Western Midstream Operating, LP.

32.

Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 - Western Midstream Partners, LP.

32.

101.

INS

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.

INS

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 Schema Document

101.

SCH

Inline XBRL Schema Document

101.

CAL

Inline XBRL Calculation Linkbase Document

101.

CAL

Inline XBRL Calculation Linkbase Document

101.

DEF

Inline XBRL Definition Linkbase Document

101.

DEF

Inline XBRL Definition Linkbase Document

101.

LAB

Inline XBRL Label Linkbase Document

101.

LAB

Inline XBRL Label Linkbase Document

101.

PRE

Inline XBRL Presentation Linkbase Document

101.

PRE

Inline XBRL Presentation Linkbase Document

104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

104

Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)




#			Pursuant to Item 601(b)(2) of Regulation S-K, the registrant agrees to furnish supplementally a copy of any omitted schedule to the Securities and Exchange Commission upon request.

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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, hereunto duly authorized.


			WESTERN MIDSTREAM PARTNERS, LP

~~November 9, 2021~~August 3, 2022
			/s/ Michael P. Ure
			Michael P. Ure President and Chief Executive Officer Western Midstream Holdings, LLC (as general partner of Western Midstream Partners, LP)

August 3, 2022
			/s/ Kristen S. Shults
			Kristen S. Shults Senior Vice President and Chief Financial Officer Western Midstream Holdings, LLC (as general partner of Western Midstream Partners, LP)






			WESTERN MIDSTREAM OPERATING, LP

~~November 9, 2021~~August 3, 2022
			/s/ Michael P. Ure
			Michael P. Ure President ~~Chief Executive Officer~~ and Chief ~~Financial~~Executive Officer Western Midstream Operating GP, LLC (as general partner of Western Midstream Operating, LP)

August 3, 2022
			/s/ Kristen S. Shults
			Kristen S. Shults Senior Vice President and Chief Financial Officer Western Midstream Operating GP, LLC (as general partner of Western Midstream Operating, LP)

7364