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 ~~June~~September 30, 2023


☐			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 ~~August 3,~~October 26, 2023:

Western Midstream Partners, LP

Common units

WES

New York Stock Exchange

~~384,614,611~~379,516,369

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 ~~and six~~ ni ne months ended ~~June~~S eptember 30,, 2023 and 2022	6
		Consolidated Balance Sheets as of ~~June~~September 30 , 2023, and December 31, 2022	7
		Consolidated Statements of Equity and Partners’ Capital for the three and ~~and six~~ n i ne months ended ~~June~~September 30,, 2023 and 2022	8
		Consolidated Statements of Cash Flows for the n i ne ~~six~~ months ended ~~June~~September 3 0 ,30, 2023 and 2022	910
		Western Midstream Operating, LP
		Consolidated Statements of Operations for the three and ~~and six~~n i ne months ended ~~June~~September 30,, 2023 and 202 2	1011
		Consolidated Balance Sheets as of ~~June~~September 30 , 2023, and December 31, 2022	1112
		Consolidated Statements of Equity and Partners’ Capital for the three and ~~six~~n i ne months ended ~~June 30~~September ~~, 2023 and 2022~~	12
		~~Consolidated Statements of Cash Flows for the six months ended June~~ 30, 2023 and 2022	13
		Consolidated Statements of Cash Flows for the n i ne months ended September 30, 2023 and 2022	15
		Notes to Consolidated Financial Statements	1416
		Note 1. Description of Business and Basis of Presentation	1416
		Note 2. Revenue from Contracts with Customers	1719
		Note 3. Acquisitions and Divestitures	21
		Note 4 . Partnership Distributions	21
		Note 5 . Equity and Partners’ Capital	23
		Note 6 . Related-Party Transactions	24
		Note 7 . Equity Investments	28
		Note 8 . Property, Plant, and Equipment	29

		Note ~~3. Partnership Distributions~~	199
		~~Note 4. Equity and Partners’ Capital~~	21
		~~Note 5. Related-Party Transactions~~	22
		~~Note 6. Equity Investments~~	26
		~~Note 7. Property, Plant, and Equipment~~	27

		~~Note 8.~~. Selected Components of Working Capital	2830
		Note 9.10 . Debt and Interest Expense	29
		~~Note 10. Commitments and Contingencies~~	31
		Note 1 1 . Commitments and Contingencies	33
		Note 1 2 . Subsequent Events	34
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3235
		Cautionary Note Regarding Forward-Looking Statements	3235
		Executive Summary	3437
		Outlook	3640
		Acquisitions and Divestitures	3741

		Results of Operations	3741
		Operating Results	3741
		Reconciliation of Non-GAAP Financial Measures	4449
		Key Performance Metrics	4954
		Liquidity and Capital Resources	5055
		Items Affecting the Comparability of Financial Results with WES Operating	5560
		Critical Accounting Estimates	5661

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	5661
	Item 4.	Controls and Procedures	5762
	Item 5.	Other Information	5964
PART II		OTHER INFORMATION
	Item 1.	Legal Proceedings	5863
	Item 1A.	Risk Factors	5964
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	5964
	Item 6.	Exhibits	6065

COMMONLY USED ABBREVIATIONS AND TERMS

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. The following list of abbreviations and terms are used in this document:


Defined Term						Definition
Anadarko						Anadarko Petroleum Corporation and its subsidiaries, excluding our general partner, which became a wholly owned subsidiary of Occidental on August 8, 2019.
Barrel, Bbl, Bbls/d, MBbls/d						42 U.S. gallons measured at 60 degrees Fahrenheit, barrels per day, thousand barrels per day.
Board						The board of directors of WES’s general partner.
Cactus II						Cactus II Pipeline LLC, in which we held a 15% interest that we sold in November 2022.
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.
DBM						Delaware Basin Midstream, LLC.
DBM water systems						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 Reconciliation of Non-GAAP Financial Measures under Part I, Item 2 of this Form 10-Q.
Exchange Act						The Securities Exchange Act of 1934, as amended.
FRP						Front Range Pipeline LLC, in which we own a 33.33% interest.
GAAP						Generally accepted accounting principles in the United States.
General partner						Western Midstream Holdings, LLC, the general partner of the Partnership.
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.
Marcellus Interest						The 33.75% interest in the Larry’s Creek, Seely, and Warrensville gas-gathering systems and related facilities located in northern Pennsylvania.
Mcf, MMcf, MMcf/d						Thousand cubic feet, million cubic feet, million cubic feet per day.
Meritage						Meritage Midstream Services II, LLC, which was acquired by the Partnership on October 13, 2023.
MGR						Mountain Gas Resources, LLC, includes the Red Desert complex and the Granger straddle plant.
Mi Vida						Mi Vida JV LLC, in which we own a 50% interest.
MLP						Master limited partnership.
~~Mcf, MMcf, MMcf/d~~						~~Thousand cubic feet, million cubic feet, million cubic feet per day.~~
Mont Belvieu JV						Enterprise EF78 LLC, in which we own a 25% interest.
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.
Occidental						Occidental Petroleum Corporation and, as the context requires, its subsidiaries, excluding our general partner.
Panola						Panola Pipeline Company, LLC, in which we own a 15% interest.
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.
Ranch Westex						Ranch Westex JV LLC, in which we owned a 50% interest through August 2022, and a 100% interest thereafter.
RCF						WES Operating’s $2.0 billion senior unsecured revolving credit facility.
Red Bluff Express						Red Bluff Express Pipeline, LLC, in which we own a 30% interest.
Related parties						Occidental, the Partnership’s equity interests (see Note 6—7—Equity Investments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q), and the Partnership and WES Operating for transactions that eliminate upon consolidation.
Rendezvous						Rendezvous Gas Services, LLC, in which we own a 22% interest.
Residue						The natural gas remaining after the unprocessed natural-gas stream has been processed or treated.
~~Saddlehorn~~						~~Saddlehorn Pipeline Company, LLC, in which we own a 20% interest.~~


Defined Term						Definition
Saddlehorn						Saddlehorn Pipeline Company, LLC, in which we own a 20% interest.
SEC						U.S. Securities and Exchange Commission.
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.
TEFR Interests						The interests in TEP, TEG, and FRP.
TEG						Texas Express Gathering LLC, in which we own a 20% interest.
TEP						Texas Express Pipeline LLC, in which we own a 20% interest.
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.
White Cliffs						White Cliffs Pipeline, LLC, in which we own a 10% interest.
Whitethorn LLC						Whitethorn Pipeline Company LLC, in which we own a 20% interest.
Whitethorn						A crude-oil and condensate pipeline, and related storage facilities, owned by Whitethorn LLC.
$1.25 billion Purchase Program						The $1.25 billion buyback program ending 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.

Table of Contents

PART I. FINANCIAL INFORMATION (UNAUDITED)

Item 1. Financial Statements

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands except per-unit amounts	thousands except per-unit amounts	2023		2022		2023		2022		thousands except per-unit amounts	2023		2022		2023		2022
Revenues and other	Revenues and other									Revenues and other
Service revenues – fee based	Service revenues – fee based	$	661,506	$	655,952	$	1,309,373	$	1,287,550	Service revenues – fee based	$	695,547	$	666,555	$	2,004,920	$	1,954,105
Service revenues – product based	Service revenues – product based	46,956		70,498		93,766		111,365		Service revenues – product based	48,446		91,356		142,212		202,721
Product sales	Product sales	29,659		149,736		68,684		235,325		Product sales	31,652		79,430		100,336		314,755
Other	Other	152		233		432		476		Other	368		227		800		703
Total revenues and other (1)	Total revenues and other (1)	738,273		876,419		1,472,255		1,634,716		Total revenues and other (1)	776,013		837,568		2,248,268		2,472,284
Equity income, net – related parties	Equity income, net – related parties	42,324		48,464		81,345		98,071		Equity income, net – related parties	35,494		41,317		116,839		139,388
Operating expenses	Operating expenses									Operating expenses
Cost of product	Cost of product	44,746		148,556		96,205		221,404		Cost of product	27,590		106,833		123,795		328,237
Operation and maintenance	Operation and maintenance	183,431		168,153		357,670		297,129		Operation and maintenance	204,434		190,514		562,104		487,643
General and administrative	General and administrative	53,405		47,848		104,522		96,450		General and administrative	55,050		48,185		159,572		144,635
Property and other taxes	Property and other taxes	18,547		22,662		25,378		41,104		Property and other taxes	14,583		19,390		39,961		60,494
Depreciation and amortization	Depreciation and amortization	143,492		139,036		288,118		273,618		Depreciation and amortization	147,363		156,837		435,481		430,455
Long-lived asset and other impairments (2)	Long-lived asset and other impairments (2)	234		90		52,635		90		Long-lived asset and other impairments (2)	245		4		52,880		94

Total operating expenses (3)	Total operating expenses (3)	443,855		526,345		924,528		929,795		Total operating expenses (3)	449,265		521,763		1,373,793		1,451,558
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(70)		(1,150)		(2,188)		(780)		Gain (loss) on divestiture and other, net	(1,480)		(104)		(3,668)		(884)
Operating income (loss)	Operating income (loss)	336,672		397,388		626,884		802,212		Operating income (loss)	360,762		357,018		987,646		1,159,230

Interest expense	Interest expense	(86,182)		(80,772)		(167,852)		(166,227)		Interest expense	(82,754)		(83,106)		(250,606)		(249,333)
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	6,813		91		6,813		91		Gain (loss) on early extinguishment of debt	8,565		—		15,378		91
Other income (expense), net	Other income (expense), net	2,872		(45)		4,087		61		Other income (expense), net	(1,270)		56		2,817		117
Income (loss) before income taxes	Income (loss) before income taxes	260,175		316,662		469,932		636,137		Income (loss) before income taxes	285,303		273,968		755,235		910,105
Income tax expense (benefit)	Income tax expense (benefit)	659		1,491		2,075		3,296		Income tax expense (benefit)	905		387		2,980		3,683
Net income (loss)	Net income (loss)	259,516		315,171		467,857		632,841		Net income (loss)	284,398		273,581		752,255		906,422
Net income (loss) attributable to noncontrolling interests	Net income (loss) attributable to noncontrolling interests	6,595		8,854		11,291		17,807		Net income (loss) attributable to noncontrolling interests	7,102		7,836		18,393		25,643
Net income (loss) attributable to Western Midstream Partners, LP	Net income (loss) attributable to Western Midstream Partners, LP	$	252,921	$	306,317	$	456,566	$	615,034	Net income (loss) attributable to Western Midstream Partners, LP	$	277,296	$	265,745	$	733,862	$	880,779
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	$	252,921	$	306,317	$	456,566	$	615,034	Net income (loss) attributable to Western Midstream Partners, LP	$	277,296	$	265,745	$	733,862	$	880,779

General partner interest in net (income) loss	General partner interest in net (income) loss	(5,821)		(6,767)		(10,507)		(13,550)		General partner interest in net (income) loss	(6,453)		(6,244)		(16,960)		(19,794)
Limited partners’ interest in net income (loss) (4)	Limited partners’ interest in net income (loss) (4)	247,100		299,550		446,059		601,484		Limited partners’ interest in net income (loss) (4)	270,843		259,501		716,902		860,985
Net income (loss) per common unit – basic (4)	Net income (loss) per common unit – basic (4)	$	0.64	$	0.74	$	1.16	$	1.49	Net income (loss) per common unit – basic (4)	$	0.71	$	0.67	$	1.87	$	2.16
Net income (loss) per common unit – diluted (4)	Net income (loss) per common unit – diluted (4)	$	0.64	$	0.74	$	1.16	$	1.49	Net income (loss) per common unit – diluted (4)	$	0.70	$	0.66	$	1.86	$	2.15
Weighted-average common units outstanding – basic (4)	Weighted-average common units outstanding – basic (4)	384,614		403,027		384,542		403,140		Weighted-average common units outstanding – basic (4)	383,561		388,906		384,211		398,343
Weighted-average common units outstanding – diluted (4)	Weighted-average common units outstanding – diluted (4)	385,510		404,162		385,665		404,280		Weighted-average common units outstanding – diluted (4)	384,772		390,318		385,344		399,545

(1)Total revenues and other includes related-party amounts of ~~$441.6~~$463.6 million and ~~$890.4 million~~$1.4 billion for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$456.8~~$476.5 million and ~~$885.5 million~~$1.4 billion for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. See Note 56.

(2)See Note 78.

(3)Total operating expenses includes related-party amounts of ~~$(14.1)~~$(35.8) million and ~~$(17.2)~~$(53.0) million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$(11.2)~~$(4.5) million and ~~$(28.8)~~$(33.3) million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively, all primarily related to changes in imbalance positions. See Note 56.

(4)See Note 4.5.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


thousands except number of units	thousands except number of units	June 30, 2023		December 31, 2022		thousands except number of units	September 30, 2023		December 31, 2022
ASSETS	ASSETS					ASSETS
Current assets	Current assets					Current assets
Cash and cash equivalents	Cash and cash equivalents	$	213,953	$	286,656	Cash and cash equivalents	$	489,494	$	286,656
Accounts receivable, net	Accounts receivable, net	554,222		554,263		Accounts receivable, net	614,836		554,263
Other current assets	Other current assets	29,028		59,506		Other current assets	31,476		59,506
Total current assets	Total current assets	797,203		900,425		Total current assets	1,135,806		900,425
Property, plant, and equipment	Property, plant, and equipment					Property, plant, and equipment
Cost	Cost	13,740,911		13,365,593		Cost	13,809,080		13,365,593
Less accumulated depreciation	Less accumulated depreciation	5,139,941		4,823,993		Less accumulated depreciation	5,144,678		4,823,993
Net property, plant, and equipment	Net property, plant, and equipment	8,600,970		8,541,600		Net property, plant, and equipment	8,664,402		8,541,600
Goodwill	Goodwill	4,783		4,783		Goodwill	4,783		4,783
Other intangible assets	Other intangible assets	697,241		713,075		Other intangible assets	689,324		713,075
Equity investments	Equity investments	920,123		944,696		Equity investments	915,076		944,696
Other assets (1)	Other assets (1)	198,630		167,049		Other assets (1)	217,163		167,049
Total assets (2)	Total assets (2)	$	11,218,950	$	11,271,628	Total assets (2)	$	11,626,554	$	11,271,628
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	$	359,298	$	360,562	Accounts and imbalance payables	$	393,358	$	360,562
Short-term debt	Short-term debt	2,532		215,780		Short-term debt	2,268		215,780
Accrued ad valorem taxes	Accrued ad valorem taxes	35,827		72,875		Accrued ad valorem taxes	50,291		72,875
Accrued liabilities	Accrued liabilities	223,887		254,640		Accrued liabilities	189,983		254,640
Total current liabilities	Total current liabilities	621,544		903,857		Total current liabilities	635,900		903,857
Long-term liabilities	Long-term liabilities					Long-term liabilities
Long-term debt	Long-term debt	6,824,214		6,569,582		Long-term debt	7,260,051		6,569,582
Deferred income taxes	Deferred income taxes	15,279		14,424		Deferred income taxes	15,378		14,424
Asset retirement obligations	Asset retirement obligations	301,975		290,021		Asset retirement obligations	307,945		290,021
Other liabilities	Other liabilities	433,775		385,629		Other liabilities	452,188		385,629
Total long-term liabilities	Total long-term liabilities	7,575,243		7,259,656		Total long-term liabilities	8,035,562		7,259,656
Total liabilities (3)	Total liabilities (3)	8,196,787		8,163,513		Total liabilities (3)	8,671,462		8,163,513
Equity and partners’ capital	Equity and partners’ capital					Equity and partners’ capital
Common units (384,613,934 and 384,070,984 units issued and outstanding at June 30, 2023, and December 31, 2022, respectively)		2,888,745		2,969,604
General partner units (9,060,641 units issued and outstanding at June 30, 2023, and December 31, 2022)		322		2,105
Common units (379,516,369 and 384,070,984 units issued and outstanding at September 30, 2023, and December 31, 2022, respectively)						Common units (379,516,369 and 384,070,984 units issued and outstanding at September 30, 2023, and December 31, 2022, respectively)	2,821,958		2,969,604
General partner units (9,060,641 units issued and outstanding at September 30, 2023, and December 31, 2022)						General partner units (9,060,641 units issued and outstanding at September 30, 2023, and December 31, 2022)	1,678		2,105
Total partners’ capital	Total partners’ capital	2,889,067		2,971,709		Total partners’ capital	2,823,636		2,971,709
Noncontrolling interests	Noncontrolling interests	133,096		136,406		Noncontrolling interests	131,456		136,406
Total equity and partners’ capital	Total equity and partners’ capital	3,022,163		3,108,115		Total equity and partners’ capital	2,955,092		3,108,115
Total liabilities, equity, and partners’ capital	Total liabilities, equity, and partners’ capital	$	11,218,950	$	11,271,628	Total liabilities, equity, and partners’ capital	$	11,626,554	$	11,271,628

(1)Other assets includes ~~$3.7 million and~~ $6.5 million of NGLs line-fill inventory as of ~~June~~September 30, 2023, and December 31, ~~2022, respectively.~~2022. Other assets also includes ~~$78.4~~$92.4 million and $60.4 million of materials and supplies inventory as of ~~June~~September 30, 2023, and December 31, 2022, respectively.

(2)Total assets includes related-party amounts of $1.3 billion as of ~~June~~September 30, 2023, and December 31, 2022, which includes related-party Accounts receivable, net of ~~$346.7~~$340.9 million and $313.9 million as of ~~June~~September 30, 2023, and December 31, 2022, respectively. See Note 56.

(3)Total liabilities includes related-party amounts of ~~$346.1~~$360.8 million and $312.3 million as of ~~June~~September 30, 2023, and December 31, 2022, respectively. See Note 56.

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, 2022	Balance at December 31, 2022	$	2,969,604	$	2,105	$	136,406	$	3,108,115	Balance at December 31, 2022	$	2,969,604	$	2,105	$	136,406	$	3,108,115
Net income (loss)	Net income (loss)	198,959		4,686		4,696		208,341		Net income (loss)	198,959		4,686		4,696		208,341
Distributions to Chipeta noncontrolling interest owner	Distributions to Chipeta noncontrolling interest owner	—		—		(2,240)		(2,240)		Distributions to Chipeta noncontrolling interest owner	—		—		(2,240)		(2,240)
Distributions to noncontrolling interest owner of WES Operating	Distributions to noncontrolling interest owner of WES Operating	—		—		(4,271)		(4,271)		Distributions to noncontrolling interest owner of WES Operating	—		—		(4,271)		(4,271)
Distributions to Partnership unitholders	Distributions to Partnership unitholders	(192,039)		(4,530)		—		(196,569)		Distributions to Partnership unitholders	(192,039)		(4,530)		—		(196,569)
Unit repurchases (1)	Unit repurchases (1)	(7,061)		—		—		(7,061)		Unit repurchases (1)	(7,061)		—		—		(7,061)

Equity-based compensation expense	Equity-based compensation expense	7,199		—		—		7,199		Equity-based compensation expense	7,199		—		—		7,199

Other	Other	(11,950)		—		—		(11,950)		Other	(11,950)		—		—		(11,950)
Balance at March 31, 2023	Balance at March 31, 2023	$	2,964,712	$	2,261	$	134,591	$	3,101,564	Balance at March 31, 2023	$	2,964,712	$	2,261	$	134,591	$	3,101,564
Net income (loss)	Net income (loss)	247,100		5,821		6,595		259,516		Net income (loss)	247,100		5,821		6,595		259,516
Distributions to Chipeta noncontrolling interest owner	Distributions to Chipeta noncontrolling interest owner	—		—		(1,230)		(1,230)		Distributions to Chipeta noncontrolling interest owner	—		—		(1,230)		(1,230)
Distributions to noncontrolling interest owner of WES Operating	Distributions to noncontrolling interest owner of WES Operating	—		—		(6,860)		(6,860)		Distributions to noncontrolling interest owner of WES Operating	—		—		(6,860)		(6,860)
Distributions to Partnership unitholders	Distributions to Partnership unitholders	(329,227)		(7,760)		—		(336,987)		Distributions to Partnership unitholders	(329,227)		(7,760)		—		(336,987)
Unit repurchases (1)	Unit repurchases (1)	(41)		—		—		(41)		Unit repurchases (1)	(41)		—		—		(41)

Equity-based compensation expense	Equity-based compensation expense	7,665		—		—		7,665		Equity-based compensation expense	7,665		—		—		7,665

Other	Other	(1,464)		—		—		(1,464)		Other	(1,464)		—		—		(1,464)
Balance at June 30, 2023	Balance at June 30, 2023	$	2,888,745	$	322	$	133,096	$	3,022,163	Balance at June 30, 2023	$	2,888,745	$	322	$	133,096	$	3,022,163
Net income (loss)										Net income (loss)	270,843		6,453		7,102		284,398
Distributions to Chipeta noncontrolling interest owner										Distributions to Chipeta noncontrolling interest owner	—		—		(1,613)		(1,613)
Distributions to noncontrolling interest owner of WES Operating										Distributions to noncontrolling interest owner of WES Operating	—		—		(7,129)		(7,129)
Distributions to Partnership unitholders										Distributions to Partnership unitholders	(216,345)		(5,097)		—		(221,442)
Unit repurchases (1)										Unit repurchases (1)	(127,500)		—		—		(127,500)

Equity-based compensation expense										Equity-based compensation expense	7,171		—		—		7,171

Other										Other	(956)		—		—		(956)
Balance at September 30, 2023										Balance at September 30, 2023	$	2,821,958	$	1,678	$	131,456	$	2,955,092

(1)See Note 4.

Partners’ Capital
thousands Common
Units General Partner
Units Noncontrolling
Interests Total
Balance at December 31, 2021 $ 2,966,955 $ (8,882) $ 137,687 $ 3,095,760
Net income (loss) 301,934 6,783 8,953 317,670
Distributions to Chipeta noncontrolling interest owner — — (1,984) (1,984)
Distributions to noncontrolling interest owner of WES Operating — — (2,805) (2,805)
Distributions to Partnership unitholders (131,786) (2,963) — (134,749)
Unit repurchases (1)
(5,149) — — (5,149)
Contributions of equity-based compensation from Occidental
1,949 — — 1,949
Equity-based compensation expense
5,794 — — 5,794
Net contributions from (distributions to) related parties 409 — — 409
Other (6,088) — — (6,088)
Balance at March 31, 2022 $ 3,134,018 $ (5,062) $ 141,851 $ 3,270,807
Net income (loss) 299,550 6,767 8,854 315,171
Distributions to Chipeta noncontrolling interest owner — — (1,198) (1,198)
Distributions to noncontrolling interest owner of WES Operating — — (6,007) (6,007)
Distributions to Partnership unitholders (201,667) (4,530) — (206,197)
Unit repurchases (1)
(74,068) — — (74,068)
Contributions of equity-based compensation from Occidental
241 — — 241
Equity-based compensation expense
6,797 — — 6,797
Net contributions from (distributions to) related parties 375 — — 375
Other (918) — — (918)
Balance at June 30, 2022 $ 3,164,328 $ (2,825) $ 143,500 $ 3,305,003

~~(1)See~~ ~~Note 4~~5.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

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

(UNAUDITED)

Six Months Ended
June 30,
thousands 2023 2022
Cash flows from operating activities
Net income (loss) $ 467,857 $ 632,841
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 288,118 273,618
Long-lived asset and other impairments
52,635 90
Non-cash equity-based compensation expense
14,864 14,781
Deferred income taxes 855 1,920
Accretion and amortization of long-term obligations, net
4,095 3,586
Equity income, net – related parties (81,345) (98,071)
Distributions from equity-investment earnings – related parties
82,871 96,404
(Gain) loss on divestiture and other, net 2,188 780
(Gain) loss on early extinguishment of debt (6,813) (91)
Other 399 136
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net 41 (279,830)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net (99,575) 82,909
Change in other items, net 67,057 14,366
Net cash provided by operating activities 793,247 743,439
Cash flows from investing activities
Capital expenditures (334,570) (191,357)
Contributions to equity investments – related parties (132) (5,040)
Distributions from equity investments in excess of cumulative earnings – related parties 23,179 25,407
Proceeds from the sale of assets to third parties — 1,096
(Increase) decrease in materials and supplies inventory and other (19,145) (1,053)
Net cash used in investing activities (330,668) (170,947)
Cash flows from financing activities
Borrowings, net of debt issuance costs 956,225 634,010
Repayments of debt (918,332) (883,548)
Increase (decrease) in outstanding checks (2,951) 13,038
Distributions to Partnership unitholders (1)
(533,556) (340,946)
Distributions to Chipeta noncontrolling interest owner (3,470) (3,182)
Distributions to noncontrolling interest owner of WES Operating (11,131) (8,812)
Net contributions from (distributions to) related parties — 784
Unit repurchases (7,102) (79,217)
Other (14,965) (9,184)
Net cash provided by (used in) financing activities (535,282) (677,057)
Net increase (decrease) in cash and cash equivalents (72,703) (104,565)
Cash and cash equivalents at beginning of period 286,656 201,999
Cash and cash equivalents at end of period $ 213,953 $ 97,434
Supplemental disclosures
Interest paid, net of capitalized interest $ 158,376 $ 181,790
Income taxes paid (reimbursements received) 1,271 905
Accrued capital expenditures 116,466 51,878


	Partners’ Capital
thousands	Common Units		General Partner Units		Noncontrolling Interests		Total


































Balance at December 31, 2021	$	2,966,955	$	(8,882)	$	137,687	$	3,095,760
Net income (loss)	301,934		6,783		8,953		317,670
Distributions to Chipeta noncontrolling interest owner	—		—		(1,984)		(1,984)
Distributions to noncontrolling interest owner of WES Operating	—		—		(2,805)		(2,805)
Distributions to Partnership unitholders	(131,786)		(2,963)		—		(134,749)
Unit repurchases (1)	(5,149)		—		—		(5,149)
Contributions of equity-based compensation from Occidental	1,949		—		—		1,949
Equity-based compensation expense	5,794		—		—		5,794
Net contributions from (distributions to) related parties	409		—		—		409
Other	(6,088)		—		—		(6,088)
Balance at March 31, 2022	$	3,134,018	$	(5,062)	$	141,851	$	3,270,807
Net income (loss)	299,550		6,767		8,854		315,171
Distributions to Chipeta noncontrolling interest owner	—		—		(1,198)		(1,198)
Distributions to noncontrolling interest owner of WES Operating	—		—		(6,007)		(6,007)
Distributions to Partnership unitholders	(201,667)		(4,530)		—		(206,197)
Unit repurchases (1)	(74,068)		—		—		(74,068)
Contributions of equity-based compensation from Occidental	241		—		—		241
Equity-based compensation expense	6,797		—		—		6,797
Net contributions from (distributions to) related parties	375		—		—		375
Other	(918)		—		—		(918)
Balance at June 30, 2022	$	3,164,328	$	(2,825)	$	143,500	$	3,305,003
Net income (loss)	259,501		6,244		7,836		273,581
Distributions to Chipeta noncontrolling interest owner	—		—		(1,838)		(1,838)
Distributions to noncontrolling interest owner of WES Operating	—		—		(11,365)		(11,365)
Distributions to Partnership unitholders	(193,213)		(4,531)		—		(197,744)
Unit repurchases (1)	(367,858)		—		—		(367,858)
Contributions of equity-based compensation from Occidental	81		—		—		81
Equity-based compensation expense	6,383		—		—		6,383
Net contributions from (distributions to) related parties	377		—		—		377
Other	(934)		—		—		(934)
Balance at September 30, 2022	$	2,868,665	$	(1,112)	$	138,133	$	3,005,686

(1)~~Includes related-party amounts.~~ See Note 5.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM ~~OPERATING,~~PARTNERS, LP

CONSOLIDATED STATEMENTS OF ~~OPERATIONS~~CASH FLOWS

(UNAUDITED)

Three Months Ended
June 30, Six Months Ended
June 30,
thousands 2023 2022 2023 2022
Revenues and other
Service revenues – fee based $ 661,506 $ 655,952 $ 1,309,373 $ 1,287,550
Service revenues – product based 46,956 70,498 93,766 111,365
Product sales 29,659 149,736 68,684 235,325
Other 152 233 432 476
Total revenues and other (1)
738,273 876,419 1,472,255 1,634,716
Equity income, net – related parties 42,324 48,464 81,345 98,071
Operating expenses
Cost of product 44,746 148,556 96,205 221,404
Operation and maintenance 183,431 168,153 357,670 297,129
General and administrative 52,219 47,227 103,104 95,088
Property and other taxes 18,547 22,662 25,378 41,104
Depreciation and amortization 143,492 139,036 288,118 273,618
Long-lived asset and other impairments (2)
234 90 52,635 90
Total operating expenses (3)
442,669 525,724 923,110 928,433
Gain (loss) on divestiture and other, net (70) (1,150) (2,188) (780)
Operating income (loss) 337,858 398,009 628,302 803,574
Interest expense (86,182) (80,772) (167,852) (166,227)
Gain (loss) on early extinguishment of debt 6,813 91 6,813 91
Other income (expense), net 2,743 (49) 3,933 54
Income (loss) before income taxes 261,232 317,279 471,196 637,492
Income tax expense (benefit) 659 1,491 2,075 3,296
Net income (loss) 260,573 315,788 469,121 634,196
Net income (loss) attributable to noncontrolling interest 1,410 2,587 1,945 5,223
Net income (loss) attributable to Western Midstream Operating, LP $ 259,163 $ 313,201 $ 467,176 $ 628,973



	Nine Months Ended September 30,
thousands	2023		2022
Cash flows from operating activities
Net income (loss)	$	752,255	$	906,422
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	435,481		430,455
Long-lived asset and other impairments	52,880		94

Non-cash equity-based compensation expense	22,035		21,245
Deferred income taxes	954		1,757
Accretion and amortization of long-term obligations, net	5,977		5,359
Equity income, net – related parties	(116,839)		(139,388)
Distributions from equity-investment earnings – related parties	115,897		139,710
(Gain) loss on divestiture and other, net	3,668		884
(Gain) loss on early extinguishment of debt	(15,378)		(91)

Other	371		299
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	(60,573)		(212,955)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	(87,040)		65,069
Change in other items, net	78,346		(6,653)
Net cash provided by operating activities	1,188,034		1,212,207
Cash flows from investing activities
Capital expenditures	(536,427)		(341,505)

Acquisitions from third parties	—		(41,018)
Contributions to equity investments – related parties	(1,153)		(8,899)
Distributions from equity investments in excess of cumulative earnings – related parties	31,715		41,058

Proceeds from the sale of assets to third parties	(60)		1,111
(Increase) decrease in materials and supplies inventory and other	(32,659)		(6,999)
Net cash used in investing activities	(538,584)		(356,252)
Cash flows from financing activities
Borrowings, net of debt issuance costs	1,801,011		1,389,010
Repayments of debt	(1,317,928)		(1,268,548)
Increase (decrease) in outstanding checks	(241)		1,459
Distributions to Partnership unitholders (1)	(754,998)		(538,690)
Distributions to Chipeta noncontrolling interest owner	(5,083)		(5,020)
Distributions to noncontrolling interest owner of WES Operating	(18,260)		(20,177)
Net contributions from (distributions to) related parties	—		1,161
Unit repurchases (1)	(134,602)		(447,075)
Other	(16,511)		(10,981)
Net cash provided by (used in) financing activities	(446,612)		(898,861)
Net increase (decrease) in cash and cash equivalents	202,838		(42,906)
Cash and cash equivalents at beginning of period	286,656		201,999
Cash and cash equivalents at end of period	$	489,494	$	159,093
Supplemental disclosures
Interest paid, net of capitalized interest	$	278,283	$	314,192
Income taxes paid (reimbursements received)	1,271		905
Accrued capital expenditures	112,150		71,955

(1)~~Total revenues and other includes~~Includes related-party amounts of $441.6 million and $890.4 million for the three and six months ended June 30, 2023, respectively, and $456.8 million and $885.5 million for the three and six months ended June 30, 2022, respectively.amounts. See Note 5.

~~(2)See~~ ~~Note 7~~.

~~(3)~~Total operating expenses includes related-party amounts of $(13.4) million and $(15.3) million for the three and six months ended June 30, 2023, respectively, and $(10.5) million and $(27.2) million for the three and six months ended June 30, 2022, respectively, all primarily related to changes in imbalance positions. See ~~Note 5~~6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED ~~BALANCE SHEETS~~STATEMENTS OF OPERATIONS

(UNAUDITED)

thousands except number of units June 30,
2023 December 31,
2022
ASSETS
Current assets
Cash and cash equivalents $ 208,844 $ 286,101
Accounts receivable, net 554,202 554,263
Other current assets 27,696 57,291
Total current assets 790,742 897,655
Property, plant, and equipment
Cost 13,740,911 13,365,593
Less accumulated depreciation 5,139,941 4,823,993
Net property, plant, and equipment 8,600,970 8,541,600
Goodwill 4,783 4,783
Other intangible assets 697,241 713,075
Equity investments 920,123 944,696
Other assets (1)
196,875 166,450
Total assets (2)
$ 11,210,734 $ 11,268,259
LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables $ 367,132 $ 404,468
Short-term debt
2,532 215,780
Accrued ad valorem taxes 35,827 72,875
Accrued liabilities 187,828 197,289
Total current liabilities 593,319 890,412
Long-term liabilities
Long-term debt
6,824,214 6,569,582
Deferred income taxes 15,279 14,424
Asset retirement obligations 301,975 290,021
Other liabilities 432,020 383,713
Total long-term liabilities
7,573,488 7,257,740
Total liabilities (3)
8,166,807 8,148,152
Equity and partners’ capital
Common units (318,675,578 units issued and outstanding at June 30, 2023, and December 31, 2022) 3,017,357 3,092,012
Total partners’ capital 3,017,357 3,092,012
Noncontrolling interest 26,570 28,095
Total equity and partners’ capital 3,043,927 3,120,107
Total liabilities, equity, and partners’ capital $ 11,210,734 $ 11,268,259



	Three Months Ended September 30,				Nine Months Ended September 30,
thousands	2023		2022		2023		2022
Revenues and other
Service revenues – fee based	$	695,547	$	666,555	$	2,004,920	$	1,954,105
Service revenues – product based	48,446		91,356		142,212		202,721
Product sales	31,652		79,430		100,336		314,755
Other	368		227		800		703
Total revenues and other (1)	776,013		837,568		2,248,268		2,472,284
Equity income, net – related parties	35,494		41,317		116,839		139,388
Operating expenses
Cost of product	27,590		106,833		123,795		328,237
Operation and maintenance	204,434		190,514		562,104		487,643
General and administrative	54,541		47,783		157,645		142,871
Property and other taxes	14,583		19,390		39,961		60,494
Depreciation and amortization	147,363		156,837		435,481		430,455
Long-lived asset and other impairments (2)	245		4		52,880		94

Total operating expenses (3)	448,756		521,361		1,371,866		1,449,794
Gain (loss) on divestiture and other, net	(1,480)		(104)		(3,668)		(884)
Operating income (loss)	361,271		357,420		989,573		1,160,994

Interest expense	(82,754)		(83,106)		(250,606)		(249,333)
Gain (loss) on early extinguishment of debt	8,565		—		15,378		91
Other income (expense), net	(1,330)		45		2,603		99
Income (loss) before income taxes	285,752		274,359		756,948		911,851
Income tax expense (benefit)	905		387		2,980		3,683
Net income (loss)	284,847		273,972		753,968		908,168
Net income (loss) attributable to noncontrolling interest	1,432		2,404		3,377		7,627
Net income (loss) attributable to Western Midstream Operating, LP	$	283,415	$	271,568	$	750,591	$	900,541

(1)~~Other assets~~Total revenues and other includes ~~$3.7~~related-party amounts of $463.6 million and ~~$6.5 million of NGLs line~~-~~fill inventory as of June~~$1.4 billion for the three and nine months ended September 30, 2023, respectively, and ~~December 31, 2022, respectively. Other assets also includes $78.4~~$476.5 million and ~~$60.4 million of materials~~$1.4 billion for the three and ~~supplies inventory as of June~~nine months ended September 30, ~~2023, and December 31, 2022, respectively.~~

~~(2)Total assets includes related~~-~~party amounts of $1.3 billion as of June 30, 2023, and December 31, 2022, which includes related~~-~~party Accounts receivable, net of $346.7 million and $313.9 million as of June 30, 2023, and December 31,~~ 2022, respectively. See Note 56.

(2)See Note 8.

(3)Total ~~liabilities~~operating expenses includes ~~related~~-~~party~~related-party amounts of ~~$353.8~~$(35.1) million and ~~$356.0~~$(50.5) million ~~as of June~~for the three and nine months ended September 30, 2023, respectively, and ~~December 31,~~$(3.7) million and $(30.9) million for the three and nine months ended September 30, 2022, ~~respectively.~~respectively, all primarily related to changes in imbalance positions. See Note 56.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

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

(UNAUDITED)

thousands Common
Units Noncontrolling
Interest Total
Balance at December 31, 2022 $ 3,092,012 $ 28,095 $ 3,120,107
Net income (loss) 208,013 535 208,548
Distributions to Chipeta noncontrolling interest owner — (2,240) (2,240)
Distributions to WES Operating unitholders (213,513) — (213,513)
Contributions of equity-based compensation from WES
7,058 — 7,058
Balance at March 31, 2023 $ 3,093,570 $ 26,390 $ 3,119,960
Net income (loss) 259,163 1,410 260,573
Distributions to Chipeta noncontrolling interest owner — (1,230) (1,230)
Distributions to WES Operating unitholders (342,895) — (342,895)
Contributions of equity-based compensation from WES
7,519 — 7,519
Balance at June 30, 2023 $ 3,017,357 $ 26,570 $ 3,043,927




thousands except number of units	September 30, 2023		December 31, 2022
ASSETS
Current assets
Cash and cash equivalents	$	484,453	$	286,101
Accounts receivable, net	614,816		554,263
Other current assets	30,808		57,291
Total current assets	1,130,077		897,655
Property, plant, and equipment
Cost	13,809,080		13,365,593
Less accumulated depreciation	5,144,678		4,823,993
Net property, plant, and equipment	8,664,402		8,541,600
Goodwill	4,783		4,783
Other intangible assets	689,324		713,075
Equity investments	915,076		944,696
Other assets (1)	215,476		166,450
Total assets (2)	$	11,619,138	$	11,268,259
LIABILITIES, EQUITY, AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables	$	409,156	$	404,468
Short-term debt	2,268		215,780
Accrued ad valorem taxes	50,291		72,875
Accrued liabilities	145,729		197,289

Total current liabilities	607,444		890,412
Long-term liabilities
Long-term debt	7,260,051		6,569,582
Deferred income taxes	15,378		14,424
Asset retirement obligations	307,945		290,021
Other liabilities	450,497		383,713
Total long-term liabilities	8,033,871		7,257,740
Total liabilities (3)	8,641,315		8,148,152
Equity and partners’ capital
Common units (318,675,578 units issued and outstanding at September 30, 2023, and December 31, 2022)	2,951,434		3,092,012



Total partners’ capital	2,951,434		3,092,012
Noncontrolling interest	26,389		28,095
Total equity and partners’ capital	2,977,823		3,120,107
Total liabilities, equity, and partners’ capital	$	11,619,138	$	11,268,259

(1)Other assets includes $6.5 million of NGLs line-fill inventory as of September 30, 2023, and December 31, 2022. Other assets also includes $92.4 million and $60.4 million of materials and supplies inventory as of September 30, 2023, and December 31, 2022, respectively.

(2)Total assets includes related-party amounts of $1.3 billion as of September 30, 2023, and December 31, 2022, which includes related-party Accounts receivable, net of $340.9 million and $313.9 million as of September 30, 2023, and December 31, 2022, respectively. See Note 6.

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
(3)Total liabilities includes related-party amounts of $376.4 million and $356.0 million as of September 30, 2023, and December 31, 2022, respectively. See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

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

(UNAUDITED)

Six Months Ended
June 30,
thousands 2023 2022
Cash flows from operating activities
Net income (loss) $ 469,121 $ 634,196
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization 288,118 273,618
Long-lived asset and other impairments
52,635 90
Non-cash equity-based compensation expense
14,577 14,505
Deferred income taxes 855 1,920
Accretion and amortization of long-term obligations, net
4,095 3,586
Equity income, net – related parties (81,345) (98,071)
Distributions from equity-investment earnings – related parties
82,871 96,404
(Gain) loss on divestiture and other, net 2,188 780
(Gain) loss on early extinguishment of debt (6,813) (91)
Other 399 136
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net 61 (279,830)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net (114,355) 74,551
Change in other items, net 67,490 14,889
Net cash provided by operating activities 779,897 736,683
Cash flows from investing activities
Capital expenditures (334,570) (191,357)
Contributions to equity investments – related parties (132) (5,040)
Distributions from equity investments in excess of cumulative earnings – related parties 23,179 25,407
Proceeds from the sale of assets to third parties — 1,096
(Increase) decrease in materials and supplies inventory and other (19,145) (1,053)
Net cash used in investing activities (330,668) (170,947)
Cash flows from financing activities
Borrowings, net of debt issuance costs 956,225 634,010
Repayments of debt (918,332) (883,548)
Increase (decrease) in outstanding checks (2,951) 13,142
Distributions to WES Operating unitholders (1)
(556,408) (440,465)
Distributions to Chipeta noncontrolling interest owner (3,470) (3,182)
Net contributions from (distributions to) related parties — 784
Other (1,550) (2,177)
Net cash provided by (used in) financing activities (526,486) (681,436)
Net increase (decrease) in cash and cash equivalents (77,257) (115,700)
Cash and cash equivalents at beginning of period 286,101 195,598
Cash and cash equivalents at end of period $ 208,844 $ 79,898
Supplemental disclosures
Interest paid, net of capitalized interest $ 158,376 $ 181,790
Income taxes paid (reimbursements received) 1,271 905
Accrued capital expenditures 116,466 51,878


thousands	Common Units		Noncontrolling Interest		Total

























Balance at December 31, 2022	$	3,092,012	$	28,095	$	3,120,107
Net income (loss)	208,013		535		208,548
Distributions to Chipeta noncontrolling interest owner	—		(2,240)		(2,240)
Distributions to WES Operating unitholders	(213,513)		—		(213,513)

Contributions of equity-based compensation from WES	7,058		—		7,058


Balance at March 31, 2023	$	3,093,570	$	26,390	$	3,119,960
Net income (loss)	259,163		1,410		260,573
Distributions to Chipeta noncontrolling interest owner	—		(1,230)		(1,230)
Distributions to WES Operating unitholders	(342,895)		—		(342,895)

Contributions of equity-based compensation from WES	7,519		—		7,519


Balance at June 30, 2023	$	3,017,357	$	26,570	$	3,043,927
Net income (loss)	283,415		1,432		284,847
Distributions to Chipeta noncontrolling interest owner	—		(1,613)		(1,613)
Distributions to WES Operating unitholders	(356,362)		—		(356,362)

Contributions of equity-based compensation from WES	7,024		—		7,024

Balance at September 30, 2023	$	2,951,434	$	26,389	$	2,977,823

~~(1)Includes related-party amounts. See~~ ~~Note 5.~~

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, 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
Net income (loss)	271,568		2,404		273,972
Distributions to Chipeta noncontrolling interest owner	—		(1,838)		(1,838)
Distributions to WES Operating unitholders	(568,107)		—		(568,107)
Contributions of equity-based compensation from Occidental	81		—		81
Contributions of equity-based compensation from WES	6,236		—		6,236
Net contributions from (distributions to) related parties	377		—		377
Balance at September 30, 2022	$	2,977,241	$	31,984	$	3,009,225

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	2023		2022
Cash flows from operating activities
Net income (loss)	$	753,968	$	908,168
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	435,481		430,455
Long-lived asset and other impairments	52,880		94

Non-cash equity-based compensation expense	21,601		20,822
Deferred income taxes	954		1,757
Accretion and amortization of long-term obligations, net	5,977		5,359
Equity income, net – related parties	(116,839)		(139,388)
Distributions from equity-investment earnings – related parties	115,897		139,710
(Gain) loss on divestiture and other, net	3,668		884
(Gain) loss on early extinguishment of debt	(15,378)		(91)
Other	371		299
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	(60,553)		(212,955)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	(102,048)		55,981
Change in other items, net	78,111		(6,666)
Net cash provided by operating activities	1,174,090		1,204,429
Cash flows from investing activities
Capital expenditures	(536,427)		(341,505)

Acquisitions from third parties	—		(41,018)
Contributions to equity investments – related parties	(1,153)		(8,899)
Distributions from equity investments in excess of cumulative earnings – related parties	31,715		41,058

Proceeds from the sale of assets to third parties	(60)		1,111
(Increase) decrease in materials and supplies inventory and other	(32,659)		(6,999)
Net cash used in investing activities	(538,584)		(356,252)
Cash flows from financing activities
Borrowings, net of debt issuance costs	1,801,011		1,389,010
Repayments of debt	(1,317,928)		(1,268,548)
Increase (decrease) in outstanding checks	(244)		1,562
Distributions to WES Operating unitholders (1)	(912,770)		(1,008,572)
Distributions to Chipeta noncontrolling interest owner	(5,083)		(5,020)
Net contributions from (distributions to) related parties	—		1,161
Other	(2,140)		(3,039)
Net cash provided by (used in) financing activities	(437,154)		(893,446)
Net increase (decrease) in cash and cash equivalents	198,352		(45,269)
Cash and cash equivalents at beginning of period	286,101		195,598
Cash and cash equivalents at end of period	$	484,453	$	150,329
Supplemental disclosures

Interest paid, net of capitalized interest	$	278,283	$	314,192
Income taxes paid (reimbursements received)	1,271		905
Accrued capital expenditures	112,150		71,955

(1)Includes related-party amounts. See Note 6.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

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 56), the Partnership’s investments accounted for under the equity method of accounting (see Note 67), and the Partnership and WES Operating for transactions that eliminate upon consolidation (see Note 56).

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 ~~June~~September 30, 2023, the Partnership’s assets and investments consisted of the following:


	Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems (1)	17	2	3	1
Treating facilities	37	3	—	—
Natural-gas processing plants/trains	25	3	—	3
NGLs pipelines	2	—	—	5
Natural-gas pipelines	6	—	—	1
Crude-oil pipelines	3	1	—	3

(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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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 (see Note 6)7):


	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	%
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	%
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 2022 Form 10-K, as filed with the SEC on February 22, 2023. Management believes that the disclosures made are adequate to make the information not misleading.

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.

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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

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 ~~June~~September 30, 2023 (see Note 67). 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.

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% limited partner interest in WES Operating owned by an Occidental subsidiary. WES Operating’s noncontrolling interest in the consolidated financial statements consists of the 25% third-party interest in Chipeta. See Note 4.5.

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 ~~six~~nine months ended ~~June~~September 30, 2023, the Partnership issued ~~830,272~~832,707 common units under its long-term incentive plans. Compensation expense was ~~$7.7~~$7.2 million and ~~$14.9~~$22.0 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~$6.8~~$6.4 million and ~~$12.6~~$19.0 million for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table summarizes revenue from contracts with customers:


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands	thousands	2023		2022		2023		2022		thousands	2023		2022		2023		2022
Revenue from customers	Revenue from customers									Revenue from customers
Service revenues – fee based	Service revenues – fee based	$	661,506	$	655,952	$	1,309,373	$	1,287,550	Service revenues – fee based	$	695,547	$	666,555	$	2,004,920	$	1,954,105
Service revenues – product based	Service revenues – product based	46,956		70,498		93,766		111,365		Service revenues – product based	48,446		91,356		142,212		202,721
Product sales	Product sales	29,659		149,736		68,684		235,325		Product sales	31,652		79,430		100,336		314,755
Total revenue from customers	Total revenue from customers	738,121		876,186		1,471,823		1,634,240		Total revenue from customers	775,645		837,341		2,247,468		2,471,581
Revenue from other than customers	Revenue from other than customers									Revenue from other than customers

Other	Other	152		233		432		476		Other	368		227		800		703
Total revenues and other	Total revenues and other	$	738,273	$	876,419	$	1,472,255	$	1,634,716	Total revenues and other	$	776,013	$	837,568	$	2,248,268	$	2,472,284

Contract balances. Receivables from customers, which are included in Accounts receivable, net on the consolidated balance sheets were ~~$551.9~~$610.1 million and $545.0 million as of ~~June~~September 30, 2023, and December 31, 2022, 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, 2022

22,561

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

~~(2,688)~~(4,089)

Additional estimated revenues recognized (2)

~~7,344~~6,477

Contract assets balance at ~~June~~September 30, 2023

~~27,217~~24,949

Contract assets at ~~June~~September 30, 2023

Other current assets

~~9,390~~7,850

Other assets

~~17,827~~17,099

Total contract assets from contracts with customers

~~27,217~~24,949

(1)Includes $(1.4) million for the three months ended ~~June~~September 30, 2023.

(2)Includes ~~$2.1~~$(0.9) million for the three months ended ~~June~~September 30, 2023.

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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) 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, 2022

369,285

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

~~41,226~~59,649

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

~~(13,818)~~(16,859)

Contract liabilities balance at ~~June~~September 30, 2023

~~396,693~~412,075

Contract liabilities at ~~June~~September 30, 2023

Accrued liabilities

~~14,905~~14,888

Other liabilities

~~381,788~~397,187

Total contract liabilities from contracts with customers

~~396,693~~412,075

(1)Includes ~~$17.5~~$18.4 million for the three months ended ~~June~~September 30, 2023.

(2)Includes ~~$(3.6)~~$(3.0) million for the three months ended ~~June~~September 30, 2023.

Transaction price allocated to remaining performance obligations. Revenues expected to be recognized from certain performance obligations that are unsatisfied (or partially unsatisfied) as of ~~June~~September 30, 2023, 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 2023	Remainder of 2023	$	550,406	Remainder of 2023	$	275,996
2024	2024	1,144,937		2024	1,147,263
2025	2025	1,097,142		2025	1,098,627
2026	2026	992,822		2026	993,997
2027	2027	903,367		2027	904,146
Thereafter	Thereafter	2,513,102		Thereafter	2,455,565
Total	Total	$	7,201,776	Total	$	6,875,594

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

3. ACQUISITIONS AND DIVESTITURES

Ranch Westex. In September 2022, the Partnership acquired the remaining 50% interest in Ranch Westex JV LLC (“Ranch Westex”) from a third party for $40.1 million. Subsequent to the acquisition, (i) the Partnership is the sole owner and operator of the asset, (ii) Ranch Westex is no longer accounted for under the equity method of accounting, and (iii) the Ranch Westex processing plant is included as part of the operations of the West Texas complex.

See also Note 12 for information related to the acquisition of Meritage Midstream Services II, LLC (“Meritage”) that closed on October 13, 2023.

4. PARTNERSHIP DISTRIBUTIONS

Partnership distributions. Under its partnership agreement, the Partnership distributes all of its available cash to unitholders of record on the applicable record date within 55 days following each quarter’s end. The amount of available cash (beyond proper reserves as defined in 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 (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.

The Board of Directors of the general partner (the “Board”) declared the following cash distributions to the Partnership’s unitholders for the periods presented:


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

2022	2022							2022
March 31	March 31	$	0.500	$	206,197	May 13, 2022	May 2, 2022	March 31	$	0.500	$	206,197	May 13, 2022	May 2, 2022
June 30	June 30	0.500		197,744		August 12, 2022	August 1, 2022	June 30	0.500		197,744		August 12, 2022	August 1, 2022
September 30	September 30	0.500		197,065		November 14, 2022	October 31, 2022	September 30	0.500		197,065		November 14, 2022	October 31, 2022
December 31	December 31	0.500		196,569		February 13, 2023	February 1, 2023	December 31	0.500		196,569		February 13, 2023	February 1, 2023
2023	2023							2023
March 31 (1)	March 31 (1)	$	0.856	$	336,987	May 15, 2023	May 1, 2023	March 31 (1)	$	0.856	$	336,987	May 15, 2023	May 1, 2023
June 30	June 30	0.5625		221,442		August 14, 2023	July 31, 2023	June 30	0.5625		221,442		August 14, 2023	July 31, 2023
September 30								September 30	0.5750		223,432		November 13, 2023	November 1, 2023

(1)Includes the regular quarterly distribution of $0.500 per unit, or $196.8 million, as well as the Enhanced Distribution of $0.356 per unit discussed below.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

4. PARTNERSHIP DISTRIBUTIONS

To facilitate the distribution of available cash, during 2022 the Partnership adopted a financial policy that provided for an additional distribution (“Enhanced Distribution”) to be paid in conjunction with the regular first-quarter distribution of the following year (beginning in 2023), in a target amount equal to Free cash flow generated in the prior year after subtracting Free cash flow used for the prior year’s debt repayments, regular-quarter distributions, and unit repurchases. This Enhanced Distribution is subject to Board discretion, the establishment of cash reserves for the proper conduct of the Partnership’s business and is also contingent on the attainment of prior year-end net leverage thresholds (the ratio of total principal debt outstanding less total cash on hand as of the end of such period, as compared to trailing-twelve-months Adjusted EBITDA), after taking the Enhanced Distribution for such prior year into effect. Free cash flow and Adjusted EBITDA are defined under the caption Reconciliation of Non-GAAP Financial Measures within Part I, Item 2 of this Form 10-Q. In April 2023, the Board approved an Enhanced Distribution of $0.356 per unit, or $140.1 million, related to the Partnership’s 2022 performance, which was paid in conjunction with the regular first-quarter 2023 distribution on May 15, 2023.

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~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~3. PARTNERSHIP 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 45. WES Operating made and/or declared the following cash distributions to its limited partners for the periods presented:

thousands

Quarters Ended

Total Quarterly
Cash Distribution

Distribution
Date

2022

March 31

213,513

May 2022

June 30

213,513

August 2022

September 30

213,513

November 2022

December 31

213,513

February 2023

2023

March 31 (1)

342,895

May 2023

June 30

226,260

August 2023

September 30

229,446

November 2023

(1)Includes amounts related to the Enhanced Distribution discussed above.

In addition to the distributions above, during the ~~three~~nine months ended ~~June~~September 30, 2023 and 2022, WES Operating made distributions of ~~$86.7~~$130.1 million and $441.3 million, respectively, to the Partnership and WGRAH. The Partnership used its portion of the ~~distribution~~distributions to repurchase common units. See Note 45.

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(UNAUDITED)

4.5. 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 ~~June~~September 30, 2023, Occidental held ~~190,281,578~~185,181,578 common units, representing a ~~48.3%~~47.7% 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 2.3% general partner interest in the Partnership. The public held ~~194,332,356~~194,334,791 common units, representing a ~~49.4%~~50.0% limited partner interest in the Partnership.

Partnership equity repurchases. In 2022, the Board authorized the Partnership to buy back up to $1.25 billion of the Partnership’s common units through December 31, 2024 (the “$1.25 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 ~~six~~nine months ended ~~June~~September 30, 2023, the Partnership repurchased ~~287,322~~5,387,322 common units, which includes 5,100,000 common units repurchased from Occidental, for an aggregate purchase price of ~~$7.1~~$134.6 million. During the ~~six~~nine months ended ~~June~~September 30, 2022, the Partnership repurchased ~~3,314,562~~17,982,357 common units, which includes 10,000,000 common units repurchased from Occidental, on the open market for an aggregate purchase price of ~~$79.2~~$447.1 million. The units were canceled immediately upon receipt. As of ~~June~~September 30, 2023, the Partnership had an authorized amount of ~~$755.3~~$627.8 million remaining under the program.

Holdings of WES Operating equity. As of ~~June~~September 30, 2023, (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.

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands except per-unit amounts	thousands except per-unit amounts	2023		2022		2023		2022		thousands except per-unit amounts	2023		2022		2023		2022
Net income (loss)	Net income (loss)									Net income (loss)
Limited partners’ interest in net income (loss)	Limited partners’ interest in net income (loss)	$	247,100	$	299,550	$	446,059	$	601,484	Limited partners’ interest in net income (loss)	$	270,843	$	259,501	$	716,902	$	860,985
Weighted-average common units outstanding	Weighted-average common units outstanding									Weighted-average common units outstanding
Basic	Basic	384,614		403,027		384,542		403,140		Basic	383,561		388,906		384,211		398,343
Dilutive effect of non-vested phantom units	Dilutive effect of non-vested phantom units	896		1,135		1,123		1,140		Dilutive effect of non-vested phantom units	1,211		1,412		1,133		1,202
Diluted	Diluted	385,510		404,162		385,665		404,280		Diluted	384,772		390,318		385,344		399,545
Excluded due to anti-dilutive effect	Excluded due to anti-dilutive effect	1,159		618		873		731		Excluded due to anti-dilutive effect	143		108		123		597
Net income (loss) per common unit	Net income (loss) per common unit									Net income (loss) per common unit
Basic	Basic	$	0.64	$	0.74	$	1.16	$	1.49	Basic	$	0.71	$	0.67	$	1.87	$	2.16
Diluted	Diluted	$	0.64	$	0.74	$	1.16	$	1.49	Diluted	$	0.70	$	0.66	$	1.86	$	2.15

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.

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5.6. 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 June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands	thousands	2023		2022		2023		2022		thousands	2023		2022		2023		2022
Revenues and other	Revenues and other									Revenues and other
Service revenues – fee based	Service revenues – fee based	$	423,330	$	428,631	$	846,831	$	843,530	Service revenues – fee based	$	454,039	$	431,944	$	1,300,870	$	1,275,474
Service revenues – product based	Service revenues – product based	6,642		21,808		14,758		24,051		Service revenues – product based	(234)		24,246		14,524		48,297
Product sales	Product sales	11,611		6,342		28,779		17,909		Product sales	9,818		20,323		38,597		38,232
Total revenues and other	Total revenues and other	441,583		456,781		890,368		885,490		Total revenues and other	463,623		476,513		1,353,991		1,362,003
Equity income, net – related parties (1)	Equity income, net – related parties (1)	42,324		48,464		81,345		98,071		Equity income, net – related parties (1)	35,494		41,317		116,839		139,388
Operating expenses	Operating expenses									Operating expenses
Cost of product (2)	Cost of product (2)	(15,184)		(12,148)		(19,131)		(31,691)		Cost of product (2)	(37,083)		(7,771)		(56,214)		(39,462)
Operation and maintenance	Operation and maintenance	903		702		1,650		643		Operation and maintenance	843		3,231		2,493		3,874
General and administrative (3)	General and administrative (3)	217		233		284		2,208		General and administrative (3)	414		81		698		2,289
Total operating expenses	Total operating expenses	(14,064)		(11,213)		(17,197)		(28,840)		Total operating expenses	(35,826)		(4,459)		(53,023)		(33,299)

(1)See Note 67.

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

(3)Balances for the three and ~~six~~nine months ended ~~June~~September 30, 2022, include 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.


Consolidated balance sheets	Consolidated balance sheets					Consolidated balance sheets
thousands	thousands	June 30, 2023		December 31, 2022		thousands	September 30, 2023		December 31, 2022
Assets	Assets					Assets
Accounts receivable, net	Accounts receivable, net	$	346,688	$	313,937	Accounts receivable, net	$	340,927	$	313,937
Other current assets	Other current assets	3,755		1,578		Other current assets	461		1,578
Equity investments (1)	Equity investments (1)	920,123		944,696		Equity investments (1)	915,076		944,696
Other assets	Other assets	38,623		29,058		Other assets	37,880		29,058
Total assets	Total assets	1,309,189		1,289,269		Total assets	1,294,344		1,289,269
Liabilities	Liabilities					Liabilities
Accounts and imbalance payables	Accounts and imbalance payables	33,632		32,150		Accounts and imbalance payables	34,307		32,150
Accrued liabilities	Accrued liabilities	2,350		11,756		Accrued liabilities	2,974		11,756
Other liabilities (2)	Other liabilities (2)	310,131		268,399		Other liabilities (2)	323,562		268,399
Total liabilities	Total liabilities	346,113		312,305		Total liabilities	360,843		312,305

(1)See Note 67.

(2)Includes contract liabilities from contracts with customers. See Note 2.

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5.6. RELATED-PARTY TRANSACTIONS


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

		Six Months Ended June 30,					Nine Months Ended September 30,
thousands	thousands	2023		2022		thousands	2023		2022
Distributions from equity-investment earnings – related parties	Distributions from equity-investment earnings – related parties	$	82,871	$	96,404	Distributions from equity-investment earnings – related parties	$	115,897	$	139,710

Contributions to equity investments – related parties	Contributions to equity investments – related parties	(132)		(5,040)		Contributions to equity investments – related parties	(1,153)		(8,899)
Distributions from equity investments in excess of cumulative earnings – related parties	Distributions from equity investments in excess of cumulative earnings – related parties	23,179		25,407		Distributions from equity investments in excess of cumulative earnings – related parties	31,715		41,058
Distributions to Partnership unitholders (1)	Distributions to Partnership unitholders (1)	(270,308)		(173,126)		Distributions to Partnership unitholders (1)	(382,438)		(272,797)
Distributions to WES Operating unitholders (2)	Distributions to WES Operating unitholders (2)	(11,131)		(8,812)		Distributions to WES Operating unitholders (2)	(18,260)		(20,177)
Net contributions from (distributions to) related parties	Net contributions from (distributions to) related parties	—		784		Net contributions from (distributions to) related parties	—		1,161

Unit repurchases from Occidental (3)						Unit repurchases from Occidental (3)	(127,500)		(252,500)

(1)Represents common and general partner unit distributions paid to Occidental pursuant to the partnership agreement of the Partnership (see Note 34 and Note 45).

(2)Represents distributions paid to Occidental, through its ownership of WGRAH, pursuant to WES Operating’s partnership agreement (see Note 34 and Note 45).

(3)Represents common units repurchased from Occidental (see Note 5).

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 June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands	thousands	2023		2022		2023		2022		thousands	2023		2022		2023		2022
General and administrative (1)	General and administrative (1)	$	853	$	919	$	2,134	$	3,867	General and administrative (1)	$	1,137	$	795	$	3,271	$	4,662

(1)Includes ~~(i)~~ an intercompany service fee between the Partnership and WES ~~Operating~~Operating. Balances for the three and ~~(ii)~~nine months ended September 30, 2022, include 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.


Consolidated balance sheets	Consolidated balance sheets					Consolidated balance sheets
thousands	thousands	June 30, 2023		December 31, 2022		thousands	September 30, 2023		December 31, 2022

Other current assets	Other current assets	$	3,540	$	1,487	Other current assets	$	408	$	1,487
Other assets	Other assets	36,868		28,459		Other assets	36,193		28,459
Accounts and imbalance payables (1)	Accounts and imbalance payables (1)	41,623		76,131		Accounts and imbalance payables (1)	50,204		76,131
Accrued liabilities	Accrued liabilities	2,033		11,439		Accrued liabilities	2,657		11,439

(1)Includes balances related to transactions between the Partnership and WES Operating.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5.6. RELATED-PARTY TRANSACTIONS


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

		Six Months Ended June 30,						Nine Months Ended September 30,
thousands	thousands		2023		2022		thousands		2023		2022
Distributions to WES Operating unitholders (1)	Distributions to WES Operating unitholders (1)		$	(556,408)	$	(440,465)	Distributions to WES Operating unitholders (1)		$	(912,770)	$	(1,008,572)

(1)Represents distributions paid to the Partnership and Occidental, through its ownership of WGRAH, pursuant to WES Operating’s partnership agreement. Includes distributions made from WES Operating to the Partnership that were used by the Partnership to repurchase common units. See Note 34 and Note 45.

Related-party revenues. Related-party revenues include amounts earned by the Partnership from services provided to Occidental and from the sale of natural gas, condensate, and NGLs to Occidental.

Gathering and processing agreements. The Partnership has significant gathering, processing, and 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 34% ~~and 35%~~ for both the three and ~~six~~nine months ended ~~June~~September 30, 2023, ~~respectively,~~ and 35% and 36% for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. Crude-oil and NGLs throughput (excluding equity-investment throughput) attributable to production owned or controlled by Occidental was 87% for both the three and nine months ended September 30, 2023, and 88% for both the three and ~~six~~nine months ended ~~June~~September 30, ~~2023, respectively, and 88% and 89% for the three and six months ended June 30, 2022, respectively.~~2022. Produced-water throughput attributable to production owned or controlled by Occidental was ~~76%~~77% and 78% for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, and ~~81%~~75% and ~~82%~~80% for the three and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

The Partnership is currently discussing varying interpretations of certain contractual provisions 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 discussions are 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 allowed 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 is not liable for any obligations under the Brasada gas processing agreement after June 30, 2023. For all periods presented, Mesquite 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 ended as of September 30, 2022.

Marketing Transition Services Agreement. During the year ended December 31, 2020, Occidental provided marketing-related services to certain of the Partnership’s subsidiaries (the “Marketing Transition Services Agreement”). While the Partnership still has some marketing agreements with affiliates of Occidental, on January 1, 2021, the Partnership began marketing and selling substantially all of its crude oil and residue gas, and a majority of its NGLs, directly to third parties.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5.6. RELATED-PARTY TRANSACTIONS

Related-party expenses. Operation and maintenance expense includes amounts accrued for or paid to related parties for field-related costs, shared field offices, and easements (see Related-party commercial agreement below) supporting the Partnership’s operations at certain 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. Related-party expenses bear no direct relationship to related-party revenues, and third-party expenses bear no direct relationship to third-party revenues.

Services Agreement. Occidental performed certain centralized corporate functions for the Partnership and WES Operating pursuant to the agreement dated as of December 31, 2019, by and among Occidental, Anadarko, and WES Operating GP (“Services Agreement”). Most of the administrative and operational services previously provided by Occidental fully transitioned to the Partnership by December 31, 2021, with certain limited transition services remaining in place pursuant to the terms of the Services Agreement.

Construction reimbursement agreements and purchases and sales with 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 and sells equipment, inventory, and other miscellaneous assets from or to Occidental or its affiliates.

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. Also, as a result of the amendments under the CUA, these agreements are 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 is being amortized to Operation and maintenance expense through 2038, the remaining term of the agreements.

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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(UNAUDITED)

6.7. EQUITY INVESTMENTS

The following table presents the financial statement impact of the Partnership’s equity investments for the ~~six~~nine months ended ~~June~~September 30, 2023:


thousands	thousands	Balance at December 31, 2022		Equity income, net		Contributions		Distributions		Distributions in excess of cumulative earnings (1)		Balance at June 30, 2023		thousands	Balance at December 31, 2022		Equity income, net		Contributions		Distributions		Distributions in excess of cumulative earnings (1)		Balance at September 30, 2023
White Cliffs	White Cliffs	$	16,095	$	985	$	—	$	(611)	$	(1,631)	$	14,838	White Cliffs	$	16,095	$	1,495	$	—	$	(1,120)	$	(2,387)	$	14,083
Rendezvous	Rendezvous	16,114		(1,286)		—		(344)		(1,062)		13,422		Rendezvous	16,114		(1,976)		—		(469)		(1,598)		12,071
Mont Belvieu JV	Mont Belvieu JV	91,310		14,103		—		(14,122)		(903)		90,388		Mont Belvieu JV	91,310		16,549		—		(16,577)		(3,103)		88,179
TEG	TEG	15,856		3,462		—		(3,375)		(75)		15,868		TEG	15,856		3,183		700		(3,200)		(976)		15,563
TEP	TEP	184,687		19,939		—		(20,065)		(6,755)		177,806		TEP	184,687		28,579		—		(28,767)		(9,239)		175,260
FRP	FRP	192,716		22,090		—		(22,177)		(4,163)		188,466		FRP	192,716		34,785		—		(34,916)		(4,447)		188,138
Whitethorn LLC	Whitethorn LLC	146,595		(1,614)		132		1,753		(1,083)		145,783		Whitethorn LLC	146,595		(3,295)		132		3,579		(1,083)		145,928
Saddlehorn	Saddlehorn	104,191		11,286		—		(11,057)		(1,875)		102,545		Saddlehorn	104,191		17,597		—		(17,253)		(2,722)		101,813
Panola	Panola	19,311		1,186		—		(1,318)		(169)		19,010		Panola	19,311		1,844		—		(1,974)		(169)		19,012
Mi Vida	Mi Vida	48,862		3,973		—		(4,334)		(4,358)		44,143		Mi Vida	48,862		7,212		—		(4,334)		(4,357)		47,383
Red Bluff Express	Red Bluff Express	108,959		7,221		—		(7,221)		(1,105)		107,854		Red Bluff Express	108,959		10,866		321		(10,866)		(1,634)		107,646
Total	Total	$	944,696	$	81,345	$	132	$	(82,871)	$	(23,179)	$	920,123	Total	$	944,696	$	116,839	$	1,153	$	(115,897)	$	(31,715)	$	915,076

(1)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.

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(UNAUDITED)

7.8. PROPERTY, PLANT, AND EQUIPMENT

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


thousands	thousands	Estimated Useful Life	June 30, 2023		December 31, 2022		thousands	Estimated Useful Life	September 30, 2023		December 31, 2022
Land	Land	N/A	$	10,982	$	10,982	Land	N/A	$	11,383	$	10,982
Gathering systems – pipelines	Gathering systems – pipelines	30 years	5,558,416		5,519,592		Gathering systems – pipelines	30 years	5,447,406		5,519,592
Gathering systems – compressors	Gathering systems – compressors	15 years	2,361,002		2,266,410		Gathering systems – compressors	15 years	2,369,219		2,266,410
Processing complexes and treating facilities	Processing complexes and treating facilities	25 years	3,452,005		3,419,201		Processing complexes and treating facilities	25 years	3,452,289		3,419,201
Transportation pipeline and equipment	Transportation pipeline and equipment	3 to 48 years	192,126		174,241		Transportation pipeline and equipment	3 to 48 years	192,289		174,241
Produced-water disposal systems	Produced-water disposal systems	20 years	1,031,623		932,627		Produced-water disposal systems	20 years	1,063,184		932,627
Assets under construction	Assets under construction	N/A	318,171		263,353		Assets under construction	N/A	443,272		263,353
Other	Other	3 to 40 years	816,586		779,187		Other	3 to 40 years	830,038		779,187
Total property, plant, and equipment	Total property, plant, and equipment		13,740,911		13,365,593		Total property, plant, and equipment		13,809,080		13,365,593
Less accumulated depreciation	Less accumulated depreciation		5,139,941		4,823,993		Less accumulated depreciation		5,144,678		4,823,993
Net property, plant, and equipment	Net property, plant, and equipment		$	8,600,970	$	8,541,600	Net property, plant, and equipment		$	8,664,402	$	8,541,600

“Assets under construction” represents property that is not yet placed into productive service as of the respective balance sheet date and is excluded from capitalized costs being depreciated.

Long-lived asset impairments. During the ~~six~~nine months ended ~~June~~September 30, 2023, the Partnership recognized a long-lived asset impairment of $52.1 million for assets located in the Rockies due to a reduction in estimated future cash flows resulting from a contract termination notice received in the first quarter of 2023. This asset was impaired to its estimated fair value of $22.8 million. The fair value was 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.

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~8. SELECTED COMPONENTS OF WORKING CAPITAL~~

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

The Partnership WES Operating
thousands June 30,
2023 December 31,
2022 June 30,
2023 December 31,
2022
Trade receivables, net $ 553,461 $ 548,859 $ 553,461 $ 548,859
Other receivables, net 761 5,404 741 5,404
Total accounts receivable, net $ 554,222 $ 554,263 $ 554,202 $ 554,263

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

The Partnership WES Operating
thousands June 30,
2023 December 31,
2022 June 30,
2023 December 31,
2022
NGLs inventory $ 1,904 $ 3,797 $ 1,904 $ 3,797
Imbalance receivables 2,158 32,658 2,158 32,658
Prepaid insurance 1,289 13,262 172 11,139
Contract assets 9,390 3,381 9,390 3,381
Other 14,287 6,408 14,072 6,316
Total other current assets $ 29,028 $ 59,506 $ 27,696 $ 57,291

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

The Partnership WES Operating
thousands June 30,
2023 December 31,
2022 June 30,
2023 December 31,
2022
Accrued interest expense $ 117,188 $ 110,486 $ 117,188 $ 110,486
Short-term asset retirement obligations
4,716 10,493 4,716 10,493
Short-term remediation and reclamation obligations
8,226 5,383 8,226 5,383
Income taxes payable 3,647 2,428 3,647 2,428
Contract liabilities 14,905 20,903 14,905 20,903
Accrued payroll and benefits 35,889 44,855 — —
Other 39,316 60,092 39,146 47,596
Total accrued liabilities $ 223,887 $ 254,640 $ 187,828 $ 197,289

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

9. SELECTED COMPONENTS OF WORKING CAPITAL

A summary of accounts receivable, net is as follows:


	The Partnership				WES Operating


thousands	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Trade receivables, net	$	614,493	$	548,859	$	614,493	$	548,859
Other receivables, net	343		5,404		323		5,404
Total accounts receivable, net	$	614,836	$	554,263	$	614,816	$	554,263

A summary of other current assets is as follows:


	The Partnership				WES Operating


thousands	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
NGLs inventory	$	3,019	$	3,797	$	3,019	$	3,797
Imbalance receivables	3,659		32,658		3,659		32,658
Prepaid insurance	2,453		13,262		1,840		11,139
Contract assets	7,850		3,381		7,850		3,381
Other	14,495		6,408		14,440		6,316
Total other current assets	$	31,476	$	59,506	$	30,808	$	57,291

A summary of accrued liabilities is as follows:


	The Partnership				WES Operating


thousands	September 30, 2023		December 31, 2022		September 30, 2023		December 31, 2022
Accrued interest expense	$	78,154	$	110,486	$	78,154	$	110,486
Short-term asset retirement obligations	3,453		10,493		3,453		10,493
Short-term remediation and reclamation obligations	6,061		5,383		6,061		5,383
Income taxes payable	4,453		2,428		4,453		2,428
Contract liabilities	14,888		20,903		14,888		20,903
Accrued payroll and benefits	42,595		44,855		—		—
Other	40,379		60,092		38,720		47,596
Total accrued liabilities	$	189,983	$	254,640	$	145,729	$	197,289

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

10. 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:


		June 30, 2023						December 31, 2022							September 30, 2023						December 31, 2022
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
Floating-Rate Senior Notes due 2023	Floating-Rate Senior Notes due 2023	$	—	$	—	$	—	$	213,138	$	213,121	$	214,823	Floating-Rate Senior Notes due 2023	$	—	$	—	$	—	$	213,138	$	213,121	$	214,823

Finance lease liabilities	Finance lease liabilities	2,532		2,532		2,532		2,659		2,659		2,659		Finance lease liabilities	2,268		2,268		2,268		2,659		2,659		2,659
Total short-term debt	Total short-term debt	$	2,532	$	2,532	$	2,532	$	215,797	$	215,780	$	217,482	Total short-term debt	$	2,268	$	2,268	$	2,268	$	215,797	$	215,780	$	217,482

Long-term debt	Long-term debt													Long-term debt
3.100% Senior Notes due 2025	3.100% Senior Notes due 2025	$	677,859	$	675,888	$	648,908	$	730,706	$	727,953	$	692,491	3.100% Senior Notes due 2025	$	666,481	$	664,844	$	638,729	$	730,706	$	727,953	$	692,491
3.950% Senior Notes due 2025	3.950% Senior Notes due 2025	399,163		397,288		383,780		399,163		396,825		379,107		3.950% Senior Notes due 2025	349,163		347,730		335,675		399,163		396,825		379,107
4.650% Senior Notes due 2026	4.650% Senior Notes due 2026	468,970		467,186		451,768		474,242		472,161		452,201		4.650% Senior Notes due 2026	467,204		465,566		448,890		474,242		472,161		452,201
4.500% Senior Notes due 2028	4.500% Senior Notes due 2028	397,182		394,188		375,297		400,000		396,698		368,346		4.500% Senior Notes due 2028	357,094		354,533		332,283		400,000		396,698		368,346
4.750% Senior Notes due 2028	4.750% Senior Notes due 2028	382,888		380,541		364,054		400,000		397,340		368,141		4.750% Senior Notes due 2028	382,888		380,644		358,230		400,000		397,340		368,141
6.350% Senior Notes due 2029														6.350% Senior Notes due 2029	600,000		593,081		601,962		—		—		—
4.050% Senior Notes due 2030	4.050% Senior Notes due 2030	1,160,471		1,152,608		1,045,828		1,200,000		1,191,345		1,053,038		4.050% Senior Notes due 2030	1,104,593		1,097,358		964,553		1,200,000		1,191,345		1,053,038
6.150% Senior Notes due 2033	6.150% Senior Notes due 2033	750,000		741,039		755,873		—		—		—		6.150% Senior Notes due 2033	750,000		740,947		724,425		—		—		—
5.450% Senior Notes due 2044	5.450% Senior Notes due 2044	600,000		593,954		511,260		600,000		593,878		503,742		5.450% Senior Notes due 2044	600,000		593,992		484,524		600,000		593,878		503,742
5.300% Senior Notes due 2048	5.300% Senior Notes due 2048	700,000		687,613		587,440		700,000		687,494		580,570		5.300% Senior Notes due 2048	700,000		687,674		548,429		700,000		687,494		580,570
5.500% Senior Notes due 2048	5.500% Senior Notes due 2048	350,000		342,847		294,126		350,000		342,783		291,194		5.500% Senior Notes due 2048	350,000		342,880		278,674		350,000		342,783		291,194
5.250% Senior Notes due 2050	5.250% Senior Notes due 2050	1,000,000		984,069		833,880		1,000,000		983,945		829,804		5.250% Senior Notes due 2050	1,000,000		984,136		775,000		1,000,000		983,945		829,804
RCF	RCF	—		—		—		375,000		375,000		375,000		RCF	—		—		—		375,000		375,000		375,000
Finance lease liabilities	Finance lease liabilities	6,993		6,993		6,993		4,160		4,160		4,160		Finance lease liabilities	6,666		6,666		6,666		4,160		4,160		4,160
Total long-term debt	Total long-term debt	$	6,893,526	$	6,824,214	$	6,259,207	$	6,633,271	$	6,569,582	$	5,897,794	Total long-term debt	$	7,334,089	$	7,260,051	$	6,498,040	$	6,633,271	$	6,569,582	$	5,897,794

(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)

10. DEBT AND INTEREST EXPENSE

Debt activity. The following table presents the debt activity for the ~~six~~nine months ended ~~June~~September 30, 2023:


thousands	Carrying Value







Balance at December 31, 2022	$	6,785,362
RCF borrowings	~~220,000~~470,000
Repayments of RCF borrowings	~~(595,000)~~(845,000)
Issuance of 6.350% Senior Notes due 2029	600,000
Issuance of 6.150% Senior Notes due 2033	750,000
Repayment of Floating-Rate Senior Notes due 2023	(213,138)
Repayment of 3.100% Senior Notes due 2025	~~(52,847)~~(64,225)
Repayment of 3.950% Senior Notes due 2025	(50,000)
Repayment of 4.650% Senior Notes due 2026	~~(5,272)~~(7,038)
Repayment of 4.500% Senior Notes due 2028	~~(2,818)~~(42,906)
Repayment of 4.750% Senior Notes due 2028	(17,112)
Repayment of 4.050% Senior Notes due 2030	~~(39,529)~~(95,407)
Finance lease liabilities	~~2,706~~2,115
Other	~~(5,606)~~(10,332)
Balance at ~~June~~September 30, 2023	$	~~6,826,746~~7,262,319

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~9. DEBT AND INTEREST EXPENSE~~

WES Operating Senior Notes. WES Operating issued the Fixed-Rate 3.100% Senior Notes due 2025, 4.050% Senior Notes due 2030, 5.250% Senior Notes due 2050, and the Floating-Rate Senior Notes due 2023 in January 2020. 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 ~~3.791%~~3.290%, ~~4.671%~~4.169%, and ~~5.869%~~5.363%, respectively, at ~~June~~September 30, 2023, and were 3.790%, 4.671%, and 5.869%, respectively, at ~~June~~September 30, 2022. 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 quarter of 2023, WES Operating completed the public offering of $600.0 million in aggregate principal amount of 6.350% Senior Notes due 2029. Interest is payable semi-annually on January 15th and July 15th of each year, with the initial interest payment being due on January 15, 2024. Net proceeds from the offering were used to fund a portion of the aggregate purchase price for the Meritage acquisition (see Note 12), to pay related costs and expenses, and for general partnership purposes.

During the second quarter of 2023, WES Operating completed the public offering of $750.0 million in aggregate principal amount of 6.150% Senior Notes due 2033. Interest is payable semi-annually on April 1st and October 1st of each year, with the initial interest payment being due on October 1, 2023. Net proceeds from the offering were used to repay borrowings under the RCF and for general partnership purposes.

~~Also during~~During the ~~second quarter of~~nine months ended September 30, 2023, WES Operating purchased and retired ~~$117.6~~$276.7 million of certain of its senior notes via open-market repurchases ~~(see~~ ~~Debt activity~~ ~~above). For the three months ended June 30, 2023, a gain of $6.8 million was recognized for the early retirement of portions of these notes. Subsequent to June 30, 2023, WES Operating purchased~~ and ~~retired $159.1 million of certain of its senior notes via open-market repurchases. During the first quarter of 2023, WES Operating~~ redeemed the total principal amount outstanding on the Floating-Rate Senior Notes due 2023 at par value with cash on ~~hand.~~hand (see Debt activity above). For the three and nine months ended September 30, 2023, a gain of $8.6 million and $15.4 million, respectively, was recognized for the early retirement of portions of these notes.

During the second quarter of 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 $1.4 million of the 3.100% Senior Notes due 2025 via open-market repurchases.

As of ~~June~~September 30, 2023, WES Operating was in compliance with all covenants under the relevant governing indentures.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

10. DEBT AND INTEREST EXPENSE

Revolving credit facility. In April 2023, WES Operating (i) repaid all then-outstanding borrowings under its senior unsecured revolving credit facility (“RCF”) with proceeds from the 6.150% Senior Notes due 2033 offering, and (ii) entered into an amendment to its RCF to, among other things, extend the maturity date to April 2028 and provide for a maximum borrowing capacity up to $2.0 billion, expandable to a maximum of $2.5 billion, through the maturity date.

As of ~~June~~September 30, 2023, there were no outstanding borrowings and $5.1 million of outstanding letters of credit, resulting in $2.0 billion of available borrowing capacity under the RCF. As of ~~June~~September 30, 2023 and 2022, the interest rate on any outstanding RCF borrowings was ~~6.44%~~6.62% and ~~3.12%~~4.65%, respectively. The facility-fee rate was 0.20% and 0.25% at ~~June~~September 30, 2023 and 2022, respectively. As of ~~June~~September 30, 2023, WES Operating was in compliance with all covenants under the RCF.

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


		Three Months Ended June 30,				Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,
thousands	thousands	2023		2022		2023		2022		thousands	2023		2022		2023		2022

Long-term and short-term debt	Long-term and short-term debt	$	(85,088)	$	(78,577)	$	(166,239)	$	(162,005)	Long-term and short-term debt	$	(83,177)	$	(81,554)	$	(249,416)	$	(243,559)
Finance lease liabilities	Finance lease liabilities	(230)		(31)		(393)		(73)		Finance lease liabilities	(223)		(23)		(616)		(96)
Commitment fees and amortization of debt-related costs	Commitment fees and amortization of debt-related costs	(3,414)		(3,068)		(6,295)		(6,100)		Commitment fees and amortization of debt-related costs	(2,904)		(3,049)		(9,199)		(9,149)
Capitalized interest	Capitalized interest	2,550		904		5,075		1,951		Capitalized interest	3,550		1,520		8,625		3,471

Interest expense	Interest expense	$	(86,182)	$	(80,772)	$	(167,852)	$	(166,227)	Interest expense	$	(82,754)	$	(83,106)	$	(250,606)	$	(249,333)

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~10.~~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 ~~June~~September 30, 2023, and December 31, 2022, the consolidated balance sheets included ~~$12.1~~$9.5 million and $7.4 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 year. See Note 89.

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 12 months, primarily relate to expansion, construction, and asset-integrity projects at the West Texas complex, DBM water systems, DBM oil system, and DJ Basin complex.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

12. SUBSEQUENT EVENTS

Meritage. On October 13, 2023, the Partnership closed on the acquisition of Meritage for $885.0 million (subject to certain customary post-closing adjustments) funded with cash, including proceeds from the Partnership’s $600.0 million senior note issuance in September 2023 (see Note 10) and borrowings on the RCF. The acquisition expands the Partnership’s existing Powder River Basin asset base, increasing total natural-gas processing capacity in that region to 440 MMcf/d and includes a FERC regulated NGL pipeline that connects to the processing facility. Due to the timing, the initial purchase price accounting for the transaction was not yet complete at the time of filing.

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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 2022 Form 10-K as filed with the SEC on February 22, 2023.

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 ~~June~~September 30, 2023 (see Note 6—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:

•benefits of the Meritage acquisition;

•our ability to pay distributions to our ~~unitholders;~~unitholders and the amount of such distributions;

•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, keep-whole, and fixed-recovery processing contracts;

•weather and natural disasters;

•inflation;

•the availability of goods and services;

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•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 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;

•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 2022 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 ~~June~~September 30, 2023, our assets and investments consisted of the following:


	Wholly Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems (1)	17	2	3	1
Treating facilities	37	3	—	—
Natural-gas processing plants/trains	25	3	—	3
NGLs pipelines	2	—	—	5
Natural-gas pipelines	6	—	—	1
Crude-oil pipelines	3	1	—	3

(1)Includes the DBM water systems.

Significant financial and operational events during the ~~six~~nine months ended ~~June~~September 30, 2023, included the following:

•WES Operating completed the public offering of $600.0 million in aggregate principal amount of 6.350% Senior Notes due 2029. Net proceeds from the offering were used to fund a portion of the aggregate purchase price for the Meritage acquisition, to pay related costs and expenses, and for general partnership purposes. See Liquidity and Capital Resources within this Item 2 for additional information.

•On October 13, 2023, we closed on the acquisition of Meritage for $885.0 million (subject to certain customary post-closing adjustments). See Acquisitions and Divestitures within this Item 2 for additional information.

•WES Operating completed the public offering of $750.0 million in aggregate principal amount of 6.150% Senior Notes due 2033. Net proceeds from this offering were used to repay borrowings under the RCF and for general partnership purposes. See Liquidity and Capital Resources within this Item 2 for additional information.

•WES Operating redeemed the $213.1 million total principal amount outstanding of the Floating-Rate Senior Notes due 2023 at par value with cash on hand.

•WES Operating purchased and retired ~~$117.6~~$276.7 million of certain of its senior notes via open-market repurchases.

•Our ~~second~~third-quarter 2023 per-unit distribution of ~~$0.5625~~$0.5750 increased ~~$0.0625~~$0.0125 from the ~~regular first-quarter~~second-quarter 2023 per-unit distribution of ~~$0.500.~~$0.5625.

•The Board approved an Enhanced Distribution of $0.356 per unit, or $140.1 million, related to our 2022 performance. This Enhanced Distribution was paid, along with our regular first-quarter 2023 distribution, on May 15, 2023, to our unitholders of record at the close of business on May 1, 2023.

•We repurchased ~~287,322~~5,387,322 common units, which includes 5,100,000 common units repurchased from Occidental, for an aggregate purchase price of ~~$7.1~~$134.6 million.

•Natural-gas throughput attributable to WES totaled ~~4,254~~4,484 MMcf/d and ~~4,181~~4,283 MMcf/d for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a 4%5% increase and a 2% increase compared to the three months ended ~~March 31,~~June 30, 2023, and ~~no change compared to the six~~nine months ended ~~June~~September 30, 2022, respectively.

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•Crude-oil and NGLs throughput attributable to WES totaled ~~626~~667 MBbls/d and ~~619~~635 MBbls/d for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a 2%7% increase and ~~an 8%~~a 7% decrease compared to the three months ended ~~March 31,~~June 30, 2023, and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

•Produced-water throughput attributable to WES totaled ~~943~~1,079 MBbls/d and ~~950~~994 MBbls/d for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a ~~1% decrease~~14% increase and ~~an 18%~~a 20% increase compared to the three months ended ~~March 31,~~June 30, 2023, and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

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•Gross margin ~~was $550.0~~totaled $601.1 million and ~~$1,087.9~~$1,689.0 million for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a 2%9% increase and a 5%1% decrease compared to the three months ended ~~March 31,~~June 30, 2023, and ~~six~~nine months ended ~~June~~September 30, 2022, respectively. See Reconciliation of Non-GAAP Financial Measures within this Item 2.

•Adjusted gross margin for natural-gas assets (as defined under the caption Reconciliation of Non-GAAP Financial Measures within this Item 2) averaged $1.26 per Mcf and ~~$1.28~~$1.27 per Mcf for the three and ~~six~~nine months ended September 30, 2023, respectively, representing no change compared to the three months ended June 30, 2023, ~~respectively, representing a 3% decrease~~ and a 5% decrease compared to the ~~three~~nine months ended ~~March 31, 2023, and six months ended June~~September 30, ~~2022, respectively.~~2022.

•Adjusted gross margin for crude-oil and NGLs assets (as defined under the caption Reconciliation of Non-GAAP Financial Measures within this Item 2) averaged ~~$2.58~~$2.27 per Bbl and ~~$2.61~~$2.49 per Bbl for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a 3%12% decrease and a 4%2% increase compared to the three months ended ~~March 31,~~June 30, 2023, and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

•Adjusted gross margin for produced-water assets (as defined under the caption Reconciliation of Non-GAAP Financial Measures within this Item 2) averaged ~~$0.83~~$0.84 per Bbl and ~~$0.82~~$0.83 per Bbl for the three and ~~six~~nine months ended ~~June~~September 30, 2023, respectively, representing a 2%1% increase and a ~~14%~~12% decrease compared to the three months ended ~~March 31,~~June 30, 2023, and ~~six~~nine months ended ~~June~~September 30, 2022, respectively.

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


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

		June 30, 2023	March 31, 2023	Inc/ (Dec)		June 30, 2023	June 30, 2022	Inc/ (Dec)				September 30, 2023	June 30, 2023	Inc/ (Dec)		September 30, 2023	September 30, 2022	Inc/ (Dec)
Throughput for natural-gas assets (MMcf/d)	Throughput for natural-gas assets (MMcf/d)									Throughput for natural-gas assets (MMcf/d)
Delaware Basin	Delaware Basin	1,592	1,569	1	%	1,581	1,410	12	%		Delaware Basin	1,674	1,592	5	%	1,612	1,452	11	%
DJ Basin	DJ Basin	1,309	1,306	—	%	1,308	1,329	(2)	%		DJ Basin	1,331	1,309	2	%	1,316	1,328	(1)	%
Equity investments	Equity investments	454	423	7	%	438	498	(12)	%		Equity investments	495	454	9	%	458	490	(7)	%
Other	Other	1,061	948	12	%	1,004	1,082	(7)	%		Other	1,151	1,061	8	%	1,053	1,088	(3)	%
Total throughput for natural-gas assets	Total throughput for natural-gas assets	4,416	4,246	4	%	4,331	4,319	—	%		Total throughput for natural-gas assets	4,651	4,416	5	%	4,439	4,358	2	%
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)
Delaware Basin	Delaware Basin	208	205	1	%	206	195	6	%		Delaware Basin	220	208	6	%	211	196	8	%
DJ Basin	DJ Basin	66	69	(4)	%	67	85	(21)	%		DJ Basin	68	66	3	%	68	84	(19)	%
Equity investments	Equity investments	323	314	3	%	319	367	(13)	%		Equity investments	347	323	7	%	328	382	(14)	%
Other	Other	42	35	20	%	40	37	8	%		Other	46	42	10	%	41	38	8	%
Total throughput for crude-oil and NGLs assets	Total throughput for crude-oil and NGLs assets	639	623	3	%	632	684	(8)	%		Total throughput for crude-oil and NGLs assets	681	639	7	%	648	700	(7)	%
Throughput for produced-water assets (MBbls/d)	Throughput for produced-water assets (MBbls/d)									Throughput for produced-water assets (MBbls/d)
Delaware Basin	Delaware Basin	963	977	(1)	%	970	824	18	%		Delaware Basin	1,101	963	14	%	1,014	848	20	%

Total throughput for produced-water assets	Total throughput for produced-water assets	963	977	(1)	%	970	824	18	%		Total throughput for produced-water assets	1,101	963	14	%	1,014	848	20	%

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OUTLOOK

We expect our business 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 producer activity. Our business is primarily driven by the level of production of ~~crude-oil~~crude oil and natural gas by producers in our areas of operation. This activity, however, can be impacted negatively by, among other things, commodity-price fluctuations and operational challenges. Fluctuating crude-oil, natural-gas, and NGLs prices can reduce the level of our customers’ activities and change the allocation of capital within their own asset portfolios. Such fluctuations can also impact us directly to the extent we take ownership of and sell certain volumes at the tailgate of our plants for our own account. During 2020, oil and natural-gas prices were negatively impacted by 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, the New York Mercantile Exchange (“NYMEX”) West Texas Intermediate crude-oil daily settlement prices during 2022 ranged from a high of $123.70 per barrel in March 2022 to a low of $71.02 per barrel in December 2022, and prices during the ~~six~~nine months ended ~~June~~September 30, 2023, ranged from ~~a high of $83.26 per barrel in April 2023 to~~ a low of $66.74 per barrel in March 2023 to a high of $93.68 per barrel in September 2023. Similar disruptions could occur as a consequence of the current conflict in the Middle East. The extent and duration of commodity-price volatility, and the associated direct and indirect impact on our business, cannot be predicted. To address the risks posed by fluctuating commodity prices, we intend to continue evaluating the relevant price environments and adjust our capital spending plans to reflect our customers’ anticipated activity levels, while maintaining appropriate liquidity and financial flexibility.

Additionally, even when the commodity-price environments are favorable, our customers must manage numerous operational challenges, including severe weather disruptions, downstream and produced-water takeaway constraints, seismicity concerns, new regulatory requirements, and the ability to optimize the efficiency and results of large, complex drilling programs. Our producers’ ability to mitigate or manage such challenges can have a significant impact on the volumes available for us to service in the short term. For this reason, we strive to work proactively with our customers whenever possible to provide high levels of reliability on our systems and help them meet these operational challenges as they arise.

Impact of inflation and supply-chain disruptions. The U.S. economy has recently experienced 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 inflation has raised our costs for labor, materials, fuel, and services, which has increased our operating costs and capital expenditures. Increases in inflationary pressure could 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. Short- and long-term interest rates increased during 2022, and have continued to increase during 2023, resulting in increased interest expense on RCF borrowings. Any future increases in interest rates likely will result in additional increases in financing costs. 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.

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ACQUISITIONS AND DIVESTITURES

Meritage. On October 13, 2023, we closed on the acquisition of Meritage for $885.0 million (subject to certain customary post-closing adjustments) funded with cash, including proceeds from our $600.0 million senior note issuance in September 2023and borrowings on the RCF. See Note 12—Subsequent Events and Note 10—Debt and Interest Expense under Part I, Item 1 of this Form 10-Q.

Cactus II. In November 2022, we sold our 15.00% interest in Cactus II to two third parties for $264.8 million, which includes a $1.8 million pro-rata distribution through closing. Total proceeds were received during the fourth quarter of 2022, resulting in a net gain on sale of $109.9 million that was recorded as Gain (loss) on divestiture and other, net in the consolidated statements of operations.

Ranch Westex. In September 2022, we acquired the remaining 50% interest in Ranch Westex from a third party for $40.1 million. Subsequent to the acquisition, (i) we are the sole owner and operator of the asset, (ii) Ranch Westex is no longer accounted for under the equity method of accounting, and (iii) the Ranch Westex processing plant is included as part of the operations of the West Texas complex.

RESULTS OF OPERATIONS

OPERATING RESULTS

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


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

thousands	thousands	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022			thousands	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
Total revenues and other (1)	Total revenues and other (1)	$	738,273	$	733,982	$	1,472,255	$	1,634,716		Total revenues and other (1)	$	776,013	$	738,273	$	2,248,268	$	2,472,284
Equity income, net – related parties	Equity income, net – related parties	42,324		39,021		81,345		98,071			Equity income, net – related parties	35,494		42,324		116,839		139,388
Total operating expenses (1)	Total operating expenses (1)	443,855		480,673		924,528		929,795			Total operating expenses (1)	449,265		443,855		1,373,793		1,451,558
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(70)		(2,118)		(2,188)		(780)			Gain (loss) on divestiture and other, net	(1,480)		(70)		(3,668)		(884)
Operating income (loss)	Operating income (loss)	336,672		290,212		626,884		802,212			Operating income (loss)	360,762		336,672		987,646		1,159,230
Interest expense	Interest expense	(86,182)		(81,670)		(167,852)		(166,227)			Interest expense	(82,754)		(86,182)		(250,606)		(249,333)
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	6,813		—		6,813		91			Gain (loss) on early extinguishment of debt	8,565		6,813		15,378		91
Other income (expense), net	Other income (expense), net	2,872		1,215		4,087		61			Other income (expense), net	(1,270)		2,872		2,817		117
Income (loss) before income taxes	Income (loss) before income taxes	260,175		209,757		469,932		636,137			Income (loss) before income taxes	285,303		260,175		755,235		910,105
Income tax expense (benefit)	Income tax expense (benefit)	659		1,416		2,075		3,296			Income tax expense (benefit)	905		659		2,980		3,683
Net income (loss)	Net income (loss)	259,516		208,341		467,857		632,841			Net income (loss)	284,398		259,516		752,255		906,422
Net income (loss) attributable to noncontrolling interests	Net income (loss) attributable to noncontrolling interests	6,595		4,696		11,291		17,807			Net income (loss) attributable to noncontrolling interests	7,102		6,595		18,393		25,643
Net income (loss) attributable to Western Midstream Partners, LP (2)	Net income (loss) attributable to Western Midstream Partners, LP (2)	$	252,921	$	203,645	$	456,566	$	615,034		Net income (loss) attributable to Western Midstream Partners, LP (2)	$	277,296	$	252,921	$	733,862	$	880,779

(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 5—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.

For purposes of the following discussion, any increases or decreases “for the three months ended ~~June~~September 30, 2023” refer to the comparison of the three months ended ~~June~~September 30, 2023, to the three months ended ~~March 31,~~June 30, 2023; and any increases or decreases “for the ~~six~~nine months ended ~~June~~September 30, 2023” refer to the comparison of the ~~six~~nine months ended ~~June~~September 30, 2023, to the ~~six~~nine months ended ~~June~~September 30, 2022.

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Throughput


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

		June 30, 2023	March 31, 2023	Inc/ (Dec)		June 30, 2023	June 30, 2022	Inc/ (Dec)				September 30, 2023	June 30, 2023	Inc/ (Dec)		September 30, 2023	September 30, 2022	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	395	369	7	%	382	408	(6)	%		Gathering, treating, and transportation	457	395	16	%	407	411	(1)	%
Processing	Processing	3,567	3,454	3	%	3,511	3,413	3	%		Processing	3,699	3,567	4	%	3,574	3,457	3	%
Equity investments (1)	Equity investments (1)	454	423	7	%	438	498	(12)	%		Equity investments (1)	495	454	9	%	458	490	(7)	%
Total throughput	Total throughput	4,416	4,246	4	%	4,331	4,319	—	%		Total throughput	4,651	4,416	5	%	4,439	4,358	2	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	162	139	17	%	150	154	(3)	%		Throughput attributable to noncontrolling interests (2)	167	162	3	%	156	157	(1)	%
Total throughput attributable to WES for natural-gas assets	Total throughput attributable to WES for natural-gas assets	4,254	4,107	4	%	4,181	4,165	—	%		Total throughput attributable to WES for natural-gas assets	4,484	4,254	5	%	4,283	4,201	2	%
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	316	309	2	%	313	317	(1)	%		Gathering, treating, and transportation	334	316	6	%	320	318	1	%
Equity investments (1)	Equity investments (1)	323	314	3	%	319	367	(13)	%		Equity investments (1)	347	323	7	%	328	382	(14)	%
Total throughput	Total throughput	639	623	3	%	632	684	(8)	%		Total throughput	681	639	7	%	648	700	(7)	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	13	12	8	%	13	14	(7)	%		Throughput attributable to noncontrolling interests (2)	14	13	8	%	13	14	(7)	%
Total throughput attributable to WES for crude-oil and NGLs assets	Total throughput attributable to WES for crude-oil and NGLs assets	626	611	2	%	619	670	(8)	%		Total throughput attributable to WES for crude-oil and NGLs assets	667	626	7	%	635	686	(7)	%
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	963	977	(1)	%	970	824	18	%		Gathering and disposal	1,101	963	14	%	1,014	848	20	%
Throughput attributable to noncontrolling interests (2)	Throughput attributable to noncontrolling interests (2)	20	20	—	%	20	16	25	%		Throughput attributable to noncontrolling interests (2)	22	20	10	%	20	17	18	%
Total throughput attributable to WES for produced-water assets	Total throughput attributable to WES for produced-water assets	943	957	(1)	%	950	808	18	%		Total throughput attributable to WES for produced-water assets	1,079	943	14	%	994	831	20	%

(1)Represents our share of average throughput for investments accounted for under the equity method of accounting.

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

Natural-gas assets

Total throughput attributable to WES for natural-gas assets increased by ~~147~~230 MMcf/d for the three months ended ~~June~~September 30, 2023, primarily due to (i) higher volumes at the ~~Chipeta complex due to volumes being diverted away from the plant for part of December 2022 through February 2023, (ii) higher volumes at the~~ West Texas complex, DJ Basin complex, and Marcellus Interest systems due to increased production in the area, (ii) higher volumes on the Red Bluff Express pipeline due to the addition of a new delivery point onto the pipeline, (iii) higher volumes ~~on Red Bluff Express,~~at the Brasada complex due to downstream issues which caused volumes to be diverted away from the plant and maintenance activities in the second quarter of 2023, (iv) higher volumes ~~around~~at the ~~Granger complex~~Springfield gas-gathering system due to new third-party production, ~~declines and extended winter weather conditions during the first quarter of 2023,~~ and (v) higher volumes at the MIGC ~~system.~~system and Mi Vida plant.

Total throughput attributable to WES for natural-gas assets increased by 1682 MMcf/d for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to higher volumes at the West Texas complex due to increased production in the area. This increase was offset partially by (i) lower volumes due to production declines in the areas around the Marcellus Interest systems and DJ Basin complex, (ii) decreased volumes at the Ranch Westex plant, which we acquired in the third quarter of 2022 and is included as part of the West Texas complex subsequent to the acquisition, and (iii) lower volumes due to production declines and extended winter weather conditions during the first quarter of 2023 in areas around the Granger and Red Desert complexes, (iv) lower volumes at the Brasada complex due to downstream issues causing volumes to be diverted away from the plant and maintenance activities, (v) lower volumes at the Chipeta complex due to volumes being diverted away from the plant for part of December 2022 through February 2023, and (vi) lower volumes at the Mi Vida plant.complex.

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Crude-oil and NGLs assets

Total throughput attributable to WES for crude-oil and NGLs assets increased by 1541 MBbls/d for the three months ended ~~June~~September 30, 2023, primarily due to (i) higher volumes on the ~~GNB NGL~~Whitethorn pipeline ~~due to higher volumes received from the Chipeta complex compared to the first quarter of 2023 along with increased producer activity~~ and (ii) higher volumes onat the ~~Saddlehorn pipeline.~~DBM oil system resulting from increased production in the area.

Total throughput attributable to WES for crude-oil and NGLs assets decreased by 51 MBbls/d for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to (i) lower volumes on the Cactus II pipeline, which was sold in the fourth quarter of 2022, and (ii) lower volumes at the DJ Basin oil system resulting from production declines in the area. These decreases were offset partially by (i) increased volumes on the Whitethorn pipeline and (ii) higher volumes at the DBM oil system resulting from increased production in the area.

Produced-water assets

Total throughput attributable to WES for produced-water assets increased by ~~142~~136 MBbls/d and 163 MBbls/d for the ~~six~~three and nine months ended ~~June~~September 30, 2023, respectively, due to higher production and new third-party connections brought online during ~~the first half of~~ 2023.

Service Revenues


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
Service revenues – fee based	Service revenues – fee based	$	661,506	$	647,867	2	%	$	1,309,373	$	1,287,550	2	%	Service revenues – fee based	$	695,547	$	661,506	5	%	$	2,004,920	$	1,954,105	3	%
Service revenues – product based	Service revenues – product based	46,956		46,810		—	%	93,766		111,365		(16)	%	Service revenues – product based	48,446		46,956		3	%	142,212		202,721		(30)	%
Total service revenues	Total service revenues	$	708,462	$	694,677	2	%	$	1,403,139	$	1,398,915	—	%	Total service revenues	$	743,993	$	708,462	5	%	$	2,147,132	$	2,156,826	—	%

Service revenues – fee based

Service revenues – fee based increased by ~~$13.6~~$34.0 million for the three months ended ~~June~~September 30, 2023, primarily due to increases of (i) ~~$8.1~~$17.8 million at the West Texas complex resulting from increased throughput, electricity-related rates billed to customers, and deficiency fees, (ii) ~~$5.4~~$11.3 million at the DBM water systems due to increased throughput and higher average fees, (iii) $4.5 million at the DJ Basin complex due to increased throughput and deficiency ~~fees. These increases were partially offset by a decrease of $2.8 million at the DJ Basin oil system due to decreased throughput.~~

Service revenues – fee based increased by $21.8 million for the six months ended June 30, 2023, primarily due to increases of (i) $45.7 million at the West Texas complex as a result of increased throughput, (ii) $4.3fees, and (iv) $3.0 million at the DBM oil system due to increased throughput, partially offset by decreased deficiency fees. These increases were partially offset by a ~~lower average~~decrease of $6.5 million at the Brasada complex due to a change in contract terms effective July 1, 2023.

Service revenues – fee ~~resulting from~~based increased by $50.8 million for the nine months ended September 30, 2023, primarily due to increases of (i) $74.8 million at the West Texas complex as a ~~cost-of-service rate redetermination effective January 1, 2023,~~result of increased throughput, electricity-related rates billed to customers, and ~~(iii) $3.0~~deficiency fees, (ii) $10.4 million at the DBM water systems due to increased throughput, partially offset by decreased deficiency fees, (iii) $8.9 million at the DBM oil system due to increased throughput, and ~~a lower average fee resulting from a cost-of-service rate redetermination effective January 1, 2023.~~(iv) $7.6 million at the DJ Basin complex due to increased deficiency fees and electricity-related rates billed to customers, partially offset by decreased throughput. These increases were partially offset by decreases of (i) ~~$10.3 million at the Chipeta complex due to decreased deficiency fees and throughput, (ii) $8.4~~$15.5 million at the DJ Basin oil system due to decreased throughput, ~~partially offset by increased~~(ii) $13.9 million at the Chipeta complex due to decreased deficiency fees, (iii) ~~$6.1~~$8.5 million at the Springfield system primarily due to decreased demand-fee revenue, partially offset by increased throughput, (iv) $5.9 million at the Brasada complex due to a change in contract terms effective July 1, 2023, and ~~(iv) $4.5~~(v) $5.2 million at the Marcellus Interest systems due to decreased throughput.

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Service revenues – product based

Service revenues – product based decreased by ~~$17.6~~$60.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to decreases of (i) $24.6 million at the West Texas complex due to decreased average prices, volumes sold, and electricity-related rates billed to customers, (ii) $13.6 million and $5.9 million at the DJ Basin complex and Hilight system, respectively, due to decreased average prices, (iii) $7.7 million and $5.1 million at the Red Desert ~~complex~~and Granger complexes, respectively, due to decreased average prices and volumes sold, ~~(ii) $4.3 million, $4.1 million,~~ and ~~$3.5 million at the Granger complex, Hilight system, and DJ Basin complex, respectively, due to decreased average prices, and (iii) $3.6~~(iv) $2.8 million at the Chipeta complex due to decreased volumes sold. ~~These decreases were partially offset by an increase of $4.0 million at the West Texas complex due to increased volumes sold and increased electricity-related rates billed to customers.~~

~~Table of Contents~~

Product Sales


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

thousands except percentages and per-unit amounts	thousands except percentages and per-unit amounts	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages and per-unit amounts	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
Natural-gas sales	Natural-gas sales	$	7,237	$	2,775	161	%	$	10,012	$	66,363	(85)	%	Natural-gas sales	$	16,454	$	7,237	127	%	$	26,466	$	101,475	(74)	%
NGLs sales	NGLs sales	22,422		36,250		(38)	%	58,672		168,962		(65)	%	NGLs sales	15,198		22,422		(32)	%	73,870		213,280		(65)	%
Total Product sales	Total Product sales	$	29,659	$	39,025	(24)	%	$	68,684	$	235,325	(71)	%	Total Product sales	$	31,652	$	29,659	7	%	$	100,336	$	314,755	(68)	%
Per-unit gross average sales price:	Per-unit gross average sales price:													Per-unit gross average sales price:
Natural gas (per Mcf)	Natural gas (per Mcf)	$	1.33	$	1.75	(24)	%	$	1.53	$	5.76	(73)	%	Natural gas (per Mcf)	$	1.91	$	1.33	44	%	$	1.67	$	6.28	(73)	%
NGLs (per Bbl)	NGLs (per Bbl)	23.65		28.78		(18)	%	26.17		46.53		(44)	%	NGLs (per Bbl)	27.64		23.65		17	%	26.65		44.43		(40)	%

Natural-gas sales

Natural-gas sales increased by ~~$4.5~~$9.2 million for the three months ended ~~June~~September 30, 2023, primarily due to an increase of $10.1 million at the West Texas complex due to increased ~~volumes sold, partially offset by decreased~~ average prices ~~at the DJ Basin complex.~~and volumes sold.

Natural-gas sales decreased by ~~$56.4~~$75.0 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to decreases of (i) ~~$53.4~~$71.0 million at the West Texas complex due to decreased average prices, partially offset by higher volumes sold, and (ii) ~~$8.2~~$14.3 million at the Red Desert complex due to decreased average prices and volumes sold. These decreases were partially offset by an increase of $10.3 million at the DJ Basin complex as a result of higher average prices and volumes sold.

NGLs sales

NGLs sales decreased by ~~$13.8~~$7.2 million for the three months ended ~~June~~September 30, 2023, primarily due to ~~decreases~~a decrease of ~~$7.1~~$13.1 million at the West Texas complex due to changes in contract mix and ~~$6.6~~decreased volumes sold. This decrease was partially offset by increases of (i) $2.0 million at the DJ Basin ~~and West Texas complexes, respectively, due to decreased average prices. These decreases were partially offset by an increase of $2.4 million at the Chipeta~~ complex due to ~~higher~~increased average prices and (ii) $1.7 million at DBM water systems due to increased volumes sold.

NGLs sales decreased by ~~$110.3~~$139.4 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to decreases of (i) ~~$75.3~~$93.0 million, $21.6 million, $8.7 million, and ~~$7.1~~$3.2 million at the West Texas, Chipeta, Granger, and ~~Granger~~Red Desert complexes, respectively, ~~due to decreased volumes sold and average prices, (ii) $16.0 million at the Chipeta complex~~ due to decreased average prices and ~~(iii) $6.7~~volumes sold, and (ii) $7.5 million at the Brasada complex due to a contract expiration in the third quarter of 2022.

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Equity Income, Net – Related Parties


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
Equity income, net – related parties	Equity income, net – related parties	$	42,324	$	39,021	8	%	$	81,345	$	98,071	(17)	%	Equity income, net – related parties	$	35,494	$	42,324	(16)	%	$	116,839	$	139,388	(16)	%

Equity income, net – related parties ~~increased~~decreased by ~~$3.3~~$6.8 million for the three months ended ~~June~~September 30, 2023, primarily due to ~~increases~~decreases of ~~(i) $2.2~~$4.8 million and $2.1 million at ~~FRP~~Mont Belvieu JV and ~~(ii) $1.0 million at Mi Vida.~~TEG, respectively.

Equity income, net – related parties decreased by ~~$16.7~~$22.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to decreases of (i) ~~$7.3~~$10.9 million at Cactus II due to the divestiture of our interest in the fourth quarter of 2022 (see Acquisitions and Divestitures within this Item 2), (ii) ~~$4.7~~$5.1 million and $3.9 million at Mont Belvieu JV and TEP, respectively, and (iii) $3.4 million at Ranch Westex, which we acquired in the third quarter of 2022 and is included as part of the West Texas complex subsequent to the acquisition (see Acquisitions and Divestitures within this Item 2)~~, and (iii) $3.1 million at Mi Vida due to a decrease in gross margin.~~.

~~Table of Contents~~

Cost of Product and Operation and Maintenance Expenses


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
Residue purchases	Residue purchases	$	6,066	$	15,638	(61)	%	$	21,704	$	100,160	(78)	%	Residue purchases	$	2,880	$	6,066	(53)	%	$	24,584	$	142,959	(83)	%
NGLs purchases	NGLs purchases	48,942		51,829		(6)	%	100,771		173,054		(42)	%	NGLs purchases	50,394		48,942		3	%	151,165		263,014		(43)	%
Other	Other	(10,262)		(16,008)		36	%	(26,270)		(51,810)		49	%	Other	(25,684)		(10,262)		(150)	%	(51,954)		(77,736)		33	%
Cost of product	Cost of product	44,746		51,459		(13)	%	96,205		221,404		(57)	%	Cost of product	27,590		44,746		(38)	%	123,795		328,237		(62)	%
Operation and maintenance	Operation and maintenance	183,431		174,239		5	%	357,670		297,129		20	%	Operation and maintenance	204,434		183,431		11	%	562,104		487,643		15	%
Total Cost of product and Operation and maintenance expenses	Total Cost of product and Operation and maintenance expenses	$	228,177	$	225,698	1	%	$	453,875	$	518,533	(12)	%	Total Cost of product and Operation and maintenance expenses	$	232,024	$	228,177	2	%	$	685,899	$	815,880	(16)	%

Residue purchases

Residue purchases decreased by ~~$9.6~~$118.4 million for the ~~three~~nine months ended ~~June~~September 30, 2023, primarily due to decreases of (i) ~~$5.6 million at the Granger complex due to decreased volumes purchased and (ii) $1.4 million at the Red Desert complex due to lower average prices.~~

~~Residue purchases decreased by $78.5 million for the six months ended June 30, 2023, primarily due to decreases of (i) $54.7~~$75.0 million at the West Texas complex attributable to changes in contract mix during 2022 and lower average prices, (ii) ~~$9.4~~$14.9 million and ~~$6.7~~$12.2 million at the Chipeta and Red Desert complexes, respectively, due to decreased volumes purchased and lower average prices, and (iii) ~~$5.4~~$9.0 million at the DJ Basin complex primarily due to lower average prices.

NGLs purchases

NGLs purchases decreased by ~~$2.9~~$111.8 million for the ~~three~~nine months ended ~~June~~September 30, 2023, primarily due to ~~a decrease~~decreases of ~~$2.8~~(i) $66.8 million, $5.2 million, and $5.2 million at the West Texas, Chipeta, and Granger complexes, respectively, primarily due to lower average prices and volumes purchased, (ii) $23.1 million at the DJ Basin complex due to lower average ~~prices.~~

~~NGLs purchases decreased by $72.3 million for the six months ended June 30, 2023, primarily due to decreases of (i) $42.6 million, $9.2 million,~~prices, and ~~$4.6 million at the West Texas, DJ Basin, and Granger complexes, respectively, primarily due to lower average prices, (ii) $6.8~~(iii) $7.7 million at the Brasada complex due to a contract expiration in the third quarter of ~~2022, and (iii) $5.6 million at the Chipeta complex due to decreased volumes purchased and lower average prices.~~2022.

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Other items

Other items ~~increased~~decreased by ~~$5.7~~$15.4 million for the three months ended ~~June~~September 30, 2023, primarily due to decreases of (i) $12.0 million at the West Texas complex due to changes in imbalance positions, ~~across several systems.~~partially offset by higher electricity-related costs, and (ii) $3.8 million at the DJ Basin complex due to changes in imbalance positions.

Other items increased by ~~$25.5~~$25.8 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to an increase of ~~$29.6~~$39.5 million at the DJ Basin complex due to changes in imbalance positions. This increase was partially offset by ~~a decrease~~decreases of ~~$2.8~~(i) $6.2 million at the West Texas complex due to changes in imbalance positions, partially offset by higher electricity-related and offload costs, and (ii) $3.7 million and $1.9 million at the Red Desert complex and MIGC system, respectively, attributable to changes in imbalance positions.

Operation and maintenance expense

Operation and maintenance expense increased by ~~$9.2~~$21.0 million for the three months ended ~~June~~September 30, 2023, primarily due to increases of (i) ~~$6.6~~$14.1 million in utility expense, ~~and~~ (ii) ~~$3.2~~$3.7 million for ~~salaries~~maintenance and ~~wages costs.~~repair expense, and (iii) $2.8 million attributable to higher contract labor and consulting expense.

Operation and maintenance expense increased by ~~$60.5~~$74.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to increases of (i) ~~$19.7~~$27.9 million for maintenance and repair expense, (ii) ~~$12.4~~$19.5 million for salaries and wages costs, (iii) ~~$5.4 million in regulatory and environmental expense, (iv) $4.9 million in mechanical-integrity costs, (v) $4.6~~$7.5 million in utility expense, ~~(vi) $3.9~~(iv) $5.5 million in land-related costs, (v) $4.8 million attributable to higher contract labor and ~~(vii) $3.3~~consulting expense, (vi) $4.6 million in water-disposal costs, and (vii) $3.6 million in higher equipment rental costs.

~~Table of Contents~~

Other Operating Expenses


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
General and administrative	General and administrative	$	53,405	$	51,117	4	%	$	104,522	$	96,450	8	%	General and administrative	$	55,050	$	53,405	3	%	$	159,572	$	144,635	10	%
Property and other taxes	Property and other taxes	18,547		6,831		172	%	25,378		41,104		(38)	%	Property and other taxes	14,583		18,547		(21)	%	39,961		60,494		(34)	%
Depreciation and amortization	Depreciation and amortization	143,492		144,626		(1)	%	288,118		273,618		5	%	Depreciation and amortization	147,363		143,492		3	%	435,481		430,455		1	%
Long-lived asset and other impairments	Long-lived asset and other impairments	234		52,401		(100)	%	52,635		90		NM		Long-lived asset and other impairments	245		234		5	%	52,880		94		NM

Total other operating expenses	Total other operating expenses	$	215,678	$	254,975	(15)	%	$	470,653	$	411,262	14	%	Total other operating expenses	$	217,241	$	215,678	1	%	$	687,894	$	635,678	8	%

NM—Not meaningful

General and administrative expenses

General and administrative expenses increased by ~~$2.3~~$14.9 million for the ~~three~~nine months ended ~~June~~September 30, 2023, primarily due to increases of (i) $3.9 million in corporate-related costs, primarily related to information technology costs, and (ii) $2.9 million in contract and consulting costs. These increases were partially offset by a decrease of $4.4 million in personnel costs.

~~General and administrative expenses increased by $8.1 million for the six months ended June 30, 2023, primarily due to increases of (i) $3.1~~$6.3 million in corporate-related costs, primarily related to information technology costs, (ii) ~~$2.5~~$3.9 million in personnel costs, and (iii) ~~$2.5~~$3.2 million in contract and consulting costs.

Property and other taxes

Property and other taxes ~~increased~~decreased by ~~$11.7~~$4.0 million for the three months ended ~~June~~September 30, 2023, primarily due to ~~decreases in the ad valorem~~lower property tax ~~accrual during the first quarter of 2023 related to the finalization of 2022 assessments~~values at the DJ Basin ~~complex.~~and West Texas complexes.

Property and other taxes decreased by ~~$15.7~~$20.5 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to decreases in the ad valorem property tax accrual during 2023 related to the finalization of 2022 assessments at the DJ Basin complex.

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Depreciation and amortization expense

Depreciation and amortization expense ~~decreased~~increased by ~~$1.1~~$3.9 million for the three months ended ~~June~~September 30, 2023, primarily due to a decrease of $5.1 million at the DJ Basin complex due to acceleration of depreciation expense during the first quarter of 2023, partially offset by increases of (i) $2.3 million related to depreciation for capitalized information technology implementation costs and (ii) $2.3 million at the West Texas complex as a result of accretion adjustments to our asset retirement obligation during the first quarter of 2023.

Depreciation and amortization expense increased by $14.5 million for the six months ended June 30, 2023, primarily due to increases of (i) $4.5 million and $2.5 million at the DJ Basin and Red Desert complexes, respectively, due to acceleration of depreciation expense as well as accretion adjustments to our asset retirement obligation during 2023, (ii) $3.5 million at the West Texas complex primarily resulting from capital projects being placed into service and ~~(iii) $2.5~~asset retirement obligation revisions at the West Texas complex and DBM water systems.

Depreciation and amortization expense increased by $5.0 million for the nine months ended September 30, 2023, primarily due to increases of (i) $8.9 million and $5.1 million at the West Texas complex and DBM water systems, respectively, primarily resulting from capital projects being placed into service, and (ii) $5.4 million related to depreciation for capitalized information technology implementation costs. These increases were offset partially by a decrease of $13.3 million at the DJ Basin complex primarily due to acceleration of depreciation expense during 2022.

Long-lived asset and other impairment expense

Long-lived asset and other impairment expense for the ~~three~~nine months ended ~~March 31,~~September 30, 2023, was primarily due to a $52.1 million impairment for assets located in the Rockies.

For further information on Long-lived asset and other impairment expense, see Note 7—8—Property, Plant, and Equipment in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

~~Table of Contents~~

Interest Expense


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)			thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)
Long-term and short-term debt	Long-term and short-term debt	$	(85,088)	$	(81,151)	5	%	$	(166,239)	$	(162,005)	3	%		Long-term and short-term debt	$	(83,177)	$	(85,088)	(2)	%	$	(249,416)	$	(243,559)	2	%
Finance lease liabilities	Finance lease liabilities	(230)		(163)		41	%	(393)		(73)		NM			Finance lease liabilities	(223)		(230)		(3)	%	(616)		(96)		NM
Commitment fees and amortization of debt-related costs	Commitment fees and amortization of debt-related costs	(3,414)		(2,881)		19	%	(6,295)		(6,100)		3	%		Commitment fees and amortization of debt-related costs	(2,904)		(3,414)		(15)	%	(9,199)		(9,149)		1	%
Capitalized interest	Capitalized interest	2,550		2,525		1	%	5,075		1,951		160	%		Capitalized interest	3,550		2,550		39	%	8,625		3,471		148	%

Interest expense	Interest expense	$	(86,182)	$	(81,670)	6	%	$	(167,852)	$	(166,227)	1	%		Interest expense	$	(82,754)	$	(86,182)	(4)	%	$	(250,606)	$	(249,333)	1	%

Interest expense

Interest expense ~~increased~~decreased by ~~$4.5~~$3.4 million for the three months ended ~~June~~September 30, 2023, primarily due to decreases of (i) $3.7 million due to credit-rating related interest rate changes and lower outstanding balances on certain senior notes, and (ii) $1.0 million due to higher capitalized interest. These decreases were offset partially by an increase of ~~$11.3~~$0.7 million ~~of interest incurred on the 6.150% Senior Notes due 2033 that were issued during the second quarter of 2023, partially offset by a decrease of $6.3 million~~primarily due to ~~lower~~higher outstanding borrowings under the RCF during the ~~second~~third quarter of 2023.

Interest expense increased by ~~$1.6~~$1.3 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to increases of (i) ~~$11.3~~$23.0 million of interest incurred on the 6.150% Senior Notes due 2033 that were issued during the second quarter of 2023 and (ii) ~~$5.8~~$1.7 million primarily due to higher outstanding borrowings and average interest rates ~~under~~on the RCF during ~~the first quarter of~~ 2023. These increases were offset partially by decreases of (i) $10.0 million due to credit-rating related interest rate changes and lower outstanding balances on certain senior notes, (ii) $5.2 million due to higher capitalized interest, (iii) $5.1 million due to the redemption of the total principal amount outstanding of the 4.000% Senior Notes due 2022 during the second quarter of 2022, ~~(ii) $3.7 million due to credit-rating related interest rate changes~~ and ~~a lower outstanding balance on the 4.050% Senior Notes due 2030 and 3.100% Senior Notes due 2025, (iii) $3.1 million due to higher capitalized interest,~~ (iv) ~~$2.0~~$3.9 million due to the redemption of the total principal amount outstanding of the Floating-Rate Senior Notes due 2023 during the first quarter of ~~2023, and (v) $1.9 million due to credit-rating related interest rate changes on the 5.250% Senior Notes due 2050.~~2023.

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

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Other Income (Expense), Net


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

thousands except percentages	thousands except percentages	June 30, 2023		March 31, 2023		Inc/ (Dec)	June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages	September 30, 2023		June 30, 2023		Inc/ (Dec)	September 30, 2023		September 30, 2022		Inc/ (Dec)
Other income (expense), net	Other income (expense), net	$	2,872	$	1,215	136%	$	4,087	$	61	NM		Other income (expense), net	$	(1,270)	$	2,872	(144)%	$	2,817	$	117	NM

Other income (expense), net ~~increased~~decreased by ~~$1.7 million and $4.0~~$4.1 million for the three ~~and six~~ months ended ~~June~~September 30, 2023, ~~respectively,~~primarily due to interest accrued in the third quarter of 2023 related to a sales tax audit.

Other income (expense), net increased by $2.7 million for the nine months ended September 30, 2023, primarily due to interest income earned resulting from higher interest rates and cash and cash equivalent balances throughout ~~2023.~~2023, partially offset by interest accrued in the third quarter of 2023 related to a sales tax audit.

Income Tax Expense (Benefit)

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.

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RECONCILIATION OF NON-GAAP FINANCIAL MEASURES

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, (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, and (iv) costs associated with our offload commitments with third parties providing firm-processing capacity. 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).

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.

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.

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Adjusted gross margin, Adjusted EBITDA, and Free cash flow are not defined in GAAP. The GAAP measure 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 that are most directly comparable to Adjusted EBITDA. The GAAP measure 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				Six Months Ended				Three Months Ended				Nine Months Ended

thousands	thousands	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022			thousands	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
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	$	738,273	$	733,982	$	1,472,255	$	1,634,716		Total revenues and other	$	776,013	$	738,273	$	2,248,268	$	2,472,284
Less:	Less:										Less:
Cost of product	Cost of product	44,746		51,459		96,205		221,404			Cost of product	27,590		44,746		123,795		328,237
Depreciation and amortization	Depreciation and amortization	143,492		144,626		288,118		273,618			Depreciation and amortization	147,363		143,492		435,481		430,455
Gross margin	Gross margin	550,035		537,897		1,087,932		1,139,694			Gross margin	601,060		550,035		1,688,992		1,713,592
Add:	Add:										Add:
Distributions from equity investments	Distributions from equity investments	54,075		51,975		106,050		121,811			Distributions from equity investments	41,562		54,075		147,612		180,768
Depreciation and amortization	Depreciation and amortization	143,492		144,626		288,118		273,618			Depreciation and amortization	147,363		143,492		435,481		430,455
Less:	Less:										Less:
Reimbursed electricity-related charges recorded as revenues	Reimbursed electricity-related charges recorded as revenues	23,286		23,569		46,855		37,446			Reimbursed electricity-related charges recorded as revenues	29,981		23,286		76,836		58,187
Adjusted gross margin attributable to noncontrolling interests (1)	Adjusted gross margin attributable to noncontrolling interests (1)	16,914		15,774		32,688		37,256			Adjusted gross margin attributable to noncontrolling interests (1)	18,095		16,914		50,783		56,142
Adjusted gross margin	Adjusted gross margin	$	707,402	$	695,155	$	1,402,557	$	1,460,421		Adjusted gross margin	$	741,909	$	707,402	$	2,144,466	$	2,210,486

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

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To facilitate investor and industry analysis, 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.


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

thousands except per-unit amounts	thousands except per-unit amounts	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022			thousands except per-unit amounts	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
Gross margin	Gross margin										Gross margin
Gross margin for natural-gas assets (1)	Gross margin for natural-gas assets (1)	$	409,634	$	393,673	$	803,307	$	850,980		Gross margin for natural-gas assets (1)	$	450,130	$	409,634	$	1,253,437	$	1,273,689
Gross margin for crude-oil and NGLs assets (1)	Gross margin for crude-oil and NGLs assets (1)	88,024		89,281		177,305		180,135			Gross margin for crude-oil and NGLs assets (1)	87,911		88,024		265,216		270,716
Gross margin for produced-water assets (1)	Gross margin for produced-water assets (1)	59,130		59,549		118,679		118,646			Gross margin for produced-water assets (1)	70,353		59,130		189,032		184,085
Per-Mcf Gross margin for natural-gas assets (2)	Per-Mcf Gross margin for natural-gas assets (2)	1.02		1.03		1.02		1.09			Per-Mcf Gross margin for natural-gas assets (2)	1.05		1.02		1.03		1.07
Per-Bbl Gross margin for crude-oil and NGLs assets (2)	Per-Bbl Gross margin for crude-oil and NGLs assets (2)	1.51		1.59		1.55		1.45			Per-Bbl Gross margin for crude-oil and NGLs assets (2)	1.40		1.51		1.50		1.42
Per-Bbl Gross margin for produced-water assets (2)	Per-Bbl Gross margin for produced-water assets (2)	0.68		0.68		0.68		0.80			Per-Bbl Gross margin for produced-water assets (2)	0.69		0.68		0.68		0.80
Adjusted gross margin	Adjusted gross margin										Adjusted gross margin
Adjusted gross margin for natural-gas assets	Adjusted gross margin for natural-gas assets	$	489,476	$	480,009	$	969,485	$	1,017,892		Adjusted gross margin for natural-gas assets	$	518,765	$	489,476	$	1,488,250	$	1,539,009
Adjusted gross margin for crude-oil and NGLs assets	Adjusted gross margin for crude-oil and NGLs assets	147,036		145,577		292,613		303,933			Adjusted gross margin for crude-oil and NGLs assets	139,430		147,036		432,043		457,158
Adjusted gross margin for produced-water assets	Adjusted gross margin for produced-water assets	70,890		69,569		140,459		138,596			Adjusted gross margin for produced-water assets	83,714		70,890		224,173		214,319
Per-Mcf Adjusted gross margin for natural-gas assets (3)	Per-Mcf Adjusted gross margin for natural-gas assets (3)	1.26		1.30		1.28		1.35			Per-Mcf Adjusted gross margin for natural-gas assets (3)	1.26		1.26		1.27		1.34
Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (3)	Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (3)	2.58		2.65		2.61		2.50			Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (3)	2.27		2.58		2.49		2.44
Per-Bbl Adjusted gross margin for produced-water assets (3)	Per-Bbl Adjusted gross margin for produced-water assets (3)	0.83		0.81		0.82		0.95			Per-Bbl Adjusted gross margin for produced-water assets (3)	0.84		0.83		0.83		0.94

(1)Excludes corporate-level depreciation and amortization.

(2)Average for period. Calculated as Gross margin for natural-gas assets, crude-oil and NGLs assets, or produced-water assets, divided by the respective total throughput (MMcf or MBbls) for natural-gas assets, crude-oil and NGLs assets, or produced-water assets.

(3)Average for period. Calculated as Adjusted gross margin for natural-gas assets, crude-oil and NGLs assets, or produced-water assets, divided by the respective total throughput (MMcf or MBbls) attributable to WES for natural-gas assets, crude-oil and NGLs assets, or produced-water assets.

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

thousands	thousands	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022				thousands	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
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)	$	259,516	$	208,341	$	467,857	$	632,841			Net income (loss)	$	284,398	$	259,516	$	752,255	$	906,422
Add:	Add:											Add:
Distributions from equity investments	Distributions from equity investments	54,075		51,975		106,050		121,811				Distributions from equity investments	41,562		54,075		147,612		180,768
Non-cash equity-based compensation expense	Non-cash equity-based compensation expense	7,665		7,199		14,864		14,781				Non-cash equity-based compensation expense	7,171		7,665		22,035		21,245
Interest expense	Interest expense	86,182		81,670		167,852		166,227				Interest expense	82,754		86,182		250,606		249,333
Income tax expense	Income tax expense	659		1,416		2,075		3,296				Income tax expense	905		659		2,980		3,683
Depreciation and amortization	Depreciation and amortization	143,492		144,626		288,118		273,618				Depreciation and amortization	147,363		143,492		435,481		430,455
Impairments	Impairments	234		52,401		52,635		90				Impairments	245		234		52,880		94
Other expense	Other expense	199		200		399		181				Other expense	1,269		199		1,668		346
Less:	Less:											Less:
Gain (loss) on divestiture and other, net	Gain (loss) on divestiture and other, net	(70)		(2,118)		(2,188)		(780)				Gain (loss) on divestiture and other, net	(1,480)		(70)		(3,668)		(884)
Gain (loss) on early extinguishment of debt	Gain (loss) on early extinguishment of debt	6,813		—		6,813		91				Gain (loss) on early extinguishment of debt	8,565		6,813		15,378		91
Equity income, net – related parties	Equity income, net – related parties	42,324		39,021		81,345		98,071				Equity income, net – related parties	35,494		42,324		116,839		139,388

Other income	Other income	2,872		1,215		4,087		106				Other income	27		2,872		4,114		164

Adjusted EBITDA attributable to noncontrolling interests (1)	Adjusted EBITDA attributable to noncontrolling interests (1)	11,737		11,015		22,752		27,989				Adjusted EBITDA attributable to noncontrolling interests (1)	12,134		11,737		34,886		41,395
Adjusted EBITDA	Adjusted EBITDA	$	488,346	$	498,695	$	987,041	$	1,087,368			Adjusted EBITDA	$	510,927	$	488,346	$	1,497,968	$	1,612,192
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	$	490,823	$	302,424	$	793,247	$	743,439			Net cash provided by operating activities	$	394,787	$	490,823	$	1,188,034	$	1,212,207
Interest (income) expense, net	Interest (income) expense, net	86,182		81,670		167,852		166,227				Interest (income) expense, net	82,754		86,182		250,606		249,333
Accretion and amortization of long-term obligations, net	Accretion and amortization of long-term obligations, net	(2,403)		(1,692)		(4,095)		(3,586)				Accretion and amortization of long-term obligations, net	(1,882)		(2,403)		(5,977)		(5,359)
Current income tax expense (benefit)	Current income tax expense (benefit)	728		492		1,220		1,376				Current income tax expense (benefit)	806		728		2,026		1,926
Other (income) expense, net	Other (income) expense, net	(2,872)		(1,215)		(4,087)		(61)				Other (income) expense, net	1,270		(2,872)		(2,817)		(117)

Distributions from equity investments in excess of cumulative earnings – related parties	Distributions from equity investments in excess of cumulative earnings – related parties	10,813		12,366		23,179		25,407				Distributions from equity investments in excess of cumulative earnings – related parties	8,536		10,813		31,715		41,058
Changes in assets and liabilities:	Changes in assets and liabilities:											Changes in assets and liabilities:
Accounts receivable, net	Accounts receivable, net	(4,078)		4,037		(41)		279,830				Accounts receivable, net	60,614		(4,078)		60,573		212,955
Accounts and imbalance payables and accrued liabilities, net	Accounts and imbalance payables and accrued liabilities, net	(36,885)		136,460		99,575		(82,909)				Accounts and imbalance payables and accrued liabilities, net	(12,535)		(36,885)		87,040		(65,069)
Other items, net	Other items, net	(42,225)		(24,832)		(67,057)		(14,366)				Other items, net	(11,289)		(42,225)		(78,346)		6,653
Adjusted EBITDA attributable to noncontrolling interests (1)	Adjusted EBITDA attributable to noncontrolling interests (1)	(11,737)		(11,015)		(22,752)		(27,989)				Adjusted EBITDA attributable to noncontrolling interests (1)	(12,134)		(11,737)		(34,886)		(41,395)
Adjusted EBITDA	Adjusted EBITDA	$	488,346	$	498,695	$	987,041	$	1,087,368			Adjusted EBITDA	$	510,927	$	488,346	$	1,497,968	$	1,612,192
Cash flow information	Cash flow information									Cash flow information
Net cash provided by operating activities	Net cash provided by operating activities	$	490,823	$	302,424	$	793,247	$	743,439			Net cash provided by operating activities	$	394,787	$	490,823	$	1,188,034	$	1,212,207
Net cash used in investing activities	Net cash used in investing activities	(151,490)		(179,178)		(330,668)		(170,947)				Net cash used in investing activities	(207,916)		(151,490)		(538,584)		(356,252)
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(238,025)		(297,257)		(535,282)		(677,057)				Net cash provided by (used in) financing activities	88,670		(238,025)		(446,612)		(898,861)

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

thousands	thousands	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022			thousands	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
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	$	490,823	$	302,424	$	793,247	$	743,439		Net cash provided by operating activities	$	394,787	$	490,823	$	1,188,034	$	1,212,207
Less:	Less:										Less:
Capital expenditures	Capital expenditures	161,482		173,088		334,570		191,357			Capital expenditures	201,857		161,482		536,427		341,505
Contributions to equity investments – related parties	Contributions to equity investments – related parties	22		110		132		5,040			Contributions to equity investments – related parties	1,021		22		1,153		8,899
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	10,813		12,366		23,179		25,407			Distributions from equity investments in excess of cumulative earnings – related parties	8,536		10,813		31,715		41,058
Free cash flow	Free cash flow	$	340,132	$	141,592	$	481,724	$	572,449		Free cash flow	$	200,445	$	340,132	$	682,169	$	902,861
Cash flow information	Cash flow information										Cash flow information
Net cash provided by operating activities	Net cash provided by operating activities	$	490,823	$	302,424	$	793,247	$	743,439		Net cash provided by operating activities	$	394,787	$	490,823	$	1,188,034	$	1,212,207
Net cash used in investing activities	Net cash used in investing activities	(151,490)		(179,178)		(330,668)		(170,947)			Net cash used in investing activities	(207,916)		(151,490)		(538,584)		(356,252)
Net cash provided by (used in) financing activities	Net cash provided by (used in) financing activities	(238,025)		(297,257)		(535,282)		(677,057)			Net cash provided by (used in) financing activities	88,670		(238,025)		(446,612)		(898,861)

Gross margin. Refer to Operating Results within this Item 2 for a discussion of the components of Gross margin as compared to the prior periods, including Service Revenues, Product Sales, Cost of Product (Residue purchases, NGLs purchases, and Other items), and Other Operating Expenses (Depreciation and amortization expense).

Gross margin increased by ~~$12.1~~$51.0 million for the three months ended ~~June~~September 30, 2023, due to (i) a ~~$6.7 million decrease in cost of product and (ii) a $4.3~~$37.7 million increase in total revenues and ~~other.~~other and (ii) a $17.2 million decrease in cost of product. These amounts were offset partially by a $3.9 million increase in depreciation and amortization.

Gross margin decreased by ~~$51.8~~$24.6 million for the ~~six~~nine months ended ~~June~~September 30, 2023, due to (i) a ~~$162.5~~$224.0 million decrease in total revenues and other and (ii) a ~~$14.5~~$5.0 million increase in depreciation and amortization. These amounts were offset partially by a ~~$125.2~~$204.4 million decrease in cost of product.

Net income (loss). Refer to Operating Results within this Item 2 for a discussion of the primary components of Net income (loss) as compared to the prior periods.

Net income (loss) increased by ~~$51.2~~$24.9 million for the three months ended ~~June~~September 30, 2023, primarily due to a $37.7 million increase in total revenues and other. This increase was offset partially by (i) a $6.8 million decrease in equity income, net – related parties and (ii) a $4.1 million decrease in other income (expense), net.

Net income (loss) decreased by $154.2 million for the nine months ended September 30, 2023, primarily due to (i) a ~~$36.8 million decrease in total operating expenses, (ii) a $6.8 million increase in gain (loss) on early extinguishment of debt, and (iii) a $4.3 million increase in total revenues and other.~~

~~Net income (loss) decreased by $165.0 million for the six months ended June 30, 2023, primarily due to (i) a $162.5~~$224.0 million decrease in total revenues and other and (ii) a ~~$16.7~~$22.5 million decrease in equity income, net – related parties. These amounts were offset partially by (i) a ~~$6.7~~$77.8 million decrease in total operating expenses and (ii) a $15.3 million increase in gain (loss) on early extinguishment of ~~debt and (ii) a $5.3 million decrease in total operating expenses.~~debt.

Net cash provided by operating activities. Refer to Historical cash flow within this Item 2 for a discussion of the primary components of Net cash provided by operating activities as compared to the prior periods.

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KEY PERFORMANCE METRICS


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

thousands except percentages and per-unit amounts	thousands except percentages and per-unit amounts	June 30, 2023		March 31, 2023		Inc/ (Dec)		June 30, 2023		June 30, 2022		Inc/ (Dec)		thousands except percentages and per-unit amounts	September 30, 2023		June 30, 2023		Inc/ (Dec)		September 30, 2023		September 30, 2022		Inc/ (Dec)

Adjusted gross margin	Adjusted gross margin	$	707,402	$	695,155	2	%	$	1,402,557	$	1,460,421	(4)	%	Adjusted gross margin	$	741,909	$	707,402	5	%	$	2,144,466	$	2,210,486	(3)	%
Per-Mcf Adjusted gross margin for natural-gas assets (1)	Per-Mcf Adjusted gross margin for natural-gas assets (1)	1.26		1.30		(3)	%	1.28		1.35		(5)	%	Per-Mcf Adjusted gross margin for natural-gas assets (1)	1.26		1.26		—	%	1.27		1.34		(5)	%
Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (1)	Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (1)	2.58		2.65		(3)	%	2.61		2.50		4	%	Per-Bbl Adjusted gross margin for crude-oil and NGLs assets (1)	2.27		2.58		(12)	%	2.49		2.44		2	%
Per-Bbl Adjusted gross margin for produced-water assets (1)	Per-Bbl Adjusted gross margin for produced-water assets (1)	0.83		0.81		2	%	0.82		0.95		(14)	%	Per-Bbl Adjusted gross margin for produced-water assets (1)	0.84		0.83		1	%	0.83		0.94		(12)	%
Adjusted EBITDA	Adjusted EBITDA	488,346		498,695		(2)	%	987,041		1,087,368		(9)	%	Adjusted EBITDA	510,927		488,346		5	%	1,497,968		1,612,192		(7)	%
Free cash flow	Free cash flow	340,132		141,592		140	%	481,724		572,449		(16)	%	Free cash flow	200,445		340,132		(41)	%	682,169		902,861		(24)	%

(1)Average for period. Calculated as Adjusted gross margin for natural-gas assets, crude-oil and NGLs assets, or produced-water assets, divided by the respective total throughput (MMcf or MBbls) attributable to WES for natural-gas assets, crude-oil and NGLs assets, or produced-water assets.

Adjusted gross margin. Adjusted gross margin increased by ~~$12.2~~$34.5 million for the three months ended ~~June~~September 30, 2023, primarily due to (i) increased throughput and deficiency fees at the ~~Chipeta,~~West Texas complex, and (ii) increased throughput at the DBM water systems and DJ Basin ~~and Granger complexes,~~complex. These increases were partially offset by (i) decreased processing fees at the Brasada complex and (ii) ~~an increase~~a decrease in distributions from ~~Saddlehorn.~~Mi Vida and Mont Belvieu JV.

Adjusted gross margin decreased by ~~$57.9~~$66.0 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to (i) a decrease in distributions from Cactus II, which was sold in the fourth quarter of 2022, (ii) decreased deficiency fees and throughput at the Chipeta complex, (iii) decreased throughput at the DJ Basin ~~complex, DJ Basin~~ oil system and Granger complex, ~~and~~ (iv) a decrease in distributions from Ranch Westex, which was acquired in the third quarter of 2022 and is included in the West Texas complex subsequent to the ~~acquisition.~~acquisition, and (v) decreased throughput partially offset by increased deficiency fees at the DJ Basin complex. These decreases were partially offset by (i) increased throughput at the West Texas ~~complex.~~

~~Per~~-~~Mcf Adjusted gross margin for natural~~-~~gas assets~~complex and (ii) increased throughput, partially offset by decreased ~~by $0.04 for~~deficiency fees at the ~~three months ended June 30, 2023, primarily due to higher throughput across several assets that have lower-than average per-Mcf margins as compared to our other natural-gas assets.~~DBM water systems.

Per-Mcf Adjusted gross margin for natural-gas assets decreased by $0.07 for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to ~~contract mix and~~ lower commodity prices and contract mix, partially offset by increased throughput at the West Texas complex.

Per-Bbl Adjusted gross margin for crude-oil and NGLs assets decreased by ~~$0.07~~$0.31 for the three months ended ~~June~~September 30, 2023, primarily due to ~~decreases~~(i) a decrease in ~~demand-fee revenue and~~distributions, coupled with an increase in throughput ~~at the DJ Basin oil system,~~from Whitethorn LLC, which has a ~~higher-than-average~~lower-than-average per-Bbl margin as compared to our other crude-oil and NGLs ~~assets.~~assets, and (ii) decreases in distributions from TEP and Mont Belvieu JV.

Per-Bbl Adjusted gross margin for crude-oil and NGLs assets increased by ~~$0.11~~$0.05 for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to (i) decreases in throughput and distributions from Cactus II, which was sold in the fourth quarter of 2022 and had lower-than-average per-Bbl margin as compared to our other crude-oil and NGLs assets and (ii) increases in distributions from FRP and TEP.

~~Per~~-~~Bbl Adjusted gross~~ These increases were partially offset by (i) decreases in distributions from Whitethorn LLC and Mont Belvieu JV, and (ii) decreases in throughput at the DJ Basin oil system which has a higher-than-average per-Bbl margin ~~for produced~~-~~water assets increased by $0.02 for the three months ended June 30, 2023, primarily due~~as compared to ~~increased throughput on certain fee-based contracts.~~our other crude-oil and NGLs assets.

Per-Bbl Adjusted gross margin for produced-water assets decreased by ~~$0.13~~$0.11 for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to a lower average fee resulting from a cost-of-service rate redetermination effective January 1, 2023, and lower deficiency fee revenues.

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Adjusted EBITDA. Adjusted EBITDA ~~decreased~~increased by ~~$10.3~~$22.6 million for the three months ended ~~June~~September 30, 2023, primarily due to (i) ~~an $11.7~~a $37.7 million increase in ~~property~~total revenues and other, ~~taxes and~~ (ii) a ~~$9.2 million increase in operation and maintenance expenses. These amounts were offset partially by (i) a $6.7~~$16.9 million decrease in cost of product (net of lower of cost or market inventory adjustments), ~~(ii)~~and (iii) a ~~$4.3~~$4.0 million decrease in property and other taxes. These amounts were offset partially by (i) a $21.0 million increase in ~~total revenues~~operation and ~~other,~~maintenance expenses and ~~(iii)~~(ii) a ~~$2.1~~$12.5 million ~~increase~~decrease in distributions from equity investments.

Adjusted EBITDA decreased by ~~$100.3~~$114.2 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to (i) a ~~$162.5~~$224.0 million decrease in total revenues and other, (ii) a ~~$60.5~~$74.5 million increase in operation and maintenance expenses, (iii) a ~~$15.8~~$33.2 million decrease in distributions from equity investments, and (iv) ~~an $8.0~~a $14.1 million increase in general and administrative expenses excluding non-cash equity-based compensation expense. These amounts were offset partially by (i) a ~~$125.5~~$204.5 million decrease in cost of product (net of lower of cost or market inventory adjustments) and (ii) a ~~$15.7~~$20.5 million decrease in property and other taxes.

Free cash flow. Free cash flow ~~increased~~decreased by ~~$198.5~~$139.7 million for the three months ended ~~June~~September 30, 2023, primarily due to (i) a ~~$188.4~~$96.0 million ~~increase in net cash provided by operating activities and (ii) an $11.6 million~~ decrease ~~in capital expenditures.~~

~~Free cash flow decreased by $90.7 million for the six months ended June 30, 2023, primarily due to a $143.2 million increase in capital expenditures, offset partially by (i) a $49.8 million increase~~ in net cash provided by operating activities and (ii) a ~~$4.9~~$40.4 million increase in capital expenditures.

Free cash flow decreased by $220.7 million for the nine months ended September 30, 2023, primarily due to a $194.9 million increase in capital expenditures (ii) a $24.2 million decrease in net cash provided by operating activities, and (iii) a $9.3 million decrease in distributions from equity investments in excess of cumulative earnings. These amounts were offset partially by a $7.7 million decrease in contributions to equity investments.

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

LIQUIDITY AND CAPITAL RESOURCES

Our primary cash uses include equity and debt service, operating expenses, and capital expenditures. Our sources of liquidity as of ~~June~~September 30, 2023, 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 requirements.

The amount of future distributions to unitholders will be determined by the Board on a quarterly basis. 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) 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. The Board declared a cash distribution to unitholders for the ~~second~~third quarter of 2023 of ~~$0.5625~~$0.5750 per unit, a ~~12.5%~~2.2% increase from the prior quarter, or ~~$221.4~~$223.4 million in the aggregate. The cash distribution is payable on ~~August 14,~~November 13, 2023, to our unitholders of record at the close of business on ~~July 31,~~November 1, 2023.

To facilitate the distribution of available cash, during 2022 we adopted a financial policy that provided for an additional distribution (“Enhanced Distribution”) to be paid in conjunction with the regular first-quarter distribution of the following year (beginning in 2023), in a target amount equal to Free cash flow generated in the prior year after subtracting Free cash flow used for the prior year’s debt repayments, regular-quarter distributions, and unit repurchases. This Enhanced Distribution is subject to Board discretion, the establishment of cash reserves for the proper conduct of our business and is also contingent on the attainment of prior year-end net leverage thresholds (the ratio of our total principal debt outstanding less total cash on hand as of the end of such period, as compared to our trailing-twelve-months Adjusted EBITDA), after taking the Enhanced Distribution for such prior year into effect. Free cash flow and Adjusted EBITDA are defined under the caption Reconciliation of Non-GAAP Financial Measures within this Item 2. In April 2023, the Board approved an Enhanced Distribution of $0.356 per unit, or $140.1 million, related to our 2022 performance, which was paid in conjunction with our regular first-quarter 2023 distribution on May 15, 2023.

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In 2022, we announced a common-unit buyback program of up to $1.25 billion 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. 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 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 ~~six~~nine months ended ~~June~~September 30, 2023, we repurchased ~~287,322~~5,387,322 common units, which includes 5,100,000 common units repurchased from Occidental, for an aggregate purchase price of ~~$7.1~~$134.6 million. The units were canceled immediately upon receipt. As of ~~June~~September 30, 2023, we had an authorized amount of ~~$755.3~~$627.8 million remaining under the program.

For the year ended December 31, 2023, capital expenditures are expected to range between $700.0 million to $800.0 million (accrual-based, includes equity investments, excludes capitalized interest, and excludes capital expenditures associated with the 25% third-party interest in Chipeta), representing a $125.0 million increase to the midpoint of our previously announced guidance in February 2023. Total-year capital expenditures guidance includes capital expenditures attributable to (i) a portion of Mentone Train III, (ii) a portion of the North Loving plant, a new 250 MMcf/d cryogenic processing plant in the North Loving area of our West Texas complex that was sanctioned in May 2023, and (iii) additional expansion capital needed to support new commercial activity.

Management continuously monitors our leverage position and other financial projections to manage the capital structure according to long-term objectives. We may, from time to time, seek to retire, rearrange, or amend some or all of our outstanding debt or financing 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 and the amounts involved may be material. 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 ~~June~~September 30, 2023, we had a ~~$175.7~~$499.9 million working capital surplus, which we define as the amount by which current assets exceed current liabilities. As of ~~June~~September 30, 2023, there was $2.0 billion available for borrowing under the RCF. See Note 8—9—Selected Components of Working Capital and Note 9—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 include maintenance capital expenditures, which include those expenditures required to maintain existing operating capacity and service capability of our assets, and expansion capital expenditures, which include expenditures to construct new midstream infrastructure and expenditures incurred to reduce costs, increase revenues, or increase system throughput or capacity from current 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 expenditures as presented in the consolidated statements of cash flows and capital incurred were as follows:


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

thousands	thousands	2023		2022			thousands	2023		2022

Acquisitions							Acquisitions	$	—	$	41,018
Capital expenditures (1)	Capital expenditures (1)	$	334,570	$	191,357		Capital expenditures (1)	536,427		341,505
Capital incurred (1)	Capital incurred (1)	368,683		207,996			Capital incurred (1)	566,224		377,650

(1)For the ~~six~~nine months ended ~~June~~September 30, 2023 and 2022, included ~~$5.1~~$8.6 million and ~~$2.0~~$3.5 million, respectively, of capitalized interest.

Acquisitions for the nine months ended September 30, 2022, include the acquisition of the remaining 50% interest in Ranch Westex (see Acquisitions and Divestitures within this Item 2).

Capital expenditures increased by ~~$143.2~~$194.9 million for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to increases of (i) ~~$66.5~~$91.2 million at the West Texas complex, primarily attributable to facility expansion, including ongoing construction of Mentone Train III and engineering and equipment milestone payments for the North Loving Plant, and pipeline projects, (ii) ~~$54.3~~$71.4 million at the DBM water systems due to construction of additional water-disposal wells and facilities, pipeline build-out, and ~~pipeline~~replacement projects, ~~and~~ (iii) ~~$17.1~~$30.5 million at the DBM oil system, primarily related to an increase in pipeline, oil treating, and oil pumping projects, and (iv) $8.1 million at the DJ Basin oil system due to an increase in pipeline projects.

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:


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

thousands	thousands	2023		2022		thousands	2023		2022
Net cash provided by (used in):	Net cash provided by (used in):					Net cash provided by (used in):
Operating activities	Operating activities	$	793,247	$	743,439	Operating activities	$	1,188,034	$	1,212,207
Investing activities	Investing activities	(330,668)		(170,947)		Investing activities	(538,584)		(356,252)
Financing activities	Financing activities	(535,282)		(677,057)		Financing activities	(446,612)		(898,861)
Net increase (decrease) in cash and cash equivalents	Net increase (decrease) in cash and cash equivalents	$	(72,703)	$	(104,565)	Net increase (decrease) in cash and cash equivalents	$	202,838	$	(42,906)

Operating activities. Net cash provided by operating activities ~~increased~~decreased for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily due to ~~the impact of changes in assets and liabilities. This increase was partially offset by~~ (i) lower cash operating income, (ii) lower distributions from equity investments, and (iii) higher interest expense. These increases were partially offset by the impact of changes in assets and liabilities. Refer to Operating Results within this Item 2 for a discussion of our results of operations as compared to the prior periods.

Investing activities. Net cash used in investing activities for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily included the following:

•$~~334.6~~536.4 million of capital expenditures, primarily related to construction, expansion, and asset-integrity projects at the West Texas complex, DBM water systems, DBM oil system, and DJ Basin complex;

•$~~19.1~~32.7 million of increases to materials and supplies inventory; and

•$~~23.2~~31.7 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~~nine months ended ~~June~~September 30, 2022, primarily included the following:

•$~~191.4~~341.5 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;

52•$41.0 million of cash paid for the acquisition of the remaining 50% interest in Ranch Westex (see Acquisitions and Divestitures within this Item 2);

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•$~~5.0~~8.9 million of capital contributions primarily paid to Red Bluff Express;

•$7.0 million of increases to materials and supplies inventory; and

•$~~25.4~~41.1 million of distributions received from equity investments in excess of cumulative earnings.

Financing activities. Net cash used in financing activities for the ~~six~~nine months ended ~~June~~September 30, 2023, primarily included the following:

•$~~595.0~~845.0 million of repayments of outstanding borrowings under the RCF;

•$~~548.2~~778.3 million of distributions paid to WES unitholders and noncontrolling interest owners;

•$259.8 million to purchase and retire portions of certain of WES Operating’s senior notes via open-market repurchases;

•$213.1 million to redeem the total principal amount outstanding on the Floating-Rate Senior Notes due 2023 at par value;

•$~~110.2 million to purchase and retire portions of certain of WES Operating’s senior notes via open-market repurchases;~~

•~~$7.1~~134.6 million of unit repurchases;

•$~~740.9~~740.6 million of net proceeds from the 6.150% Senior Notes due 2033 issued in April 2023, which were used to repay borrowings under the RCF and for general partnership purposes;

•$595.1 million of net proceeds from the 6.350% Senior Notes due 2029 issued in September 2023, which were used to fund a portion of the aggregate purchase price for the Meritage acquisition, to pay related costs and expenses, and for general partnership purposes; and

•$~~220.0~~470.0 million of borrowings under the RCF, which were used for general partnership purposes.

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

•$~~883.5~~765.0 million of repayments of outstanding borrowings under the RCF;

•$538.7 million of distributions paid to WES unitholders;

•$502.2 million to redeem the total principal amount outstanding of WES Operating’s 4.000% Senior Notes due ~~2022 and repay borrowings under the RCF;~~2022;

•$~~340.9 million of distributions paid to WES unitholders;~~

•~~$79.2~~447.1 million of unit repurchases;

•$~~8.8~~20.2 million of distributions paid to the noncontrolling interest owner of WES Operating;

•$~~3.2~~5.0 million of distributions paid to the noncontrolling interest owner of Chipeta;

•$~~634.0~~1,390.0 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; and

•$~~13.0~~1.5 million of increases in outstanding checks.

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Debt and credit facilities. As of ~~June~~September 30, 2023, the carrying value of outstanding debt was ~~$6.8~~$7.3 billion, we have no borrowings due within the next year, and have $2.0 billion of available borrowing capacity under WES Operating’s $2.0 billion RCF.

During the ~~second quarter of~~nine months ended September 30, 2023, WES Operating (i) completed the public offering of $600.0 million in aggregate principal amount of 6.350% Senior Notes due 2029, (ii) completed the public offering of $750.0 million in aggregate principal amount of 6.150% Senior Notes due 2033, ~~(ii)~~(iii) entered into an amendment to our RCF to, among other things, extend the maturity date to April 2028 and provide for a maximum borrowing capacity up to $2.0 billion, expandable to a maximum of $2.5 billion, through the maturity date, ~~and (iii)~~(iv) purchased and retired ~~$117.6~~$276.7 million of certain of its senior notes via open-market ~~repurchases.~~repurchases, and (v) redeemed the total principal amount outstanding on the Floating-Rate Senior Notes due 2023 at par value with cash on hand.

In May 2023, Fitch Ratings upgraded WES Operating’s long-term debt from “BB+” to “BBB-.” WES Operating’s senior unsecured debt ratings is now investment grade at Standard and Poor’s, Moody’s Investors Services, and Fitch Ratings. As a result of the upgrade, annualized borrowing costs will decrease by $6.9 million on WES Operating’s senior notes that are subject to effective interest-rate adjustments from a change in credit rating.

~~Subsequent to June 30, 2023, WES Operating purchased and retired $159.1 million of certain of its senior notes via open-market repurchases.~~

For additional information on our senior notes and the RCF, see Note 9—10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Offload commitments. We have entered into offload agreements with third parties providing firm-processing capacity through 2025. As of ~~June~~September 30, 2023, we have future minimum payments under offload agreements totaling ~~$9.2~~$4.8 million for the remainder of 2023 and a total of ~~$11.7~~$11.6 million in years thereafter.

Pipeline commitments. We have entered into transportation contracts with volume commitments on multiple pipelines through 2033. As of ~~June~~September 30, 2023, we have estimated future minimum-volume-commitment fees totaling ~~$3.1~~$1.6 million for the remainder of 2023, and a total of ~~$51.7~~$51.6 million in years thereafter.

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- or NGLs-imbalance agreements. We examine and monitor the creditworthiness of customers and may establish credit limits for customers. 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. See Note 5—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.

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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				Six Months Ended				Three Months Ended				Nine Months Ended

thousands	thousands	June 30, 2023		March 31, 2023		June 30, 2023		June 30, 2022			thousands	September 30, 2023		June 30, 2023		September 30, 2023		September 30, 2022
Net income (loss) attributable to WES	Net income (loss) attributable to WES	$	252,921	$	203,645	$	456,566	$	615,034		Net income (loss) attributable to WES	$	277,296	$	252,921	$	733,862	$	880,779
Limited partner interest in WES Operating not held by WES (1)	Limited partner interest in WES Operating not held by WES (1)	5,185		4,161		9,346		12,584			Limited partner interest in WES Operating not held by WES (1)	5,670		5,185		15,016		18,016
General and administrative expenses (2)	General and administrative expenses (2)	1,186		232		1,418		1,362			General and administrative expenses (2)	509		1,186		1,927		1,764
Other income (expense), net	Other income (expense), net	(129)		(25)		(154)		(7)			Other income (expense), net	(60)		(129)		(214)		(18)

Net income (loss) attributable to WES Operating	Net income (loss) attributable to WES Operating	$	259,163	$	208,013	$	467,176	$	628,973		Net income (loss) attributable to WES Operating	$	283,415	$	259,163	$	750,591	$	900,541

(1)Represents the portion of net income (loss) allocated to the limited partner interest 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.

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:


		Six Months Ended June 30,					Nine Months Ended September 30,
thousands	thousands	2023		2022		thousands	2023		2022
WES net cash provided by operating activities	WES net cash provided by operating activities	$	793,247	$	743,439	WES net cash provided by operating activities	$	1,188,034	$	1,212,207
General and administrative expenses (1)	General and administrative expenses (1)	1,418		1,362		General and administrative expenses (1)	1,927		1,764
Non-cash equity-based compensation expense	Non-cash equity-based compensation expense	(287)		(276)		Non-cash equity-based compensation expense	(434)		(423)
Changes in working capital	Changes in working capital	(14,327)		(7,835)		Changes in working capital	(15,223)		(9,101)
Other income (expense), net	Other income (expense), net	(154)		(7)		Other income (expense), net	(214)		(18)

WES Operating net cash provided by operating activities	WES Operating net cash provided by operating activities	$	779,897	$	736,683	WES Operating net cash provided by operating activities	$	1,174,090	$	1,204,429

WES net cash provided by (used in) financing activities	WES net cash provided by (used in) financing activities	$	(535,282)	$	(677,057)	WES net cash provided by (used in) financing activities	$	(446,612)	$	(898,861)
Distributions to WES unitholders (2)	Distributions to WES unitholders (2)	533,556		340,946		Distributions to WES unitholders (2)	754,998		538,690
Distributions to WES from WES Operating (3)	Distributions to WES from WES Operating (3)	(545,277)		(431,653)		Distributions to WES from WES Operating (3)	(894,510)		(988,395)
Increase (decrease) in outstanding checks	Increase (decrease) in outstanding checks	—		104		Increase (decrease) in outstanding checks	(3)		103
Unit repurchases	Unit repurchases	7,102		79,217		Unit repurchases	134,602		447,075
Other	Other	13,415		7,007		Other	14,371		7,942
WES Operating net cash provided by (used in) financing activities	WES Operating net cash provided by (used in) financing activities	$	(526,486)	$	(681,436)	WES Operating net cash provided by (used in) financing activities	$	(437,154)	$	(893,446)

(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 3—4—Partnership Distributions and Note 4—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 3—4—Partnership Distributions and Note 4—5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

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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 3—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, 2022.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity-price risk. There have been no significant changes to our commodity-price risk discussion from the disclosure set forth under Part II, Item 7A in our Form 10-K for the year ended December 31, 2022, except as noted below and in Outlook under Part I, Item 2 of this Form 10-Q.

For the ~~six~~nine months ended ~~June~~September 30, 2023, 95% 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 12 months, excluding the effect of imbalances.

Interest-rate risk. The Federal Open Market Committee increased its target range seven times for the federal funds rate in 2022 and increased its target range ~~three~~four times during the ~~six~~nine months ended ~~June~~September 30, 2023. Any future increases in the federal funds rate likely will result in an increase in financing costs. As of ~~June~~September 30, 2023, WES Operating had no outstanding borrowings under the RCF that bear interest at a rate based on the Secured Overnight Financing Rate (“SOFR”) or an alternative base rate at WES Operating’s option. While a 10% change in the applicable benchmark interest rate would not materially impact interest expense on our outstanding borrowings at ~~June~~September 30, 2023, it would impact the fair value of the senior notes.

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

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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 ~~June~~September 30, 2023.

Changes in Internal Control Over Financial Reporting. On April 1, 2023, WES and WES Operating implemented a new Enterprise Resource Planning (“ERP”) system. As a result of this implementation, certain internal controls over financial reporting have been automated, modified, or implemented to address the new environment associated with the implementation of this type of system. While WES and WES Operating believe that this system will strengthen the internal control system, there are inherent risks in implementing any new system and WES and WES Operating will continue to evaluate these control changes as part of their assessments of internal control over financial reporting. Other than the ERP implementation, there have been no changes in WES or WES Operating’s internal control over financial reporting that occurred during the quarter ended ~~June~~September 30, 2023, that materially affected, or are reasonably likely to materially affect, WES or WES Operating’s internal control over financial reporting during the most recent fiscal quarter.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

In 2020, the U.S. Department of Justice, on behalf of the U.S. Environmental Protection Agency (the “EPA”), and the State of Colorado, on behalf of the Colorado Department of Public Health and the Environment (the “CDPHE”) 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 and the Colorado Air Pollution Prevention and Control Act at its Fort Lupton, Platte Valley, and Lancaster facilities in the DJ Basin complex. We reached an agreement to resolve these allegations with the EPA and the CDPHE pursuant to a consent decree that became effective on June 15, 2023. While such resolution includes an injunctive relief component and payment of a civil penalty, which exceeds the disclosure threshold amount required by Item 103 of Regulation S-K, the resolution of these claims did not have a material impact on 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 treated 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.

On November 22, 2022, WGR filed suit against Enterprise Crude Oil LLC (“ECO”) in the District Court of Harris County, Texas. Our lawsuit alleges that ECO breached a contract related to the Whitethorn joint venture pursuant to which ECO must share with WGR certain of the profits and losses generated by ECO’s hydrocarbon trading activity conducted utilizing the Whitethorn pipeline. Specifically, we claim that ECO has engaged in trades knowing that the revenue to be realized would be less than the minimum floor set under the contract and has failed to allocate revenues and expenses as prescribed by the contract, resulting in improper losses to WGR. Enterprise has filed a counterclaim to our lawsuit, alleging that, between 2017 and 2019, it had mistakenly overpaid WGR approximately $12.0 million in trading profits and seeking recovery of such amount. We also claim that Enterprise Crude Pipeline LLC, as operator of the Whitethorn pipeline, failed to act as a reasonable and prudent operator of the Whitethorn pipeline and for the sole benefit of the Whitethorn joint venture as contractually required. 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, 2022, together with all of the other information included in this document, and in our other public filings, press releases, and public discussions with management.

We may fail to successfully combine our business with the assets and business of Meritage, which could have an adverse impact on our future results.

The Meritage acquisition closed on October 13, 2023. The integration of these acquired assets involve potential risks, including the failure to realize expected profitability, growth, or accretion; environmental or regulatory compliance matters or liabilities; diversion of management’s attention from our existing business; and the incurrence of unanticipated liabilities and costs for which indemnification is unavailable or inadequate.

If any of the risks described above or other anticipated or unanticipated liabilities were to materialize, it could have an adverse effect on our business, financial condition, and results of operations.

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 or in privately negotiated transactions under the $1.25 billion Purchase Program during the ~~second~~third quarter of 2023:

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, 2023 — $ — — $ 755,348,136
May 1-31, 2023 1,634 24.99 1,634 755,307,310
June 1-30, 2023 — — — 755,307,310
Total 1,634 24.99 1,634


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, 2023	—	$	—	—	$	755,307,310
August 1-31, 2023	—	—		—	755,307,310
September 1-30, 2023	5,100,000	25.00		5,100,000	627,807,310
Total	5,100,000	25.00		5,100,000

______________________________________________________________________________________

(1)In 2022, the Board authorized WES to buy back up to $1.25 billion of our common units through December 31, 2024. See Note 4—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.

Item 5. Other Information

Insider Trading Arrangements

Rule 10b5-1 under the Exchange Act provides an affirmative defense that enables prearranged transactions in securities in a manner that avoids concerns about initiating transactions at a future date while possibly in possession of material nonpublic information. Our Insider Trading Policy permits our directors and executive officers to enter into trading plans designed to comply with Rule 10b5-1. During the three months ended ~~June~~September 30, 2023, none of our executive officers or directors adopted or terminated a Rule 10b5-1 trading plan or adopted or terminated a non-Rule 10b5-1 trading arrangement (as defined in Item 408(c) of Regulation S-K).

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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	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	Exhibit Number			Description	Exhibit Number			Description
		4.	19	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).		4.	19	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).
		4.	20	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).		4.	20	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).
		4.	21	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).		4.	21	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).
		4.	22	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).		4.	22	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).
		4.	23	Twelfth Supplemental Indenture, dated as of April 4, 2023, by and between Western Midstream Operating, LP, as Issuer, and Computershare Trust Company, 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 April 5, 2023, File No. 001-34046).		4.	23	Twelfth Supplemental Indenture, dated as of April 4, 2023, by and between Western Midstream Operating, LP, as Issuer, and Computershare Trust Company, 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 April 5, 2023, File No. 001-34046).
		4.	24	Form of 6.150% Senior Notes due 2033 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on April 5, 2023, File No. 001-34046).		4.	24	Form of 6.150% Senior Notes due 2033 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on April 5, 2023, File No. 001-34046).
†		10.	1	Second Amendment to Gas Gathering Agreement by and between Delaware Basin Midstream LLC and Anadarko E&P Onshore LLC, effective as of the May 1, 2023.
						4.	25	Thirteenth Supplemental Indenture, dated as of September 29, 2023, by and between Western Midstream Operating, LP, as Issuer, and Computershare Trust Company, 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 September 29, 2023, File No. 001-34046).
						4.	26	Form of 6.350% Senior Notes due 2029 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1 to Western Midstream Operating, LP’s Current Report on Form 8-K filed on September 29, 2023, File No. 001-34046).

*	*	31.	1	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.	1	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.	2	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.	2	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.	3	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.	3	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.	4	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.	*	31.	4	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.	1	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.	1	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.	2	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 Operating, LP.	**	32.	2	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 Operating, LP.
*	*	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.
†			~~Portions of this exhibit have been omitted as confidential pursuant to Item 601(b)(10) of Regulation S-K or a request for confidential treatment.~~
‡			~~Management contracts or compensatory plans or arrangements required to be filed pursuant to Item 15.~~

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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

~~August 8,~~November 1, 2023
			/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 8,~~November 1, 2023
			/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

~~August 8,~~November 1, 2023
			/s/ Michael P. Ure
			Michael P. Ure President and Chief Executive Officer Western Midstream Operating GP, LLC (as general partner of Western Midstream Operating, LP)

~~August 8,~~November 1, 2023
			/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)

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