UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


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

For the quarterly period ended ~~March 31,~~June 30, 2019


¨☐	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:		Former Name:
Western Midstream Partners, LP	1201 Lake Robbins Drive	The Woodlands,	Texas	77380	(832)	636-6000	Western Gas Equity Partners, LP
Western Midstream Operating, LP	1201 Lake Robbins Drive	The Woodlands,	Texas	77380	(832)	636-6000	Western Gas Partners, LP

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



	~~Address~~Title of ~~principal executive offices:~~each class	~~Zip Code:~~Trading symbol	~~Registrant’s telephone number, including area code:~~Name of exchange on which registered	~~Former Name:~~Common units outstanding as of July 29, 2019:
Western Midstream Partners, LP	~~1201 Lake Robbins Drive~~ ~~The Woodlands, Texas~~Common units	~~77380~~WES	~~(832) 636-6000~~New York Stock Exchange	~~Western Gas Equity Partners, LP~~453,008,854
Western Midstream Operating, LP	~~1201 Lake Robbins Drive~~ ~~The Woodlands, Texas~~None	~~77380~~None	~~(832) 636-6000~~None	~~Western Gas Partners, 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	þ	No	¨
Western Midstream Operating, LP	Yes	þ	No	¨

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



Western Midstream Partners, LP	Yes	þ	No	¨
Western Midstream Operating, LP	Yes	þ	No	¨

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~~ þ Accelerated Filer	Accelerated ~~filer~~ ¨ Filer	Non-accelerated ~~filer~~ ¨ Filer	Smaller ~~reporting company~~ ¨ Reporting Company	Emerging ~~growth company~~ Growth Company
Western Midstream Partners, LP	þ	¨	¨	☐	☐
Western Midstream Operating, LP	Large ~~accelerated filer~~ þ Accelerated Filer	Accelerated ~~filer~~ ¨ Filer	Non-accelerated ~~filer~~ ¨ Filer	Smaller ~~reporting company~~ ¨ Reporting Company	Emerging ~~growth company~~ Growth Company
Western Midstream Operating, LP	þ	¨	¨	☐	☐

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~~ ¨ No þ
~~Western Midstream Operating, LP~~	~~Yes~~ ¨ No þ

~~Common units outstanding as of April 29, 2019:~~



Western Midstream Partners, LP	~~452,990,862~~Yes	☐	No	þ
Western Midstream Operating, LP	~~None~~Yes	☐	No	þ

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 six months ended ~~March 31,~~June 30, 2019 and 2018	7
		Consolidated Balance Sheets as of ~~March 31,~~June 30, 2019, and December 31, 2018	8
		Consolidated Statements of Equity and Partners’ Capital for the three and six months ended ~~March 31,~~June 30, 2019 and 2018	9
		Consolidated Statements of Cash Flows for the ~~three~~six months ended ~~March 31,~~June 30, 2019 and 2018	10
		~~Western Midstream Operating, LP~~
		~~Consolidated Statements of Operations for the three months ended March 31, 2019 and 2018~~	11
		Western Midstream Operating, LP
		Consolidated ~~Balance Sheets as~~Statements of ~~March 31,~~Operations for the three and six months ended June 30, 2019 and ~~December 31,~~ 2018	12
		Consolidated ~~Statements~~Balance Sheets as of ~~Equity and Partners’ Capital for the three months ended March 31,~~June 30, 2019, and December 31, 2018	13
		Consolidated Statements of ~~Cash Flows~~Equity and Partners’ Capital for the three and six months ended ~~March 31,~~June 30, 2019 and 2018	14
		~~Notes to~~ Consolidated ~~Financial~~ Statements of Cash Flows for the six months ended June 30, 2019 and 2018	1516
		Notes to Consolidated Financial Statements	17
		Note 1. Description of Business and Basis of Presentation	1517
		Note 2. Revenue from Contracts with Customers	20
		~~Note 3. Acquisitions and Divestitures~~	22
		Note ~~4. Partnership Distributions~~3. Acquisitions and Divestitures	24
		Note ~~5. Equity and Partners’ Capital~~4. Partnership Distributions	2526
		Note ~~6. Transactions with Affiliates~~5. Equity and Partners’ Capital	28
		Note ~~7. Property, Plant and Equipment~~6. Transactions with Affiliates	3231
		Note ~~8. Equity Investments~~	33
		~~Note 9. Components of Working Capital~~	34
		~~Note 10. Debt~~7. Property, Plant and ~~Interest Expense~~Equipment	35
		Note ~~11. Leases~~8. Equity Investments	36
		Note 9. Components of Working Capital	37
		Note 10. Debt and Interest Expense	38
		Note 11. Leases	41
		Note 12. Commitments and Contingencies	3943
	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	40
		~~Cautionary Note Regarding Forward-Looking Statements~~	40
		~~Executive Summary~~	42
		~~Acquisitions and Divestitures~~	44
		~~Equity Offerings~~Cautionary Note Regarding Forward-Looking Statements	4544
		~~Results of Operations~~Executive Summary	46
		~~Operating Results~~Acquisitions and Divestitures	4648
		~~Key Performance Metrics~~Equity Offerings	5249
		~~Liquidity and Capital Resources~~Results of Operations	50
		Operating Results	50
		Key Performance Metrics	57
		Liquidity and Capital Resources	62
		Items Affecting the Comparability of Financial Results with WES Operating	6368
		Contractual Obligations	6570
		Off-Balance Sheet Arrangements	6570
		Recent Accounting Developments	6570
	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	6570
	Item 4.	Controls and Procedures	6671
PART II		OTHER INFORMATION
	Item 1.	Legal Proceedings	6671
	Item 1A.	Risk Factors	6772
	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6975
	Item 6.	Exhibits	7076

COMMONLY USED TERMS AND DEFINITIONS

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

Affiliates: Subsidiaries of Anadarko, excluding us, but including equity interests in Fort Union, White Cliffs, Rendezvous, the Mont Belvieu JV, TEP, TEG, FRP, Whitethorn LLC, Cactus II, Saddlehorn, Panola, Mi Vida, Ranch Westex and Red Bluff Express.

AMA: The Anadarko Midstream Assets, which are comprised of the Wattenberg processing plant, Wamsutter pipeline, DJ Basin oil system, DBM oil system, APC water systems, the 20% interest in Saddlehorn, the 15% interest in Panola, the 50% interest in Mi Vida and the 50% interest in Ranch Westex.

AMH: APC Midstream Holdings, LLC.

Anadarko or APC: Anadarko Petroleum Corporation and its subsidiaries, excluding us and the general partner.

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

Bbls/d: Barrels per day.

Board of Directors: The board of directors of the general partner.

Btu: British thermal unit; the approximate amount of heat required to raise the temperature of one pound of water by one degree Fahrenheit.

Cactus II: Cactus II Pipeline LLC.

~~Chevron:~~ ~~Chevron Corporation.~~

~~Chevron Merger:~~ ~~Chevron’s acquisition by merger of Anadarko pursuant to, and subject to the conditions of, the Chevron Merger Agreement.~~

~~Chevron Merger Agreement:~~ ~~Agreement and Plan of Merger, dated as of April 11, 2019, by and among Chevron Corporation, Justify Merger Sub 1 Inc., Justify Merger Sub 2 Inc. and Anadarko.~~

Chipeta: Chipeta Processing, LLC.

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

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

DBM: Delaware Basin Midstream, LLC.

DBM water systems: The produced water gathering and disposal systems in West Texas, including the APC water systems acquired as part of the acquisition of AMA.

DJ Basin complex: The Platte Valley system, Wattenberg system, Lancaster plant and Wattenberg processing plant (acquired as part of the acquisition of AMA).

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

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

Fort Union: Fort Union Gas Gathering, LLC.

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

FRP: Front Range Pipeline LLC.

GAAP: Generally accepted accounting principles in the United States.

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

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

IDRs: Incentive distribution rights.

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.

IPO: Initial public offering.

LIBOR: London Interbank Offered Rate.

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

MBbls/d: Thousand barrels per day.

Mcf: Thousand cubic feet.

Merger: The merger of Clarity Merger Sub, LLC, a wholly owned subsidiary of the Partnership, with and into WES Operating, with WES Operating continuing as the surviving entity and a subsidiary of the Partnership, which closed on February 28, 2019.

Merger Agreement: The Contribution Agreement and Agreement and Plan of Merger, dated November 7, 2018, by and among the Partnership, WES Operating, Anadarko and certain of their affiliates, pursuant to which the parties thereto agreed to effect the Merger and certain other transactions.

MGR: Mountain Gas Resources, LLC.

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

Mi Vida: Mi Vida JV LLC.

MMBtu: Million British thermal units.

MMcf: Million cubic feet.

MMcf/d: Million cubic feet per day.

Mont Belvieu JV: Enterprise EF78 LLC.

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

NYSE: New York Stock Exchange.

Occidental: Occidental Petroleum Corporation.

Occidental Merger: Occidental’s acquisition by merger of Anadarko pursuant to, and subject to the conditions of, the Occidental Merger Agreement.

Occidental Merger Agreement: Agreement and Plan of Merger, dated as of May 9, 2019, by and among Occidental, Baseball Merger Sub 1, Inc. and Anadarko.

Panola: Panola Pipeline Company, LLC.

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

Ranch Westex: Ranch Westex JV LLC.

RCF: WES Operating’s senior unsecured revolving credit facility.

Red Bluff Express: Red Bluff Express Pipeline, LLC.

Red Desert complex: The Patrick Draw processing plant, the Red Desert processing plant, associated gathering lines, and related facilities.

Rendezvous: Rendezvous Gas Services, LLC.

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

ROTF: Regional oil treating facility.

Saddlehorn: Saddlehorn Pipeline Company, LLC.

SEC: U.S. Securities and Exchange Commission.

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.

TEP: Texas Express Pipeline LLC.

Term loan facility: WES Operating’s senior unsecured credit facility entered into in connection with the Merger.

WES Operating: Western Midstream Operating, LP, formerly Western Gas Partners, LP.

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, all of which were combined into a single complex effective January 1, 2018.

WGP RCF: The senior secured revolving credit facility that Western Gas Equity Partners, LP entered into in March 2016 and matured in March 2019.

White Cliffs: White Cliffs Pipeline, LLC.

Whitethorn LLC: Whitethorn Pipeline Company LLC.

~~364-day Facility:~~ ~~WES Operating’s 364-day senior unsecured credit facility.~~

PART I. FINANCIAL INFORMATION (UNAUDITED)

Item 1.Financial Statements

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except per-unit amounts	2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾
Revenues and other – affiliates
Service revenues – fee based	$	326,642		$	222,038		$	343,484		$	234,512		$	670,126		$	456,550
Service revenues – product based	1,352			631			634			538			1,986			1,169
Product sales	50,443			62,507			41,066			54,494			91,509			117,001
Total revenues and other – affiliates	378,437			285,176			385,184			289,544			763,621			574,720
Revenues and other – third parties
Service revenues – fee based	253,332			171,735			250,060			197,349			503,392			369,084
Service revenues – product based	18,027			22,792			16,041			22,124			34,068			44,916
Product sales	21,690			21,118			33,403			8,821			55,093			29,939
Other	397			233			366			240			763			473
Total revenues and other – third parties	293,446			215,878			299,870			228,534			593,316			444,412
Total revenues and other	671,883			501,054			685,054			518,078			1,356,937			1,019,132
Equity income, net – affiliates	57,992			30,229			63,598			49,430			121,590			79,659
Operating expenses
Cost of product ⁽²⁾	114,063			94,318			122,877			95,656			236,940			189,974
Operation and maintenance ⁽²⁾	142,829			96,795			148,431			112,789			291,260			209,584
General and administrative ⁽²⁾	22,844			15,829			30,027			15,597			52,871			31,426
Property and other taxes	16,285			14,600			14,282			13,750			30,567			28,350
Depreciation and amortization	113,946			84,790			121,117			88,488			235,063			173,278
Impairments	390			200			797			127,184			1,187			127,384
Total operating expenses	410,357			306,532			437,531			453,464			847,888			759,996
Gain (loss) on divestiture and other, net	(590		)	116			(1,061		)	170			(1,651		)	286
Operating income (loss)	318,928			224,867			310,060			114,214			628,988			339,081
Interest income – affiliates	4,225			4,225			4,225			4,225			8,450			8,450
Interest expense ⁽³⁾	(65,876		)	(38,015		)	(79,472		)	(42,245		)	(145,348		)	(80,260		)
Other income (expense), net	(35,206		)	817			(58,477		)	1,277			(93,683		)	2,094
Income (loss) before income taxes	222,071			191,894			176,336			77,471			398,407			269,365
Income tax expense (benefit)	10,092			10,884			1,278			10,304			11,370			21,188
Net income (loss)	211,979			181,010			175,058			67,167			387,037			248,177
Net income (loss) attributable to noncontrolling interests	93,319			49,483			5,464			(33,017		)	98,783			16,466
Net income (loss) attributable to Western Midstream Partners, LP	$	118,660		$	131,527		$	169,594		$	100,184		$	288,254		$	231,711
Limited partners’ interest in net income (loss):
Net income (loss) attributable to Western Midstream Partners, LP	$	118,660		$	131,527		$	169,594		$	100,184		$	288,254		$	231,711
Pre-acquisition net (income) loss allocated to Anadarko	(29,116		)	(30,522		)	(163		)	(32,604		)	(29,279		)	(63,126		)
Limited partners’ interest in net income (loss)	89,544			101,005			169,431			67,580			258,975			168,585
Net income (loss) per common unit – basic and diluted	$	0.30		$	0.46		$	0.37		$	0.31		$	0.69		$	0.77
Weighted-average common units outstanding – basic and diluted	299,556			218,933			453,000			218,934			376,702			218,934


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.

⁽²⁾

Cost of product includes product purchases from affiliates (as defined in Note 1) of ~~$56.2~~$68.2 million and ~~$34.8~~$124.4 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $38.0 million and $72.8 million for the three and six months ended June 30, 2018, respectively. Operation and maintenance includes charges from affiliates of ~~$39.1~~$32.3 million and ~~$23.0~~$71.5 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $26.8 million and $49.8 million for the three and six months ended June 30, 2018, respectively. General and administrative includes charges from affiliates of ~~$18.9~~$26.9 million and ~~$12.7~~$45.8 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $12.3 million and $25.0 million for the three and six months ended June 30, 2018, respectively. See Note 6.


⁽³⁾	Includes affiliate (as defined in Note 1) amounts of ~~$1.8~~$0.02 million and ~~$0.6~~$1.9 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $1.4 million and $2.0 million for the three and six months ended June 30, 2018, respectively. See Note 1 and Note 10.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


thousands except number of units	March 31, 2019		December 31, 2018 ⁽¹⁾		June 30, 2019		December 31, 2018 ⁽¹⁾
ASSETS
Current assets
Cash and cash equivalents	$	100,047	$	92,142	$	95,795	$	92,142
Accounts receivable, net ⁽²⁾	212,423		221,164		219,924		221,164
Other current assets ⁽³⁾	23,472		27,056		20,466		27,056
Total current assets	335,942		340,362		336,185		340,362
Note receivable – Anadarko	260,000		260,000		260,000		260,000
Property, plant and equipment
Cost	11,580,329		11,258,773		11,852,158		11,258,773
Less accumulated depreciation	2,950,330		2,848,420		3,058,512		2,848,420
Net property, plant and equipment	8,629,999		8,410,353		8,793,646		8,410,353
Goodwill	445,800		445,800		445,800		445,800
Other intangible assets	833,404		841,408		825,399		841,408
Equity investments	1,217,156		1,092,088		1,249,509		1,092,088
Other assets ⁽⁴⁾	74,694		67,194		69,992		67,194
Total assets	$	11,796,995	$	11,457,205	$	11,980,531	$	11,457,205
LIABILITIES, EQUITY AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables	$	328,867	$	443,343	$	240,568	$	443,343
Short-term debt(5)	2,000,000		28,000		8,381		28,000
Accrued ad valorem taxes	48,545		36,986		30,641		36,986
Accrued liabilities ⁽⁵⁾	141,442		129,148		219,726		129,148
Total current liabilities	2,518,854		637,477		499,316		637,477
Long-term liabilities
Long-term debt	5,208,411		4,787,381		7,489,448		4,787,381
APCWH Note Payable ⁽⁶⁾	—		427,493		—		427,493
Deferred income taxes	15,355		280,017		16,175		280,017
Asset retirement obligations	311,716		300,024		320,073		300,024
Other liabilities ⁽⁷⁾	151,118		132,130		164,309		132,130
Total long-term liabilities	5,686,600		5,927,045		7,990,005		5,927,045
Total liabilities	8,205,454		6,564,522		8,489,321		6,564,522
Equity and partners’ capital
Common units (452,990,862 and 218,937,797 units issued and outstanding at March 31, 2019, and December 31, 2018, respectively)	3,437,922		951,888
Common units (453,008,854 and 218,937,797 units issued and outstanding at June 30, 2019, and December 31, 2018, respectively)					3,338,646		951,888
Net investment by Anadarko	—		1,388,018		—		1,388,018
Total partners’ capital	3,437,922		2,339,906		3,338,646		2,339,906
Noncontrolling interests	153,619		2,552,777		152,564		2,552,777
Total equity and partners’ capital	3,591,541		4,892,683		3,491,210		4,892,683
Total liabilities, equity and partners’ capital	$	11,796,995	$	11,457,205	$	11,980,531	$	11,457,205


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	Accounts receivable, net includes amounts receivable from affiliates (as defined in Note 1) of ~~$68.5~~$96.3 million and $72.6 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽³⁾	Other current assets includes affiliate amounts of ~~$7.4~~$11.1 million and $3.7 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽⁴⁾	Other assets includes affiliate amounts of ~~$42.9~~$43.5 million and $42.2 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽⁵⁾	~~Accrued~~ As of June 30, 2019, all amounts are considered affiliate. See Note 11.


⁽⁶⁾	See Note 1 and Note 6.


⁽⁷⁾	Other liabilities includes affiliate amounts of ~~$3.5~~$75.1 million and ~~$2.2~~$47.8 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


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


⁽⁷⁾	~~Other liabilities includes affiliate amounts of $60.6 million and $47.8 million as of March 31, 2019, and December 31, 2018, respectively.~~

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

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

(UNAUDITED)


	Partners’ Capital												Partners’ Capital
thousands	Net Investment by Anadarko			Common Units			Noncontrolling Interests			Total			Net Investment by Anadarko			Common Units			Noncontrolling Interests			Total
Balance at December 31, 2018 ⁽¹⁾	$	1,388,018		$	951,888		$	2,552,777		$	4,892,683		$	1,388,018		$	951,888		$	2,552,777		$	4,892,683
Net income (loss)	29,116			89,544			93,319			211,979			29,116			89,544			93,319			211,979
Cumulative impact of the Merger transactions ⁽²⁾	—			3,169,800			(3,169,800		)	—			—			3,169,800			(3,169,800		)	—
Above-market component of swap agreements with Anadarko ⁽³⁾	—			7,407			—			7,407			—			7,407			—			7,407
WES Operating equity transactions, net ⁽⁴⁾	—			(752,796		)	752,796			—			—			(752,796		)	752,796			—
Distributions to Chipeta noncontrolling interest owner	—			—			(1,935		)	(1,935		)	—			—			(1,935		)	(1,935		)
Distributions to noncontrolling interest owners of WES Operating	—			—			(100,999		)	(100,999		)	—			—			(100,999		)	(100,999		)
Distributions to Partnership unitholders	—			(131,910		)	—			(131,910		)	—			(131,910		)	—			(131,910		)
Acquisitions from affiliates ⁽⁵⁾	(2,141,827		)	106,856			27,470			(2,007,501		)	(2,141,827		)	106,856			27,470			(2,007,501		)
Contributions of equity-based compensation from Anadarko	—			1,840			—			1,840			—			1,840			—			1,840
Net pre-acquisition contributions from (distributions to) Anadarko	451,591			—			—			451,591			451,591			—			—			451,591
Adjustments of net deferred tax liabilities	273,102			(4,375		)	—			268,727			273,102			(4,375		)	—			268,727
Other	—			(332		)	(9		)	(341		)	—			(332		)	(9		)	(341		)
Balance at March 31, 2019	$	—		$	3,437,922		$	153,619		$	3,591,541		$	—		$	3,437,922		$	153,619		$	3,591,541
Net income (loss)													163			169,431			5,464			175,058
Distributions to Chipeta noncontrolling interest owner													—			—			(1,858		)	(1,858		)
Distributions to noncontrolling interest owners of WES Operating													—			—			(5,667		)	(5,667		)
Distributions to Partnership unitholders													—			(276,324		)	—			(276,324		)
Acquisitions from affiliates ⁽⁵⁾													(5,510		)	4,493			1,017			—
Contributions of equity-based compensation from Anadarko													—			2,768			—			2,768
Net pre-acquisition contributions from (distributions to) Anadarko													5,347			—			—			5,347
Other													—			356			(11		)	345
Balance at June 30, 2019													$	—		$	3,338,646		$	152,564		$	3,491,210


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	See Note 1.


⁽³⁾	See Note 6.


⁽⁴⁾	~~The~~For the three months ended March 31, 2019, the $752.8 million decrease to partners’ capital, together with net income (loss) attributable to Western Midstream Partners, LP, totaled $(634.1) ~~million for the three months ended March 31, 2019.~~million.


⁽⁵⁾	The amounts allocated to common unitholders and noncontrolling interests represent a noncash investing activity related to the assets and liabilities assumed in the AMA acquisition.

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	Net Investment by Anadarko			Common Units			Noncontrolling Interests			Total			Net Investment by Anadarko			Common Units			Noncontrolling Interests			Total
Balance at December 31, 2017 ⁽¹⁾	$	1,050,171		$	1,061,125		$	2,883,754		$	4,995,050		$	1,050,171		$	1,061,125		$	2,883,754		$	4,995,050
Cumulative effect of accounting change	629			(14,209		)	(30,200		)	(43,780		)	629			(14,209		)	(30,200		)	(43,780		)
Net income (loss)	30,522			101,005			49,483			181,010			30,522			101,005			49,483			181,010
Above-market component of swap agreements with Anadarko ⁽²⁾	—			14,282			—			14,282			—			14,282			—			14,282
WES Operating equity transactions, net ⁽³⁾	—			(2,525		)	2,525			—			—			(2,525		)	2,525			—
Distributions to Chipeta noncontrolling interest owner	—			—			(3,353		)	(3,353		)	—			—			(3,353		)	(3,353		)
Distributions to noncontrolling interest owners of WES Operating	—			—			(94,272		)	(94,272		)	—			—			(94,272		)	(94,272		)
Distributions to Partnership unitholders	—			(120,140		)	—			(120,140		)	—			(120,140		)	—			(120,140		)
Contributions of equity-based compensation from Anadarko	—			1,470			—			1,470			—			1,470			—			1,470
Net pre-acquisition contributions from (distributions to) Anadarko	64,251			—			—			64,251			64,251			—			—			64,251
Adjustments of net deferred tax liabilities	(175		)	—			—			(175		)	(175		)	—			—			(175		)
Other	—			58			92			150			—			58			92			150
Balance at March 31, 2018 ⁽¹⁾	$	1,145,398		$	1,041,066		$	2,808,029		$	4,994,493		$	1,145,398		$	1,041,066		$	2,808,029		$	4,994,493
Cumulative effect of accounting change													—			9			21			30
Net income (loss)													32,604			67,580			(33,017		)	67,167
Above-market component of swap agreements with Anadarko ⁽²⁾													—			13,839			—			13,839
WES Operating equity transactions, net ⁽³⁾													—			(4,965		)	4,965			—
Distributions to Chipeta noncontrolling interest owner													—			—			(3,068		)	(3,068		)
Distributions to noncontrolling interest owners of WES Operating													—			—			(95,809		)	(95,809		)
Distributions to Partnership unitholders													—			(124,518		)	—			(124,518		)
Contributions of equity-based compensation from Anadarko													—			1,331			—			1,331
Net pre-acquisition contributions from (distributions to) Anadarko													93,013			—			—			93,013
Other													—			76			116			192
Balance at June 30, 2018 ⁽¹⁾													$	1,271,015		$	994,418		$	2,681,237		$	4,946,670


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	See Note 6.


⁽³⁾	~~The~~For the three months ended March 31, 2018 and June 30, 2018, the $2.5 million and $5.0 million decrease to partners’ capital, respectively, together with net income (loss) attributable to Western Midstream Partners, LP, totaled $129.0 million ~~for the three months ended March 31, 2018.~~and $95.2 million, respectively.

See accompanying Notes to Consolidated Financial Statements.

910

Table of Contents

WESTERN MIDSTREAM PARTNERS, LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)


	Three Months Ended March 31,						Six Months Ended June 30,
thousands	2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾
Cash flows from operating activities
Net income (loss)	$	211,979		$	181,010		$	387,037		$	248,177
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	113,946			84,790			235,063			173,278
Impairments	390			200			1,187			127,384
Non-cash equity-based compensation expense	2,368			1,630			5,493			3,165
Deferred income taxes	4,065			24,219			4,885			48,858
Accretion and amortization of long-term obligations, net	1,511			2,103			2,848			3,376
Equity income, net – affiliates	(57,992		)	(30,229		)	(121,590		)	(79,659		)
Distributions from equity investment earnings – affiliates	54,221			31,576			115,483			65,525
(Gain) loss on divestiture and other, net	590			(116		)	1,651			(286		)
(Gain) loss on interest-rate swaps	35,638			—			94,585			—
Lower of cost or market inventory adjustments	7			143			169			151
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	9,486			(29,632		)	2,668			(8,572		)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	(55,529		)	28,904			(81,198		)	42,040
Change in other items, net	22,393			5,553			38,250			5,889
Net cash provided by operating activities	343,073			300,151			686,531			629,326
Cash flows from investing activities
Capital expenditures	(386,144		)	(533,185		)	(704,425		)	(1,112,474		)
Acquisitions from affiliates	(2,007,501		)	—			(2,007,501		)	—
Acquisitions from third parties	(93,303		)	—			(93,303		)	(161,858		)
Investments in equity affiliates	(36,543		)	—			(77,333		)	(27,490		)
Distributions from equity investments in excess of cumulative earnings – affiliates	7,792			8,850			17,052			13,632
Proceeds from the sale of assets to third parties	(33		)	116			342			286
Net cash used in investing activities	(2,515,732		)	(524,219		)	(2,865,168		)	(1,287,904		)
Cash flows from financing activities
Borrowings, net of debt issuance costs ⁽²⁾	2,430,750			1,444,082			2,710,750			1,525,439
Repayments of debt ⁽³⁾	(467,595		)	(630,000		)	(467,595		)	(630,000		)
Increase (decrease) in outstanding checks	(5,890		)	(6,684		)	(5,662		)	(5,357		)
Registration expenses related to the issuance of Partnership common units	(855		)	—			(855		)	—
Distributions to Partnership unitholders ⁽⁴⁾	(131,910		)	(120,140		)	(408,234		)	(244,658		)
Distributions to Chipeta noncontrolling interest owner	(1,935		)	(3,353		)	(3,793		)	(6,421		)
Distributions to noncontrolling interest owners of WES Operating	(100,999		)	(94,272		)	(106,666		)	(190,081		)
Net contributions from (distributions to) Anadarko	451,591			64,251			456,938			157,264
Above-market component of swap agreements with Anadarko ⁽⁴⁾	7,407			14,282			7,407			28,121
Net cash provided by (used in) financing activities	2,180,564			668,166			2,182,290			634,307
Net increase (decrease) in cash and cash equivalents	7,905			444,098			3,653			(24,271		)
Cash and cash equivalents at beginning of period	92,142			79,588			92,142			79,588
Cash and cash equivalents at end of period	$	100,047		$	523,686		$	95,795		$	55,317
Supplemental disclosures
Interest paid, net of capitalized interest	$	76,871		$	25,949		$	137,686		$	56,784
Taxes paid (reimbursements received)	96			(87		)	96			(87		)
Accrued capital expenditures	203,509			367,095			141,094			327,777


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	For the ~~three~~six months ended ~~March 31,~~June 30, 2019 and 2018, includes $11.0 million and ~~$106.6~~$187.9 million of borrowings, respectively, under the APCWH Note Payable.


⁽³⁾	For the ~~three~~six months ended ~~March 31,~~June 30, 2019, includes a $439.6 million repayment to settle the APCWH Note Payable. See Note 6.


⁽⁴⁾	See Note 6.

See accompanying Notes to Consolidated Financial Statements.

1011

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WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except per-unit amounts	2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾
Revenues and other – affiliates
Service revenues – fee based	$	326,642		$	222,038		$	343,484		$	234,512		$	670,126		$	456,550
Service revenues – product based	1,352			631			634			538			1,986			1,169
Product sales	50,443			62,507			41,066			54,494			91,509			117,001
Total revenues and other – affiliates	378,437			285,176			385,184			289,544			763,621			574,720
Revenues and other – third parties
Service revenues – fee based	253,332			171,735			250,060			197,349			503,392			369,084
Service revenues – product based	18,027			22,792			16,041			22,124			34,068			44,916
Product sales	21,690			21,118			33,403			8,821			55,093			29,939
Other	397			233			366			240			763			473
Total revenues and other – third parties	293,446			215,878			299,870			228,534			593,316			444,412
Total revenues and other	671,883			501,054			685,054			518,078			1,356,937			1,019,132
Equity income, net – affiliates	57,992			30,229			63,598			49,430			121,590			79,659
Operating expenses
Cost of product ⁽²⁾	114,063			94,318			122,877			95,656			236,940			189,974
Operation and maintenance ⁽²⁾	142,829			96,795			148,431			112,789			291,260			209,584
General and administrative ⁽²⁾	20,560			14,997			28,101			14,901			48,661			29,898
Property and other taxes	16,285			14,600			14,282			13,750			30,567			28,350
Depreciation and amortization	113,946			84,790			121,117			88,488			235,063			173,278
Impairments	390			200			797			127,184			1,187			127,384
Total operating expenses	408,073			305,700			435,605			452,768			843,678			758,468
Gain (loss) on divestiture and other, net	(590		)	116			(1,061		)	170			(1,651		)	286
Operating income (loss)	321,212			225,699			311,986			114,910			633,198			340,609
Interest income – affiliates	4,225			4,225			4,225			4,225			8,450			8,450
Interest expense ⁽³⁾	(65,631		)	(36,952		)	(79,472		)	(41,937		)	(145,103		)	(78,889		)
Other income (expense), net	(35,264		)	782			(58,482		)	1,229			(93,746		)	2,011
Income (loss) before income taxes	224,542			193,754			178,257			78,427			402,799			272,181
Income tax expense (benefit)	10,092			10,884			1,278			10,304			11,370			21,188
Net income (loss)	214,450			182,870			176,979			68,123			391,429			250,993
Net income attributable to noncontrolling interest	1,854			2,985			1,967			2,811			3,821			5,796
Net income (loss) attributable to Western Midstream Operating, LP	$	212,596		$	179,885		$	175,012		$	65,312		$	387,608		$	245,197
Limited partners’ interest in net income (loss):
Net income (loss) attributable to Western Midstream Operating, LP	$	212,596		$	179,885		$	175,012		$	65,312		$	387,608		$	245,197
Pre-acquisition net (income) loss allocated to Anadarko	(29,116		)	(30,522		)	(163		)	(32,604		)	(29,279		)	(63,126		)
General partner interest in net (income) loss ⁽⁴⁾	—			(83,439		)	—			(84,176		)	—			(167,615		)
Common and Class C limited partners’ interest in net income (loss) ⁽⁴⁾	183,480			65,924			174,849			(51,468		)	358,329			14,456
Net income (loss) per common unit – basic and diluted ⁽⁴⁾	N/A			$	0.38		N/A			$	(0.32	)	N/A			$	0.06


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.

⁽²⁾

Cost of product includes product purchases from affiliates (as defined in Note 1) of ~~$56.2~~$68.2 million and ~~$34.8~~$124.4 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $38.0 million and $72.8 million for the three and six months ended June 30, 2018, respectively. Operation and maintenance includes charges from affiliates of ~~$39.1~~$32.3 million and ~~$23.0~~$71.5 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $26.8 million and $49.8 million for the three and six months ended June 30, 2018, respectively. General and administrative includes charges from affiliates of ~~$18.5~~$26.4 million and ~~$12.5~~$44.9 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $12.0 million and $24.5 million for the three and six months ended June 30, 2018, respectively. See Note 6.


⁽³⁾	Includes affiliate (as defined in Note 1) amounts of ~~$1.8~~$0.02 million and ~~$0.6~~$1.9 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and $1.4 million and $2.0 million for the three and six months ended June 30, 2018, respectively. See Note 1 and Note 10.


⁽⁴⁾	See Note 5 for the calculation of net income (loss) per common unit.

See accompanying Notes to Consolidated Financial Statements.

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WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)


thousands except number of units	March 31, 2019		December 31, 2018 ⁽¹⁾		June 30, 2019		December 31, 2018 ⁽¹⁾
ASSETS
Current assets
Cash and cash equivalents	$	97,728	$	90,448	$	95,342	$	90,448
Accounts receivable, net ⁽²⁾	214,148		221,373		220,352		221,373
Other current assets ⁽³⁾	23,434		26,181		19,794		26,181
Total current assets	335,310		338,002		335,488		338,002
Note receivable – Anadarko	260,000		260,000		260,000		260,000
Property, plant and equipment
Cost	11,580,329		11,258,773		11,852,158		11,258,773
Less accumulated depreciation	2,950,330		2,848,420		3,058,512		2,848,420
Net property, plant and equipment	8,629,999		8,410,353		8,793,646		8,410,353
Goodwill	445,800		445,800		445,800		445,800
Other intangible assets	833,404		841,408		825,399		841,408
Equity investments	1,217,156		1,092,088		1,249,509		1,092,088
Other assets ⁽⁴⁾	74,694		67,194		69,992		67,194
Total assets	$	11,796,363	$	11,454,845	$	11,979,834	$	11,454,845
LIABILITIES, EQUITY AND PARTNERS’ CAPITAL
Current liabilities
Accounts and imbalance payables	$	328,867	$	443,343	$	240,568	$	443,343
Short-term debt(5)	2,000,000		—		8,381		—
Accrued ad valorem taxes	48,545		36,986		30,641		36,986
Accrued liabilities ⁽⁵⁾	141,267		127,874		219,193		127,874
Total current liabilities	2,518,679		608,203		498,783		608,203
Long-term liabilities
Long-term debt	5,208,411		4,787,381		7,489,448		4,787,381
APCWH Note Payable ⁽⁶⁾	—		427,493		—		427,493
Deferred income taxes	15,355		280,017		16,175		280,017
Asset retirement obligations	311,716		300,024		320,073		300,024
Other liabilities ⁽⁷⁾	151,118		132,130		164,309		132,130
Total long-term liabilities	5,686,600		5,927,045		7,990,005		5,927,045
Total liabilities	8,205,279		6,535,248		8,488,788		6,535,248
Equity and partners’ capital
Common units (318,675,578 and 152,609,285 units issued and outstanding at March 31, 2019, and December 31, 2018, respectively)	3,533,398		2,475,540
Class C units (zero and 14,372,665 units issued and outstanding at March 31, 2019, and December 31, 2018, respectively) ⁽⁸⁾	—		791,410
General partner units (zero and 2,583,068 units issued and outstanding at March 31, 2019, and December 31, 2018, respectively) ⁽⁸⁾	—		206,862
Common units (318,675,578 and 152,609,285 units issued and outstanding at June 30, 2019, and December 31, 2018, respectively)					3,433,251		2,475,540
Class C units (zero and 14,372,665 units issued and outstanding at June 30, 2019, and December 31, 2018, respectively) ⁽⁸⁾					—		791,410
General partner units (zero and 2,583,068 units issued and outstanding at June 30, 2019, and December 31, 2018, respectively) ⁽⁸⁾					—		206,862
Net investment by Anadarko	—		1,388,018		—		1,388,018
Total partners’ capital	3,533,398		4,861,830		3,433,251		4,861,830
Noncontrolling interest	57,686		57,767		57,795		57,767
Total equity and partners’ capital	3,591,084		4,919,597		3,491,046		4,919,597
Total liabilities, equity and partners’ capital	$	11,796,363	$	11,454,845	$	11,979,834	$	11,454,845


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	Accounts receivable, net includes amounts receivable from affiliates (as defined in Note 1) of ~~$70.2~~$96.7 million and $72.8 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽³⁾	Other current assets includes affiliate amounts of ~~$7.4~~$11.1 million and $3.7 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽⁴⁾	Other assets includes affiliate amounts of ~~$42.9~~$43.5 million and $42.2 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽⁵⁾	~~Accrued~~ As of June 30, 2019, all amounts are considered affiliate. See Note 11.


⁽⁶⁾	See Note 1 and Note 6.


⁽⁷⁾	Other liabilities includes affiliate amounts of ~~$3.5~~$75.1 million and ~~$2.2~~$47.8 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.


⁽⁶⁾⁽⁸⁾	~~See~~ ~~Note 1~~ ~~and~~ ~~Note 6~~.


⁽⁷⁾	~~Other liabilities includes affiliate amounts of $60.6 million and $47.8 million as of March 31, 2019, and December 31, 2018, respectively.~~


⁽⁸⁾	Immediately prior to the closing of the Merger (as defined in Note 1), all outstanding general partner units converted into a non-economic general partner interest in WES Operating and WES Operating common units and all outstanding Class C units converted into WES Operating common units on a one-for-one basis.

See accompanying Notes to Consolidated Financial Statements.

1213

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WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED STATEMENTS OF EQUITY AND PARTNERS’ CAPITAL

(UNAUDITED)


	Partners’ Capital																		Partners’ Capital
thousands	Net Investment by Anadarko			Common Units			Class C Units			General Partner Units			Noncontrolling Interest			Total			Net Investment by Anadarko			Common Units			Class C Units			General Partner Units			Noncontrolling Interest			Total
Balance at December 31, 2018 ⁽¹⁾	$	1,388,018		$	2,475,540		$	791,410		$	206,862		$	57,767		$	4,919,597		$	1,388,018		$	2,475,540		$	791,410		$	206,862		$	57,767		$	4,919,597
Net income (loss)	29,116			170,847			10,636			1,997			1,854			214,450			29,116			170,847			10,636			1,997			1,854			214,450
Cumulative impact of the Merger transactions ⁽²⁾	—			926,236			(802,588		)	(123,648		)	—			—			—			926,236			(802,588		)	(123,648		)	—			—
Above-market component of swap agreements with Anadarko ⁽³⁾	—			7,407			—			—			—			7,407			—			7,407			—			—			—			7,407
Amortization of beneficial conversion feature of Class C units	—			(542		)	542			—			—			—			—			(542		)	542			—			—			—
Distributions to Chipeta noncontrolling interest owner	—			—			—			—			(1,935		)	(1,935		)	—			—			—			—			(1,935		)	(1,935		)
Distributions to WES Operating unitholders	—			(178,128		)	—			(85,230		)	—			(263,358		)	—			(178,128		)	—			(85,230		)	—			(263,358		)
Acquisitions from affiliates ⁽⁴⁾	(2,141,827		)	134,326			—			—			—			(2,007,501		)	(2,141,827		)	134,326			—			—			—			(2,007,501		)
Contributions of equity-based compensation from Anadarko	—			1,819			—			19			—			1,838			—			1,819			—			19			—			1,838
Net pre-acquisition contributions from (distributions to) Anadarko	451,591			—			—			—			—			451,591			451,591			—			—			—			—			451,591
Adjustments of net deferred tax liabilities	273,102			(4,375		)	—			—			—			268,727			273,102			(4,375		)	—			—			—			268,727
Other	—			268			—			—			—			268			—			268			—			—			—			268
Balance at March 31, 2019	$	—		$	3,533,398		$	—		$	—		$	57,686		$	3,591,084		$	—		$	3,533,398		$	—		$	—		$	57,686		$	3,591,084
Net income (loss)																			163			174,849			—			—			1,967			176,979
Distributions to Chipeta noncontrolling interest owner																			—			—			—			—			(1,858		)	(1,858		)
Distributions to WES Operating unitholders																			—			(283,271		)	—			—			—			(283,271		)
Acquisitions from affiliates ⁽⁴⁾																			(5,510		)	5,510			—			—			—			—
Contributions of equity-based compensation from Anadarko																			—			2,765			—			—			—			2,765
Net pre-acquisition contributions from (distributions to) Anadarko																			5,347			—			—			—			—			5,347
Balance at June 30, 2019																			$	—		$	3,433,251		$	—		$	—		$	57,795		$	3,491,046


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	See Note 1.


⁽³⁾	See Note 6.


⁽⁴⁾	The amount allocated to common unitholders represents a noncash investing activity related to the assets and liabilities assumed in the AMA acquisition.

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED STATEMENTS OF EQUITY AND PARTNERS’ CAPITAL

(UNAUDITED)


	Partners’ Capital																		Partners’ Capital
thousands	Net Investment by Anadarko			Common Units			Class C Units			General Partner Units			Noncontrolling Interest			Total			Net Investment by Anadarko			Common Units			Class C Units			General Partner Units			Noncontrolling Interest			Total
Balance at December 31, 2017 ⁽¹⁾	$	1,050,171		$	2,950,010		$	780,040		$	179,232		$	61,729		$	5,021,182		$	1,050,171		$	2,950,010		$	780,040		$	179,232		$	61,729		$	5,021,182
Cumulative effect of accounting change	629			(41,135		)	(3,536		)	(696		)	958			(43,780		)	629			(41,135		)	(3,536		)	(696		)	958			(43,780		)
Net income (loss)	30,522			59,133			6,791			83,439			2,985			182,870			30,522			59,133			6,791			83,439			2,985			182,870
Above-market component of swap agreements with Anadarko ⁽²⁾	—			14,282			—			—			—			14,282			—			14,282			—			—			—			14,282
Amortization of beneficial conversion feature of Class C units	—			(810		)	810			—			—			—			—			(810		)	810			—			—			—
Distributions to Chipeta noncontrolling interest owner	—			—			—			—			(3,353		)	(3,353		)	—			—			—			—			(3,353		)	(3,353		)
Distributions to WES Operating unitholders	—			(140,394		)	—			(76,192		)	—			(216,586		)	—			(140,394		)	—			(76,192		)	—			(216,586		)
Contributions of equity-based compensation from Anadarko	—			1,435			—			29			—			1,464			—			1,435			—			29			—			1,464
Net pre-acquisition contributions from (distributions to) Anadarko	64,251			—			—			—			—			64,251			64,251			—			—			—			—			64,251
Adjustments of net deferred tax liabilities	(175		)	—			—			—			—			(175		)	(175		)	—			—			—			—			(175		)
Other	—			91			—			—			—			91			—			91			—			—			—			91
Balance at March 31, 2018 ⁽¹⁾	$	1,145,398		$	2,842,612		$	784,105		$	185,812		$	62,319		$	5,020,246		$	1,145,398		$	2,842,612		$	784,105		$	185,812		$	62,319		$	5,020,246
Cumulative effect of accounting change																			—			27			3			—			—			30
Net income (loss)																			32,604			(47,605		)	(3,863		)	84,176			2,811			68,123
Above-market component of swap agreements with Anadarko ⁽²⁾																			—			13,839			—			—			—			13,839
Amortization of beneficial conversion feature of Class C units																			—			(812		)	812			—			—			—
Distributions to Chipeta noncontrolling interest owner																			—			—			—			—			(3,068		)	(3,068		)
Distributions to WES Operating unitholders																			—			(142,683		)	—			(78,450		)	—			(221,133		)
Contributions of equity-based compensation from Anadarko																			—			1,302			—			26			—			1,328
Net pre-acquisition contributions from (distributions to) Anadarko																			93,013			—			—			—			—			93,013
Other																			—			119			—			—			—			119
Balance at June 30, 2018 ⁽¹⁾																			$	1,271,015		$	2,666,799		$	781,057		$	191,564		$	62,062		$	4,972,497


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	See Note 6.

See accompanying Notes to Consolidated Financial Statements.

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WESTERN MIDSTREAM OPERATING, LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)


	Three Months Ended March 31,						Six Months Ended June 30,
thousands	2019			2018 ⁽¹⁾			2019			2018 ⁽¹⁾
Cash flows from operating activities
Net income (loss)	$	214,450		$	182,870		$	391,429		$	250,993
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization	113,946			84,790			235,063			173,278
Impairments	390			200			1,187			127,384
Non-cash equity-based compensation expense	2,116			1,563			4,882			3,017
Deferred income taxes	4,065			24,219			4,885			48,858
Accretion and amortization of long-term obligations, net	1,490			1,378			2,827			2,626
Equity income, net – affiliates	(57,992		)	(30,229		)	(121,590		)	(79,659		)
Distributions from equity investment earnings – affiliates	54,221			31,576			115,483			65,525
(Gain) loss on divestiture and other, net	590			(116		)	1,651			(286		)
(Gain) loss on interest-rate swaps	35,638			—			94,585			—
Lower of cost or market inventory adjustments	7			143			169			151
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	7,974			(29,633		)	2,464			(8,563		)
Increase (decrease) in accounts and imbalance payables and accrued liabilities, net	(54,430		)	28,672			(80,458		)	42,088
Change in other items, net	21,577			5,398			38,069			5,578
Net cash provided by operating activities	344,042			300,831			690,646			630,990
Cash flows from investing activities
Capital expenditures	(386,144		)	(533,185		)	(704,425		)	(1,112,474		)
Acquisitions from affiliates	(2,007,501		)	—			(2,007,501		)	—
Acquisitions from third parties	(93,303		)	—			(93,303		)	(161,858		)
Investments in equity affiliates	(36,543		)	—			(77,333		)	(27,490		)
Distributions from equity investments in excess of cumulative earnings – affiliates	7,792			8,850			17,052			13,632
Proceeds from the sale of assets to third parties	(33		)	116			342			286
Net cash used in investing activities	(2,515,732		)	(524,219		)	(2,865,168		)	(1,287,904		)
Cash flows from financing activities
Borrowings, net of debt issuance costs ⁽²⁾	2,430,750			1,444,090			2,710,750			1,525,447
Repayments of debt ⁽³⁾	(439,595		)	(630,000		)	(439,595		)	(630,000		)
Increase (decrease) in outstanding checks	(5,890		)	(6,684		)	(5,662		)	(5,357		)
Distributions to WES Operating unitholders ⁽⁴⁾	(263,358		)	(216,586		)	(546,629		)	(437,719		)
Distributions to Chipeta noncontrolling interest owner	(1,935		)	(3,353		)	(3,793		)	(6,421		)
Net contributions from (distributions to) Anadarko	451,591			64,251			456,938			157,264
Above-market component of swap agreements with Anadarko ⁽⁴⁾	7,407			14,282			7,407			28,121
Net cash provided by (used in) financing activities	2,178,970			666,000			2,179,416			631,335
Net increase (decrease) in cash and cash equivalents	7,280			442,612			4,894			(25,579		)
Cash and cash equivalents at beginning of period	90,448			78,814			90,448			78,814
Cash and cash equivalents at end of period	$	97,728		$	521,426		$	95,342		$	53,235
Supplemental disclosures
Interest paid, net of capitalized interest	$	76,637		$	25,606		$	137,452		$	56,155
Taxes paid (reimbursements received)	96			(87		)	96			(87		)
Accrued capital expenditures	203,509			367,095			141,094			327,777


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to AMA. See Note 1 and Note 3.


⁽²⁾	For the ~~three~~six months ended ~~March 31,~~June 30, 2019 and 2018, includes $11.0 million and ~~$106.6~~$187.9 million of borrowings, respectively, under the APCWH Note Payable.


⁽³⁾	For the ~~three~~six months ended ~~March 31,~~June 30, 2019, includes a $439.6 million repayment to settle the APCWH Note Payable. See Note 6.


⁽⁴⁾	See Note 6.

See accompanying Notes to Consolidated Financial Statements.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION

General. Western Midstream Partners, LP (formerly Western Gas Equity Partners, LP) is a Delaware master limited partnership formed in September 2012. Western Midstream Operating, LP (formerly Western Gas Partners, LP, and together with its subsidiaries, “WES Operating”) is a Delaware limited partnership formed by Anadarko Petroleum Corporation 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, and excludes WES Operating. The Partnership’s general partner, Western Midstream Holdings, LLC (the “general partner”), is a wholly owned subsidiary of Anadarko Petroleum Corporation. “Anadarko” refers to Anadarko Petroleum Corporation and its subsidiaries, excluding the Partnership and the general partner, and “affiliates” refers to subsidiaries of Anadarko, excluding the Partnership, but including equity interests in Fort Union Gas Gathering, LLC (“Fort Union”), White Cliffs Pipeline, LLC (“White Cliffs”), Rendezvous Gas Services, LLC (“Rendezvous”), Enterprise EF78 LLC (the “Mont Belvieu JV”), Texas Express Pipeline LLC (“TEP”), Texas Express Gathering LLC (“TEG”), Front Range Pipeline LLC (“FRP”), Whitethorn Pipeline Company LLC (“Whitethorn LLC”), Cactus II Pipeline LLC (“Cactus II”), Saddlehorn Pipeline Company, LLC (“Saddlehorn”), Panola Pipeline Company, LLC (“Panola”), Mi Vida JV LLC (“Mi Vida”), Ranch Westex JV LLC (“Ranch Westex”) and Red Bluff Express Pipeline, LLC (“Red Bluff Express”). See Note 3. The interests in TEP, TEG and FRP are referred to collectively as the “TEFR Interests.” “MGR assets” refers to the Red Desert complex and the Granger straddle plant. The “West Texas complex” refers to the Delaware Basin Midstream, LLC (“DBM”) complex and DBJV and Haley systems.

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 addition, in its capacity as a processor of natural gas, the Partnership also buys and sells natural gas, NGLs and condensate on behalf of itself and as agent for its customers under certain of its contracts. The Partnership provides these midstream services for Anadarko, as well as for third-party customers. As of ~~March 31,~~June 30, 2019, the Partnership’s assets and investments consisted of the following:



	Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems ⁽¹⁾	17	2	3	2
Treating facilities	35	3	—	3
Natural gas processing plants/trains	24	3	—	5
NGLs pipelines	2	—	—	4
Natural gas pipelines	5	—	—	1
Oil pipelines	3	1	—	3

Owned and
Operated

Operated
Interests

Non-Operated
Interests

Equity
Interests
Gathering systems ⁽¹⁾
17
2
3
2
Treating facilities 35
3
—
3
Natural gas processing plants/trains 24
3
—
5
NGLs pipelines 2
—
—
4
Natural gas pipelines 5
—
—
1
Oil pipelines 3
1
—
3


⁽¹⁾	Includes the DBM water systems.

These assets and investments are located in the Rocky Mountains (Colorado, Utah and Wyoming), North-central Pennsylvania, Texas and New Mexico. ~~Mentone Train II, a processing train and part of the West Texas complex, commenced operation at the end of the first quarter of 2019.~~

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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 (CONTINUED)

Merger transactions. On February 28, 2019, the Partnership, WES Operating, Anadarko and certain of their affiliates consummated the transactions contemplated by the Contribution Agreement and Agreement and Plan of Merger (the “Merger Agreement”), dated as of November 7, 2018, pursuant to which, among other things, Clarity Merger Sub, LLC, a wholly owned subsidiary of the Partnership, merged with and into WES Operating, with WES Operating continuing as the surviving entity and a subsidiary of the Partnership (the “Merger”). In connection with the closing of the Merger, (i) the common units of WES Operating, which previously traded under the symbol “WES,” ceased to trade on the New York Stock Exchange (“NYSE”), (ii) the common units of the Partnership, which previously traded under the symbol “WGP,” began to trade on the NYSE under the symbol “WES,” (iii) the Partnership changed its name from Western Gas Equity Partners, LP to Western Midstream Partners, LP and (iv) WES Operating changed its name from Western Gas Partners, LP to Western Midstream Operating, LP.

The Merger Agreement also provided that the Partnership, WES Operating and Anadarko cause their respective affiliates to cause the following transactions, among others, to occur immediately prior to the Merger becoming effective in the order as follows: (1) Anadarko E&P Onshore LLC and WGR Asset Holding Company LLC (“WGRAH”) (the “Contributing Parties”) contributed to WES Operating all of their interests in each of Anadarko Wattenberg Oil Complex LLC, Anadarko DJ Oil Pipeline LLC, Anadarko DJ Gas Processing LLC, Wamsutter Pipeline LLC, DBM Oil Services, LLC, Anadarko Pecos Midstream LLC, Anadarko Mi Vida LLC and APC Water Holdings 1, LLC (“APCWH”) to WGR Operating, LP, Kerr-McGee Gathering LLC and DBM (each wholly owned by WES Operating) in exchange for aggregate consideration of $1.814 billion in cash from WES Operating, minus the outstanding amount payable pursuant to an intercompany note (the “APCWH Note Payable”) assumed by WES Operating in connection with the transaction, and 45,760,201 WES Operating common units; (2) APC Midstream Holdings, LLC (“AMH”) sold to WES Operating its interests in Saddlehorn and Panola in exchange for aggregate consideration of $193.9 million in cash; (3) WES Operating contributed cash in an amount equal to the outstanding balance of the APCWH Note Payable immediately prior to the effective time of the Merger to APCWH, and APCWH paid such cash to Anadarko in satisfaction of the APCWH Note Payable; (4) the Class C units converted into WES Operating common units on a one-for-one basis; and (5) WES Operating and WES Operating GP caused the conversion of the incentive distribution rights (“IDRs”) and the 2,583,068 general partner units in WES Operating held by WES Operating GP into a non-economic general partner interest in WES Operating and 105,624,704 WES Operating common units. The 45,760,201 WES Operating common units issued to the Contributing Parties, less 6,375,284 WES Operating common units retained by WGRAH, converted into the right to receive an aggregate of 55,360,984 common units of the Partnership upon the consummation of the Merger. Each WES Operating common unit issued and outstanding immediately prior to the closing of the Merger (other than WES Operating common units owned by the Partnership and WES Operating GP, and certain common units held by subsidiaries of Anadarko) was converted into the right to receive 1.525 common units of the Partnership. See Note 10 for additional information.

~~Chevron~~Occidental merger. On ~~April 11,~~May 9, 2019, Anadarko, the indirect general partner and majority unitholder of the Partnership, which is the indirect general partner and majority unitholder of WES Operating, (i) terminated its agreement and plan of merger with Chevron Corporation and (ii) entered into the ~~Chevron~~Agreement and Plan of Merger ~~Agreement~~with Occidental Petroleum Corporation (“Occidental”) and Baseball Merger Sub 1, Inc., pursuant to which, and subject to the conditions of the agreement, all outstanding shares of Anadarko will be acquired by ~~Chevron~~Occidental in a stock and cash transaction. Occidental’s acquisition by merger of Anadarko ~~expects the acquisition to close in the second half of 2019, although it~~(“Occidental Merger”) is subject to Anadarko stockholder approval ~~regulatory approvals~~ and other customary closing conditions. Anadarko is holding a special meeting of its stockholders on August 8, 2019, for holders of record as of July 11, 2019, to vote on the proposal necessary to complete the Occidental Merger. Assuming all closing conditions are satisfied, including obtaining the requisite approval from the Anadarko stockholders, Occidental and Anadarko expect the Occidental Merger to close shortly after the special meeting of Anadarko stockholders.

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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 (CONTINUED)

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



	Percentage Interest
Equity investments ⁽¹⁾
Fort Union	14.81	%
White Cliffs	10.00	%
Rendezvous	22.00	%
Mont Belvieu JV	25.00	%
TEP	20.00	%
TEG	20.00	%
FRP	33.33	%
Whitethorn LLC	20.00	%
Cactus II	15.00	%
Saddlehorn	20.00	%
Panola	15.00	%
Mi Vida	50.00	%
Ranch Westex	50.00	%
Red Bluff Express	30.00	%
Proportionate consolidation ⁽²⁾
Marcellus Interest systems	33.75	%
Springfield system	50.10	%
Full consolidation
Chipeta ⁽³⁾	75.00	%


⁽¹⁾	Investments in non-controlled entities over which the Partnership exercises significant influence are accounted for under the equity method. “Equity investment throughput” refers to the Partnership’s share of average throughput for these investments.


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


⁽³⁾	The 25% interest in Chipeta Processing LLC (“Chipeta”) held by a third-party member is reflected within noncontrolling interests in the consolidated financial statements, in addition to the noncontrolling interests noted below.

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

Certain information and note disclosures commonly included in annual financial statements have been condensed or omitted pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). Accordingly, the accompanying consolidated financial statements and notes should be read in conjunction with the Partnership and WES Operating’s 2018 Forms 10-K, as filed with the SEC on February 20, 2019, certain sections of which were recast to reflect the results attributable to AMA (as defined in Note 3) in the Partnership and WES Operating’s Current Reports on Form 8-K, as filed with the SEC on May 17, 2019.

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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 (CONTINUED)

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 and Note 5), (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) the senior secured revolving credit facility (“WGP RCF”) until its repayment in March 2019. See Note 10.

Adjustments to previously issued financial statements. The consolidated statements of operations for the three and six months ended ~~March 31,~~June 30, 2018, include adjustments to revenue and cost of product expense of the following amounts: (i) ~~$14.3~~$24.7 million and $39.0 million, respectively, increase in Service revenues - fee based, (ii) ~~$5.3~~$7.3 million and $12.6 million, respectively, increase in Product sales and (iii) ~~$19.6~~$32.0 million and $51.6 million, respectively, increase in Cost of product. During the third quarter of 2018, management determined that under Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606) adopted on January 1, 2018, the Partnership’s marketing affiliate was acting as its agent in certain product sales transactions on behalf of the Partnership and in performing marketing services on behalf of the Partnership’s customers. The adjustments have no impact to Operating income (loss), Net income (loss), the balance sheets, cash flows or any non-GAAP metric the Partnership uses to evaluate its operations (see Key Performance Metrics under Part I, Item 2 of this Form 10-Q) and are not considered material to the results of operations for the three and six months ended ~~March 31,~~June 30, 2018.

Presentation of Partnership assets. The term “Partnership assets” includes both the assets owned and the interests accounted for under the equity method by the Partnership, through its partnership interests in WES Operating as of ~~March 31,~~June 30, 2019 (see Note 8). Because the Partnership owns the entire non-economic general partner interest in and controls WES Operating GP, and the general partner is controlled by Anadarko, each of the Partnership’s acquisitions of assets from Anadarko has been considered a transfer of net assets between entities under common control. As such, assets acquired from Anadarko were initially recorded at Anadarko’s historic carrying value, which did not correlate to the total acquisition price paid by the Partnership. Further, after an acquisition of assets from Anadarko, the Partnership is required to recast its financial statements to include the activities of such assets from the date of common control.

For those periods requiring recast, the consolidated financial statements for periods prior to the acquisition of assets from Anadarko are prepared from Anadarko’s historical cost-basis accounts and may not necessarily be indicative of the actual results of operations that would have occurred if the Partnership had owned the assets during the periods reported. Net income (loss) attributable to the assets acquired from Anadarko for periods prior to the Partnership’s acquisition of such assets is not allocated to the limited partners.

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 methods considered reasonable. 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, and certain prior-period amounts have been reclassified to conform to the current-year presentation.

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(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION (CONTINUED)

Noncontrolling interests. For periods subsequent to the consummation of the Merger, the Partnership’s noncontrolling interests in the consolidated financial statements consisted of (i) the 25% interest in Chipeta held by a third-party member and (ii) the 2.0% limited partner interest in WES Operating held by a subsidiary of Anadarko. For periods prior to the consummation of the Merger, the Partnership’s noncontrolling interests in the consolidated financial statements consisted of (i) the 25% interest in Chipeta held by a third-party member, (ii) the publicly held limited partner interests in WES Operating, (iii) the common units issued by WES Operating to subsidiaries of Anadarko as part of the consideration paid for prior acquisitions from Anadarko, and (iv) the Class C units issued by WES Operating to a subsidiary of Anadarko as part of the funding for the acquisition of DBM. For all periods presented, WES Operating’s noncontrolling interest in the consolidated financial statements consisted of the 25% interest in Chipeta held by a third-party member. See Note 5.

When WES Operating issues equity, the carrying amount of the noncontrolling interest reported by the Partnership is adjusted to reflect the noncontrolling ownership interest in WES Operating. The resulting impact of such noncontrolling interest adjustment on the Partnership’s interest in WES Operating is reflected as an adjustment to the Partnership’s partners’ capital.

Shutdown of gathering systems. In May 2018, after assessing a number of factors, with safety and protection of the environment as the primary focus, the Partnership decided to take the Kitty Draw gathering system in Wyoming (part of the Hilight system) and the Third Creek gathering system in Colorado (part of the DJ Basin complex) permanently out of service. ~~During~~Results for the ~~second quarter of~~three and six months ended June 30, 2018, reflect (i) an accrual of $10.9 million in anticipated costs associated with the shutdown of the systems, ~~was~~ recorded as a reduction in affiliate Product sales in the consolidated statements of ~~operations.~~operations and (ii) impairment expense of $127.2 million associated with reducing the net book value of the gathering systems and additional asset retirement obligation. During the first quarter of 2019, $5.5 million of the accrual related to the Kitty Draw gathering system was reversed due to producer settlements being less than initial estimates.

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.

Recently adopted accounting standards. ASU 2016-02, Leases (Topic 842) requires lessees to recognize a lease liability and a right-of-use (“ROU”) asset for all leases, including operating leases, with a term greater than 12 months on the balance sheet. This ASU modifies the definition of a lease and outlines the recognition, measurement, presentation, and disclosure of leasing arrangements by both lessees and lessors. The Partnership adopted this standard on January 1, 2019, using the modified retrospective method applied to all leases that existed on January 1, 2019, and prior-period financial statements were not adjusted. The Partnership elected not to reassess contracts that commenced prior to adoption, to continue applying its current accounting policy for existing or expired land easements and not to recognize ROU assets or lease liabilities for short-term leases.

Leases. The Partnership determines if an arrangement is a lease based on rights and obligations conveyed at inception of a contract. ~~Operating leases are included in other assets, accrued liabilities~~At the commencement date, a lease is classified as either operating or finance, and ~~other liabilities on the consolidated balance sheets.~~ ROU assets and lease liabilities are recognized ~~at the commencement date~~ based on the present value of future lease payments over the lease term. As the rate implicit in the Partnership’s leases is generally not readily determinable, the Partnership discounts lease liabilities using the Partnership’s incremental borrowing rate at the commencement date. Non-lease components associated with leases that begin in 2019 or later are accounted for as part of the lease component, and prepaid lease payments are included in ROU assets. Options to extend or terminate a lease are included in the lease term when it is reasonably certain that the Partnership will exercise that option. Leases of 12 months or less are not recognized on the consolidated balance sheets.

Lease cost is generally recognized on a straight-line basis over the lease term. For finance leases, interest expense is recognized over the lease term ~~and is generally recognized on a straight-line basis.~~using the effective interest method. Variable lease payments are recognized when the obligation for those payments is incurred.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. REVENUE FROM CONTRACTS WITH CUSTOMERS

The following table summarizes revenue from contracts with customers:


	Three Months Ended March 31,						Three Months Ended June 30,					Six Months Ended June 30,
thousands	2019			2018			2019		2018			2019			2018
Revenue from customers
Service revenues – fee based	$	579,974		$	393,773		$	593,544	$	431,861		$	1,173,518		$	825,634
Service revenues – product based	19,379			23,423			16,675		22,662			36,054			46,085
Product sales	72,800			84,868			74,469		64,687			147,269			149,555
Total revenue from customers	672,153			502,064			684,688		519,210			1,356,841			1,021,274
Revenue from other than customers
Net gains (losses) on commodity price swap agreements	(667		)	(1,243		)	—		(1,372		)	(667		)	(2,615		)
Other	397			233			366		240			763			473
Total revenues and other	$	671,883		$	501,054		$	685,054	$	518,078		$	1,356,937		$	1,019,132

Contract balances. Receivables from customers, which are included in Accounts receivable, net on the consolidated balance sheets were ~~$315.3~~$262.4 million and $214.3 million as of ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.

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



thousands
Balance at December 31, 2018	$	47,621
Amounts transferred to Accounts receivable, net that were included in the contract assets balance at the beginning of the period	(1,574		)
Additional estimated revenues recognized	9,951
Balance at June 30, 2019	$	55,998

Contract assets at June 30, 2019
Other current assets	$	12,501
Other assets	43,497
Total contract assets from contracts with customers	$	55,998

thousands
Balance at December 31, 2018 $ 47,621
Amounts transferred to Accounts receivable, net that were included in the contract assets balance at the beginning of the period (1,376 )
Additional estimated revenues recognized 3,810
Balance at March 31, 2019 $ 50,055

Contract assets at March 31, 2019
Other current assets $ 7,172
Other assets 42,883
Total contract assets from contracts with customers $ 50,055

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. REVENUE FROM CONTRACTS WITH CUSTOMERS (CONTINUED)

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



thousands
Balance at December 31, 2018	$	145,624
Cash received or receivable, excluding revenues recognized during the period	28,588
Revenues recognized that were included in the contract liability balance at the beginning of the period	(10,183		)
Balance at June 30, 2019	$	164,029

Contract liabilities at June 30, 2019
Accrued liabilities	$	6,620
Other liabilities	157,409
Total contract liabilities from contracts with customers	$	164,029

thousands
Balance at December 31, 2018 $ 145,624
Cash received or receivable, excluding revenues recognized during the period 15,213
Revenues recognized that were included in the contract liability balance at the beginning of the period (9,279 )
Balance at March 31, 2019 $ 151,558

Contract liabilities at March 31, 2019
Accrued liabilities $ 6,364
Other liabilities 145,194
Total contract liabilities from contracts with customers $ 151,558

Transaction price allocated to remaining performance obligations. Revenues expected to be recognized from certain performance obligations that are unsatisfied (or partially unsatisfied) as of ~~March 31,~~June 30, 2019, are reflected in the following table. The Partnership applies the optional exemptions in 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
Remainder of 2019	$	380,239
2020	873,259
2021	912,081
2022	962,556
2023	918,095
Thereafter	4,340,666
Total	$	8,386,896

thousands
Remainder of 2019 $ 532,477
2020 862,428
2021 911,450
2022 976,136
2023 932,921
Thereafter 4,500,175
Total $ 8,715,587

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3. ACQUISITIONS AND DIVESTITURES

AMA acquisition. In February 2019, WES Operating acquired the following assets from Anadarko (see Note 1), which are collectively referred to as the Anadarko Midstream Assets (“AMA”):


•	Wattenberg processing plant. The Wattenberg processing plant consists of a cryogenic train (with capacity of 190 million cubic feet per day (“MMcf/d”)) and a refrigeration train (with capacity of 100 MMcf/d) located in Adams County, Colorado, now part of the DJ Basin complex.


•	Wamsutter pipeline. The Wamsutter pipeline is a crude oil gathering pipeline located in Sweetwater County, Wyoming and delivers crude oil into Andeavor’s Wamsutter Pipeline System.

•

DJ Basin oil system. The DJ Basin oil system consists of (i) a crude oil gathering system, (ii) a centralized oil stabilization facility (“COSF”) and (iii) a 12-mile crude oil pipeline, located in Weld County, Colorado. The COSF consists of Trains I through VI with total capacity of 155 thousand barrels per day (“MBbls/d”) and two storage tanks with total capacity of 500,000 barrels. Train VI commenced operation in 2018. The pipeline connects the COSF to Tampa Rail.

•

DBM oil system. The DBM oil system consists of (i) a crude oil gathering system, (ii) three central production facilities (“CPFs”), which include ten processing trains with total capacity of 75 MBbls/d, (iii) three storage tanks with total capacity of 30,000 barrels, (iv) a 14-mile crude oil pipeline, and (v) two regional oil treating facilities (“ROTFs”), which include four trains with total capacity of 120 MBbls/d, located in Reeves and Loving Counties, Texas. The ROTFs commenced operation in 2018. The pipeline transports crude oil from the DBM oil system and one third-party CPF into Plains All American Pipeline.


•	APC water systems. The APC water systems consist of five produced-water disposal systems with total capacity of 565 MBbls/d, located in Reeves, Loving, Winkler and Ward Counties, Texas, which are now part of the DBM water systems. One produced-water disposal system commenced operation in 2017 and the others commenced operation in 2018.


•	A 20% interest in Saddlehorn. Saddlehorn owns (i) a crude oil and condensate pipeline (excluding pipeline capacity leased by Saddlehorn) that originates in Laramie County, Wyoming and terminates in Cushing, Oklahoma, and (ii) four storage tanks with total capacity of 300,000 barrels. The Saddlehorn interest is accounted for under the equity method and the pipeline is operated by a third party.


•	A 15% interest in Panola. Panola owns a 248-mile NGLs pipeline that originates in Panola County, Texas and terminates in Mont Belvieu, Texas. The Panola interest is accounted for under the equity method and the pipeline is operated by a third party.


•	A 50% interest in Mi Vida. Mi Vida owns a cryogenic gas processing plant (with capacity of 200 MMcf/d) located in Ward County, Texas. The interest in Mi Vida is accounted for under the equity method and the processing plant is operated by a third party.


•	A 50% interest in Ranch Westex. Ranch Westex owns a processing plant consisting of a cryogenic train (with capacity of 100 MMcf/d) and a refrigeration train (with capacity of 25 MMcf/d), located in Ward County, Texas. The interest in Ranch Westex is accounted for under the equity method and the processing plant is operated by a third party.

~~Wattenberg processing plant.~~ The Wattenberg processing plant consists of a cryogenic train (with capacity of 190 million cubic feet per day (“MMcf/d”)) and a refrigeration train (with capacity of 100 MMcf/d) located in Adams County, Colorado, now part of the DJ Basin complex.

~~Wamsutter pipeline.~~ ~~The Wamsutter pipeline is a crude oil gathering pipeline located in Sweetwater County, Wyoming and delivers crude oil into Andeavor’s Wamsutter Pipeline System.~~

~~DJ Basin oil system.~~ The DJ Basin oil system consists of (i) a crude oil gathering system, (ii) a centralized oil stabilization facility (“COSF”) and (iii) a 12-mile crude oil pipeline, located in Weld County, Colorado. The COSF consists of Trains I through VI with total capacity of 155 thousand barrels per day (“MBbls/d”) and two storage tanks with total capacity of 500,000 barrels. Train VI commenced operation in 2018. The pipeline connects the COSF to Tampa Rail.

~~DBM oil system.~~ The DBM oil system consists of (i) a crude oil gathering system, (ii) three central production facilities (“CPFs”), which include ten processing trains with total capacity of 71 MBbls/d, (iii) three storage tanks with total capacity of 30,000 barrels, (iv) a 14-mile crude oil pipeline, and (v) two regional oil treating facilities (“ROTFs”), which include four trains with total capacity of 120 MBbls/d, located in Reeves and Loving Counties, Texas. The ROTFs commenced operation in 2018. The pipeline transports crude oil from the DBM oil system and one third-party CPF into Plains All American Pipeline.

~~APC water systems.~~ The APC water systems consist of five produced-water disposal systems with total capacity of 565 MBbls/d, located in Reeves, Loving, Winkler and Ward Counties, Texas, which are now part of the DBM water systems. One produced-water disposal system commenced operation in 2017 and the others commenced operation in 2018.

~~A 20% interest in Saddlehorn.~~ Saddlehorn owns (i) a crude oil and condensate pipeline (excluding pipeline capacity leased by Saddlehorn) that originates in Laramie County, Wyoming and terminates in Cushing, Oklahoma, and (ii) four storage tanks with total capacity of 300,000 barrels. The Saddlehorn interest is accounted for under the equity method and the pipeline is operated by a third party.

~~A 15% interest in Panola.~~ Panola owns a 248-mile NGLs pipeline that originates in Panola County, Texas and terminates in Mont Belvieu, Texas. The Panola interest is accounted for under the equity method and the pipeline is operated by a third party.

~~A 50% interest in Mi Vida.~~ Mi Vida owns a cryogenic gas processing plant (with capacity of 200 MMcf/d) located in Ward County, Texas. The interest in Mi Vida is accounted for under the equity method and the processing plant is operated by a third party.

~~A 50% interest in Ranch Westex.~~ Ranch Westex owns a processing plant consisting of a cryogenic train (with capacity of 100 MMcf/d) and a refrigeration train (with capacity of 25 MMcf/d), located in Ward County, Texas. The interest in Ranch Westex is accounted for under the equity method and the processing plant is operated by a third party.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

3. ACQUISITIONS AND DIVESTITURES (CONTINUED)

Because the acquisition of AMA was a transfer of net assets between entities under common control, the Partnership and WES Operating’s historical financial statements previously filed with the SEC have been recast in this Form 10-Q to include the results attributable to AMA as if it was owned for all periods presented. The consolidated financial statements for periods prior to the acquisition of AMA have been prepared from Anadarko’s historical cost-basis accounts and may not necessarily be indicative of the actual results of operations that would have occurred if AMA had been owned during the periods reported.

The following tables present the impact of AMA on Revenues and other, Equity income, net – affiliates and Net income (loss) as presented in the Partnership and WES Operating’s historical consolidated statements of operations:


	Three Months Ended March 31, 2018									Three Months Ended June 30, 2018
thousands	Partnership Historical ⁽¹⁾		AMA		Eliminations			Combined		Partnership Historical ⁽¹⁾		AMA		Eliminations			Combined
Revenues and other	$	456,802	$	51,664	$	(7,412	)	$	501,054	$	467,919	$	58,686	$	(8,527	)	$	518,078
Equity income, net – affiliates	20,424		9,805		—			30,229		39,218		10,212		—			49,430
Net income (loss)	150,488		30,522		—			181,010		34,563		32,604		—			67,167


	Three Months Ended March 31, 2018									Six Months Ended June 30, 2018
thousands	WES Operating Historical ⁽¹⁾		AMA		Eliminations			Combined		Partnership Historical ⁽¹⁾		AMA		Eliminations			Combined
Revenues and other	$	456,802	$	51,664	$	(7,412	)	$	501,054	$	924,721	$	110,350	$	(15,939	)	$	1,019,132
Equity income, net – affiliates	20,424		9,805		—			30,229		59,642		20,017		—			79,659
Net income (loss)	152,348		30,522		—			182,870		185,051		63,126		—			248,177



	Three Months Ended June 30, 2018
thousands	WES Operating Historical ⁽¹⁾		AMA		Eliminations			Combined
Revenues and other	$	467,919	$	58,686	$	(8,527	)	$	518,078
Equity income, net – affiliates	39,218		10,212		—			49,430
Net income (loss)	35,519		32,604		—			68,123



	Six Months Ended June 30, 2018
thousands	WES Operating Historical ⁽¹⁾		AMA		Eliminations			Combined
Revenues and other	$	924,721	$	110,350	$	(15,939	)	$	1,019,132
Equity income, net – affiliates	59,642		20,017		—			79,659
Net income (loss)	187,867		63,126		—			250,993


⁽¹⁾	See Adjustments to previously issued financial statements within Note 1.

Red Bluff Express acquisition. In January 2019, the Partnership acquired a 30% interest in Red Bluff Express, which owns a natural gas pipeline operated by a third party connecting processing plants in Reeves and Loving Counties, Texas to the WAHA hub in Pecos County, Texas. The Partnership acquired its 30% interest from a third party via an initial net investment of $92.5 million, which represented its share of costs incurred up to the date of acquisition. The initial investment was funded with cash on hand and the interest in Red Bluff Express is accounted for under the equity method. See Note 8.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

3. ACQUISITIONS AND DIVESTITURES (CONTINUED)

Whitethorn LLC acquisition. In June 2018, the Partnership acquired a 20% interest in Whitethorn LLC, which owns a crude oil and condensate pipeline that originates in Midland, Texas and terminates in Sealy, Texas (the “Midland-to-Sealy pipeline”) and related storage facilities (collectively referred to as “Whitethorn”). A third party operates Whitethorn and oversees the related commercial activities. In connection with its investment in Whitethorn LLC, the Partnership shares proportionally in the commercial activities. The Partnership acquired its 20% interest via a $150.6 million net investment, which was funded with cash on hand and is accounted for under the equity method. See Note 8.

Cactus II acquisition. In June 2018, the Partnership acquired a 15% interest in Cactus II, which will own a crude oil pipeline operated by a third party (the “Cactus II pipeline”) connecting West Texas to the Corpus Christi area. The Cactus II pipeline is under construction and is expected to become operational in late 2019. The Partnership acquired its 15% interest from a third party via an initial net investment of $12.1 million, which represented its share of costs incurred up to the date of acquisition. The initial investment was funded with cash on hand and the interest in Cactus II is accounted for under the equity method. See Note 8.

4. PARTNERSHIP DISTRIBUTIONS

The partnership agreement requires the Partnership to distribute all of its available cash (as defined in its partnership agreement) to unitholders of record on the applicable record date within 55 days of the end of each quarter. The Board of Directors of the general partner (the “Board of Directors”) 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 Distribution per Unit		Total Quarterly Cash Distribution		Date of Distribution	thousands except per-unit amounts Quarters Ended	Total Quarterly Distribution per Unit		Total Quarterly Cash Distribution		Date of Distribution
2018⁽¹⁾	2018⁽¹⁾						2018⁽¹⁾
March 31	March 31	$	0.56875	$	124,518	May 2018	March 31	$	0.56875	$	124,518	May 2018
June 30	June 30	0.58250		127,531		August 2018	June 30	0.58250		127,531		August 2018
September 30	September 30	0.59500		130,268		November 2018	September 30	0.59500		130,268		November 2018
December 31	December 31	0.60250		131,910		February 2019	December 31	0.60250		131,910		February 2019
2019	2019						2019
March 31 ⁽²⁾	March 31 ⁽²⁾	$	0.61000	$	276,324	May 2019	March 31 ⁽²⁾	$	0.61000	$	276,324	May 2019
June 30 ⁽²⁾							June 30 ⁽²⁾	0.61800		279,959		August 2019


⁽¹⁾	The 2018 distributions were declared and paid prior to the closing of the Merger.


⁽²⁾	The Board of Directors declared a cash distribution to the Partnership’s unitholders for the ~~first~~second quarter of 2019 of ~~$0.61000~~$0.61800 per unit, or ~~$276.3~~$280.0 million in aggregate. The cash distribution is payable on ~~May 14,~~August 13, 2019, to unitholders of record at the close of business on ~~May 1,~~July 31, 2019.

Available cash. The amount of available cash (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 reserves to fund future capital expenditures; to comply with applicable laws, debt instruments or other agreements; or to provide funds for distributions to its unitholders 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. Working capital borrowings may only be those that, at the time of such borrowings, were intended to be repaid within 12 months. In all cases, working capital borrowings are used solely for working capital purposes or to fund distributions to partners.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

4. PARTNERSHIP DISTRIBUTIONS (CONTINUED)

WES Operating partnership distributions. For the 2018 periods noted below, WES Operating paid the following cash distributions to WES Operating’s common and general partner unitholders:



thousands except per-unit amounts Quarters Ended	Total Quarterly Distribution per Unit		Total Quarterly Cash Distribution		Date of Distribution
2018
March 31	$	0.935	$	221,133	May 2018
June 30	0.950		225,691		August 2018
September 30	0.965		230,239		November 2018
December 31	0.980		234,787		February 2019

thousands except per-unit amounts
Quarters Ended
Total Quarterly
Distribution
per Unit Total Quarterly
Cash Distribution Date of
Distribution
2018
March 31 $ 0.935
$ 221,133
May 2018
June 30 0.950
225,691
August 2018
September 30 0.965
230,239
November 2018
December 31 0.980
234,787
February 2019

Immediately prior to the closing of the Merger, the IDRs and the general partner units were converted into a non-economic general partner interest in WES Operating and WES Operating common units, and upon consummation of the Merger, all WES Operating common units held by the public and subsidiaries of Anadarko (other than common units held by the Partnership, WES Operating GP and 6.4 million common units held by a subsidiary of Anadarko) were converted into common units of the Partnership. Beginning in the first quarter of 2019, WES Operating ~~will make~~makes distributions to the Partnership and a subsidiary of Anadarko in respect of their proportionate share of limited partner interests in WES Operating. For the ~~three months~~quarter ended March 31, 2019, WES Operating ~~will distribute~~distributed $283.3 million to its limited partners. For the quarter ended June 30, 2019, WES Operating will distribute $288.1 million to its limited partners. See Note 5.

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~4. PARTNERSHIP DISTRIBUTIONS (CONTINUED)~~

WES Operating Class C unit distributions. Prior to the closing of the Merger, WES Operating’s Class C units received quarterly distributions at a rate equivalent to WES Operating’s publicly-traded common units. The distributions were paid in the form of additional Class C Units (“PIK Class C units”) and were disregarded with respect to WES Operating’s distributions of WES Operating’s available cash. The number of PIK Class C units issued in connection with a distribution payable on the Class C units was determined by dividing the corresponding distribution attributable to the Class C units by the volume-weighted-average price of WES Operating’s common units for the ten days immediately preceding the payment date for the common unit distribution, less a 6% discount. WES Operating recorded the PIK Class C unit distributions at fair value at the time of issuance. This Level 2 fair value measurement used WES Operating’s unit price as a significant input in the determination of the fair value. See Note 5 for further discussion of the Class C units.

In February 2019, immediately prior to the closing of the Merger, all outstanding Class C units converted into WES Operating common units on a one-for-one basis (see Note 1).

WES Operating’s general partner interest and incentive distribution rights. Prior to the closing of the Merger, WES Operating GP was entitled to 1.5% of all quarterly distributions that WES Operating made prior to its liquidation and, as the former holder of the IDRs, was entitled to incentive distributions at the maximum distribution sharing percentage of 48.0% for all prior periods presented. Immediately prior to the closing of the Merger, the IDRs and the general partner units converted into a non-economic general partner interest in WES Operating and WES Operating common units (see Note 1).

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. EQUITY AND PARTNERS’ CAPITAL

Holdings of Partnership equity. The Partnership’s common units are listed on the NYSE under the symbol “WES.” As of ~~March 31,~~June 30, 2019, Anadarko held 251,197,617 common units, representing a 55.5% limited partner interest in the Partnership, and, through its ownership of the general partner, Anadarko indirectly held the entire non-economic general partner interest in the Partnership. The public held ~~201,793,245~~201,811,237 common units, representing a 44.5% limited partner interest in the Partnership.

In February 2019, the Partnership issued common units in connection with the closing of the Merger (see Note 1) as follows:



Partnership common units outstanding prior to the Merger			218,937,797
WES Operating common units outstanding prior to the Merger	152,609,285
WES Operating Class C units outstanding prior to the Merger	14,681,388
Less: WES Operating common units owned by the Partnership	(50,132,046	)
WES Operating common units subject to conversion into Partnership common units	117,158,627
Exchange ratio per unit	1.525
Partnership common units issued for WES Operating common units⁽¹⁾			178,692,081
WES Operating common units issued as part of the AMA acquisition	45,760,201
Less: WES Operating common units retained by a subsidiary of Anadarko	(6,375,284	)
WES Operating acquisition common units subject to conversion into Partnership common units	39,384,917
Conversion ratio per unit	1.4056
Partnership common units issued for WES Operating acquisition common units			55,360,984
Partnership common units outstanding at ~~March 31,~~February 28, 2019			452,990,862

��


⁽¹⁾	Total Partnership units issued upon consummation of the Merger exceeds the calculation of such units using the exchange ratio due to the rounding convention reflected in the Merger Agreement.

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~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~5. EQUITY AND PARTNERS’ CAPITAL (CONTINUED)~~

Holdings of WES Operating equity. As of ~~March 31,~~June 30, 2019, (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) Anadarko, 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).

WES Operating interests. The following table summarizes WES Operating’s units issued during the ~~three~~six months ended ~~March 31,~~June 30, 2019:


	Common Units	Class C Units		General Partner Units		Total	Common Units	Class C Units		General Partner Units		Total
Balance at December 31, 2018	152,609,285	14,372,665		2,583,068		169,565,018	152,609,285	14,372,665		2,583,068		169,565,018
PIK Class C units	—	308,723		—		308,723	—	308,723		—		308,723
Conversion of Class C units⁽¹⁾	14,681,388	(14,681,388	)	—		—	14,681,388	(14,681,388	)	—		—
IDR and General partner unit conversion ⁽¹⁾	105,624,704	—		(2,583,068	)	103,041,636	105,624,704	—		(2,583,068	)	103,041,636
Units issued as part of the AMA acquisition ⁽¹⁾	45,760,201	—		—		45,760,201	45,760,201	—		—		45,760,201
Balance at March 31, 2019	318,675,578	—		—		318,675,578
Balance at June 30, 2019 ⁽¹⁾							318,675,578	—		—		318,675,578


⁽¹⁾	All WES Operating common units that converted into WES common units upon closing of the Merger were canceled and an equivalent amount of the canceled WES Operating common units were issued to WES. See Note 1 for further details on the units issued and converted in connection with the closing of the Merger.

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. EQUITY AND PARTNERS’ CAPITAL (CONTINUED)

WES Operating Class C units. In November 2014, WES Operating issued 10,913,853 Class C units to AMH, pursuant to a Unit Purchase Agreement with Anadarko and AMH. The Class C units were issued to partially fund the acquisition of DBM.

The Class C units were issued at a discount to the then-current market price of the common units into which they were convertible. This discount, totaling $34.8 million, represented a beneficial conversion feature, and at issuance, was reflected as an increase in WES Operating common unitholders’ capital and a decrease in Class C unitholder capital to reflect the fair value of the Class C units at issuance. The beneficial conversion feature was considered a non-cash distribution that was recognized from the date of issuance through the date of conversion, resulting in an increase in Class C unitholder capital and a decrease in common unitholders’ capital as amortized. The beneficial conversion feature was amortized assuming the extended conversion date of March 1, 2020, using the effective yield method. The impact of the beneficial conversion feature amortization was included in the calculation of earnings per unit (see WES Operating’s net income (loss) per common unit below).

All outstanding Class C units converted into WES Operating common units on a one-for-one basis immediately prior to the closing of the Merger (see Note 1).

Partnership’s net income (loss) per common unit. The Partnership’s 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. Net income (loss) per common unit is calculated assuming that cash distributions are equal to the net income attributable to the Partnership. Net income (loss) attributable to the Partnership assets (as defined in Note 1) acquired from Anadarko for periods prior to the acquisition of the assets is not allocated to the limited partners when calculating net income (loss) per common unit. Net income equal to the amount of available cash (as defined by the partnership agreement) is allocated to the Partnership’s common unitholders consistent with actual cash distributions.

WES Operating’s net income (loss) per common unit. For periods subsequent to the closing of the Merger, net income (loss) per common unit for WES Operating is not calculated as it no longer has publicly traded units. For periods prior to the closing of the Merger, Net income (loss) attributable to Western Midstream Operating, LP earned on and subsequent to the date of acquisition of the Partnership assets was allocated as discussed below. Net income (loss) attributable to the Partnership assets acquired from Anadarko for periods prior to the acquisition of the assets was not allocated to the unitholders for purposes of calculating net income (loss) per common unit.

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~5. EQUITY AND PARTNERS’ CAPITAL (CONTINUED)~~

General partner. The general partner’s allocation was equal to cash distributions plus its portion of undistributed earnings or losses. Specifically, net income equal to the amount of available cash (as defined by WES Operating’s partnership agreement) was allocated to the general partner consistent with actual cash distributions and capital account allocations, including incentive distributions. Undistributed earnings (net income in excess of distributions) or undistributed losses (available cash in excess of net income) was then allocated to the general partner in accordance with its weighted-average ownership percentage during each period.

Common and Class C unitholders. The Class C units were considered a participating security because they participated in distributions with common units according to a predetermined formula (see Note 4). The common and Class C unitholders’ allocation was equal to their cash distributions plus their respective allocations of undistributed earnings or losses. Specifically, net income equal to the amount of available cash (as defined by the WES Operating partnership agreement) was allocated to the common and Class C unitholders consistent with actual cash distributions and capital account allocations. Undistributed earnings or undistributed losses were then allocated to the common and Class C unitholders in accordance with their respective weighted-average ownership percentages during each period. The common unitholder allocation also included the impact of the amortization of the Class C units beneficial conversion feature. The Class C unitholder allocation was similarly impacted by the amortization of the Class C units beneficial conversion feature (see WES Operating Class C units above).

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WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. EQUITY AND PARTNERS’ CAPITAL (CONTINUED)

Calculation of net income (loss) per unit. Basic net income (loss) per common unit was calculated by dividing the net income (loss) attributable to common unitholders by the weighted-average number of common units outstanding during the period. The common units issued in connection with acquisitions and equity offerings were included on a weighted-average basis for periods they were outstanding. Diluted net income (loss) per common unit was calculated by dividing the sum of (i) the net income (loss) attributable to common units and (ii) the net income (loss) attributable to the Class C units as a participating security, by the sum of the weighted-average number of common units outstanding plus the dilutive effect of the weighted-average number of outstanding Class C units.

The following table illustrates the calculation of WES Operating’s net income (loss) per common unit:


	Three Months Ended March 31,			Three Months Ended June 30,			Six Months Ended June 30,
thousands except per-unit amounts	2018			2018			2018
Net income (loss) attributable to Western Midstream Operating, LP	$	179,885		$	65,312		$	245,197
Pre-acquisition net (income) loss allocated to Anadarko	(30,522		)	(32,604		)	(63,126		)
General partner interest in net (income) loss	(83,439		)	(84,176		)	(167,615		)
Common and Class C limited partners’ interest in net income (loss)	$	65,924		$	(51,468	)	$	14,456
Net income (loss) allocable to common units ⁽¹⁾	$	58,323		$	(48,417	)	$	9,906
Net income (loss) allocable to Class C units ⁽¹⁾	7,601			(3,051		)	4,550
Common and Class C limited partners’ interest in net income (loss)	$	65,924		$	(51,468	)	$	14,456
Net income (loss) per unit
Common units – basic and diluted ⁽²⁾	$	0.38		$	(0.32	)	$	0.06
Weighted-average units outstanding
Common units – basic and diluted	152,602			152,604			152,603
Excluded due to anti-dilutive effect:
Class C units⁽²⁾	13,380			13,649			13,516


⁽¹⁾	Adjusted to reflect amortization of the beneficial conversion feature.


⁽²⁾	The impact of Class C units would be anti-dilutive for the ~~period~~periods presented.

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(UNAUDITED)

6. TRANSACTIONS WITH AFFILIATES

Affiliate transactions. Revenues from affiliates include amounts earned by the Partnership from services provided to Anadarko as well as from the sale of natural gas, condensate and NGLs to Anadarko. Anadarko sells such natural gas, condensate and NGLs as an agent on behalf of either the Partnership or the Partnership’s customers. When such sales are on the Partnership’s customers’ behalf, the Partnership recognizes associated service revenues and cost of product expense. When such sales are on the Partnership’s behalf, the Partnership recognizes product sales revenues based on the Anadarko sales price to the third party and cost of product expense associated with these sales activities.

In addition, the Partnership purchases natural gas, condensate and NGLs from an affiliate of Anadarko pursuant to gas purchase agreements. Operation and maintenance expense includes amounts accrued for or paid to affiliates for the operation of the Partnership assets, whether in providing services to affiliates or to third parties, including field labor, measurement and analysis, and other disbursements. A portion of general and administrative expenses is paid by Anadarko, which results in affiliate transactions pursuant to the reimbursement provisions of the omnibus agreements of the Partnership and WES Operating. Affiliate expenses do not bear a direct relationship to affiliate revenues, and third-party expenses do not bear a direct relationship to third-party revenues.

Merger transactions. As discussed in more detail in Note 1, on February 28, 2019, the Partnership, WES Operating, Anadarko and certain of their affiliates consummated the Merger and the other transactions contemplated in the Merger Agreement, which included the acquisition of AMA from Anadarko. See Note 3.

Cash management. Anadarko operates a cash management system whereby excess cash from most of its subsidiaries’ separate bank accounts is generally swept to centralized accounts. Prior to the acquisition of Partnership assets, third-party sales and purchases related to such assets were received or paid in cash by Anadarko within its centralized cash management system. The outstanding affiliate balances were entirely settled through an adjustment to net investment by Anadarko in connection with the acquisition of the Partnership assets. Subsequent to the acquisition of Partnership assets from Anadarko, transactions related to such assets are cash-settled directly with third parties and with Anadarko affiliates. Chipeta cash settles its transactions directly with third parties and Anadarko, as well as with the other subsidiaries of the Partnership.

Note receivable - Anadarko. In May 2008, WES Operating loaned $260.0 million to Anadarko in exchange for a 30-year note bearing interest at a fixed annual rate of 6.50%, payable quarterly. The fair value of the note receivable from Anadarko was ~~$303.9~~$325.6 million and $279.6 million at ~~March 31,~~June 30, 2019, and December 31, 2018, respectively. The fair value of the note reflects consideration of credit risk and any premium or discount for the differential between the stated interest rate and quarter-end market interest rate, based on quoted market prices of similar debt instruments. Accordingly, the fair value of the note receivable from Anadarko is measured using Level 2 inputs.

APCWH Note Payable. In June 2017, APCWH entered into an eight-year note payable agreement with Anadarko, which was repaid upon consummation of the Merger. See Note 1 and Note 10.

Commodity price swap agreements. WES Operating had commodity price swap agreements with Anadarko to mitigate exposure to the commodity price risk inherent in its percent-of-proceeds, percent-of-product and keep-whole contracts. Notional volumes for each of the commodity price swap agreements were not specifically defined. Instead, the commodity price swap agreements applied to the actual volume of natural gas, condensate and NGLs purchased and sold. The commodity price swap agreements did not satisfy the definition of a derivative financial instrument and, therefore, were not required to be measured at fair value. Net gains (losses) on commodity price swap agreements were zero and $(0.7) million (due to settlement of 2018 activity in 2019) for the three and ~~$(1.2)~~six months ended June 30, 2019, respectively, and $(1.4) million and $(2.6) million for the three and six months ended ~~March 31, 2019 and~~June 30, 2018, respectively, and are reported in the consolidated statements of operations as affiliate Product sales. These commodity price swap agreements expired without renewal on December 31, 2018.

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(UNAUDITED)

6. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Revenues or costs attributable to volumes sold and purchased during 2018 and/or settled during 2019 for the DJ Basin complex and the MGR assets are recognized in the consolidated statements of operations at the applicable market price in the tables below. A capital contribution from Anadarko is recorded in the consolidated statements of equity and partners’ capital for an amount equal to (i) the amount by which the swap price for product sales exceeds the applicable market price in the tables below, minus (ii) the amount by which the swap price for product purchases exceeds the applicable market price in the tables below. ~~For the three months ended March 31, 2019 and 2018, the capital contributions from Anadarko were $7.4 million (due to settlement of 2018 activity in 2019) and $14.3 million, respectively.~~ The tables below summarize the swap prices compared to the forward market prices:



	DJ Basin Complex
per barrel except natural gas	2018 Swap Prices		2018 Market Prices ⁽¹⁾
Ethane	$	18.41	$	5.41
Propane	47.08		28.72
Isobutane	62.09		32.92
Normal butane	54.62		32.71
Natural gasoline	72.88		48.04
Condensate	76.47		49.36
Natural gas (per MMBtu)	5.96		2.21

DJ Basin Complex
per barrel except natural gas 2018 Swap Prices
2018 Market Prices ⁽¹⁾
Ethane $ 18.41
$ 5.41
Propane 47.08
28.72
Isobutane 62.09
32.92
Normal butane 54.62
32.71
Natural gasoline 72.88
48.04
Condensate 76.47
49.36
Natural gas (per MMBtu) 5.96
2.21



	MGR Assets
per barrel except natural gas	2018 Swap Prices		2018 Market Prices ⁽¹⁾
Ethane	$	23.11	$	2.52
Propane	52.90		25.83
Isobutane	73.89		30.03
Normal butane	64.93		29.82
Natural gasoline	81.68		47.25
Condensate	81.68		56.76
Natural gas (per MMBtu)	4.87		2.21


⁽¹⁾	Represents the New York Mercantile Exchange forward strip price as of December 20, 2017, for the 2018 Market Prices, adjusted for product specification, location, basis and, in the case of NGLs, transportation and fractionation costs.

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(UNAUDITED)

6. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Gathering and processing agreements. The Partnership has significant gathering and processing arrangements with affiliates of Anadarko on a majority of its systems. Natural gas gathering, treating and transportation throughput (excluding equity investment throughput) attributable to production owned or controlled by Anadarko was 5% and 6% for the three and six months ended June 30, 2019, respectively, and 6% and 7% for the three and six months ended ~~March 31, 2019 and~~June 30, 2018, respectively. Natural gas processing throughput (excluding equity investment throughput) attributable to production owned or controlled by Anadarko was 42% and 41% for the three and six months ended June 30, 2019, respectively, and 39% and 40% for the three and six months ended ~~March 31, 2019 and~~June 30, 2018, respectively. Crude oil, NGLs and produced water gathering, treating, transportation and disposal throughput (excluding equity investment throughput) attributable to production owned or controlled by Anadarko was ~~83%~~82% and ~~79%~~83% for the three and six months ended ~~March 31,~~June 30, 2019, respectively, and 82% and 80% for the three and six months ended June 30, 2018, respectively.

Commodity purchase and sale agreements. The Partnership sells a significant amount of its natural gas, condensate and NGLs to Anadarko Energy Services Company (“AESC”), Anadarko’s marketing affiliate that acts as an agent in the sale to a third party. In addition, the Partnership purchases natural gas, condensate and NGLs from AESC pursuant to purchase agreements. The purchase and sale agreements with AESC are generally one-year contracts, subject to annual renewal.

LTIPs. The general partner awards phantom units under the Western Gas Partners, LP 2017 Long-Term Incentive Plan (assumed by the Partnership in connection with the Merger) and the Western Gas Equity Partners, LP 2012 Long-Term Incentive Plan (collectively referred to as the “LTIPs”) to its independent directors, but also from time to time to the executive officers and Anadarko employees performing services for the Partnership. The phantom units awarded to the independent directors vest one year from the grant date, while all other awards are subject to graded vesting over a three-year service period.

Anadarko Incentive Plan. General and administrative expenses included equity-based compensation expense allocated to the Partnership by Anadarko, for awards granted to the executive officers of the general partner and other employees under the Anadarko Petroleum Corporation 2012 Omnibus Incentive Compensation Plan, as amended and restated (the “Anadarko Incentive Plan”). Portions of these amounts are reflected as contributions to partners’ capital in the consolidated statements of equity and partners’ capital.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Summary of affiliate transactions. The following table summarizes material affiliate transactions included in the Partnership’s consolidated financial statements:


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
thousands	2019		2018		2019		2018		2019		2018
Revenues and other ⁽¹⁾	$	378,437	$	285,176	$	385,184	$	289,544	$	763,621	$	574,720
Equity income, net – affiliates ⁽¹⁾	57,992		30,229		63,598		49,430		121,590		79,659
Cost of product ⁽¹⁾	56,172		34,819		68,225		38,001		124,397		72,820
Operation and maintenance ⁽¹⁾	39,141		23,001		32,318		26,826		71,459		49,827
General and administrative ⁽²⁾	18,894		12,688		26,892		12,262		45,786		24,950
Operating expenses	114,207		70,508		127,435		77,089		241,642		147,597
Interest income ⁽³⁾	4,225		4,225		4,225		4,225		8,450		8,450
Interest expense ⁽⁴⁾	1,833		577		20		1,409		1,853		1,986
APCWH Note Payable borrowings ⁽⁵⁾	11,000		106,565		—		81,343		11,000		187,908
Repayment of APCWH Note Payable ⁽⁵⁾	439,595		—		—		—		439,595		—
Distributions to Partnership unitholders ⁽⁶⁾	102,654		98,000		153,231		101,571		255,885		199,571
Distributions to WES Operating unitholders ⁽⁷⁾	2,543		1,850		5,667		1,881		8,210		3,731
Above-market component of swap agreements with Anadarko	7,407		14,282		—		13,839		7,407		28,121


⁽¹⁾	Represents amounts earned or incurred on and subsequent to the date of the acquisition of Partnership assets, as well as amounts earned or incurred by Anadarko on a historical basis related to the Partnership assets prior to the acquisition of such assets.

⁽²⁾

Represents general and administrative expense incurred on and subsequent to the date of the acquisition of Partnership assets, as well as a management services fee for expenses incurred by Anadarko for periods prior to the acquisition of such assets. These amounts include equity-based compensation expense allocated to the Partnership by Anadarko (see LTIPs and Anadarko Incentive Plan within this Note 6) and amounts charged by Anadarko under the omnibus agreements of the Partnership and WES Operating.


⁽³⁾	Represents interest income recognized on the note receivable from Anadarko.


⁽⁴⁾	~~Includes amounts related to the APCWH~~ See Note ~~Payable (see~~ ~~Note 1~~ ~~and~~ ~~Note 10)~~10.


⁽⁵⁾	See Note 1.


⁽⁶⁾	Represents distributions paid to Anadarko under the partnership agreement of the Partnership (see Note 4 and Note 5).


⁽⁷⁾	Represents distributions paid to other subsidiaries of Anadarko under WES Operating’s partnership agreement (see Note 4 and Note 5).

The following table summarizes affiliate transactions for WES Operating (which are included in the Partnership’s consolidated financial statements) to the extent the amounts differ from the Partnership’s consolidated financial statements:


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
thousands	2019		2018		2019		2018		2019		2018
General and administrative ⁽¹⁾	$	18,498	$	12,479	$	26,380	$	12,044	$	44,878	$	24,523
Distributions to WES Operating unitholders ⁽²⁾	164,902		124,164		283,271		127,204		448,173		251,368

⁽¹⁾

Represents general and administrative expense incurred on and subsequent to the date of the acquisition of Partnership assets, as well as a management services fee for expenses incurred by Anadarko for periods prior to the acquisition of such assets. These amounts include equity-based compensation expense allocated to WES Operating by Anadarko (see LTIPs and Anadarko Incentive Plan within this Note 6) and amounts charged by Anadarko under the omnibus agreement of WES Operating.


⁽²⁾	Represents distributions paid to the Partnership and other subsidiaries of Anadarko under WES Operating’s partnership agreement (see Note 4 and Note 5). For the ~~three~~six months ended ~~March 31,~~June 30, 2019, includes distributions to the Partnership and a subsidiary of Anadarko related to the repayment of the WGP RCF (see Note 10).

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6. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Concentration of credit risk. Anadarko was the only customer from whom revenues exceeded 10% of consolidated revenues for all periods presented in the consolidated statements of operations.

7. PROPERTY, PLANT AND EQUIPMENT

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



thousands	Estimated Useful Life	June 30, 2019		December 31, 2018
Land	n/a	$	8,863	$	5,298
Gathering systems – pipelines	30 years	4,938,224		4,764,099
Gathering systems – compressors	15 years	1,839,353		1,712,939
Processing complexes and treating facilities	25 years	2,952,268		2,844,337
Transportation pipeline and equipment	6 to 45 years	172,807		172,558
Produced water disposal systems	20 years	697,949		629,946
Assets under construction	n/a	660,397		604,265
Other	3 to 40 years	582,297		525,331
Total property, plant and equipment		11,852,158		11,258,773
Less accumulated depreciation		3,058,512		2,848,420
Net property, plant and equipment		$	8,793,646	$	8,410,353

thousands Estimated Useful Life March 31,
2019 December 31,
2018
Land n/a $ 8,858
$ 5,298
Gathering systems – pipelines 30 years 4,828,320
4,764,099
Gathering systems – compressors 15 years 1,809,009
1,712,939
Processing complexes and treating facilities 25 years 2,944,387
2,844,337
Transportation pipeline and equipment 6 to 45 years 172,637
172,558
Produced water disposal systems 20 years 667,106
629,946
Assets under construction n/a 603,234
604,265
Other 3 to 40 years 546,778
525,331
Total property, plant and equipment 11,580,329
11,258,773
Less accumulated depreciation 2,950,330
2,848,420
Net property, plant and equipment
$ 8,629,999
$ 8,410,353

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

Impairments. During the ~~three~~six months ended ~~March 31,~~June 30, 2019, the Partnership recognized impairments of ~~$0.4~~$1.2 million.

During the year ended December 31, 2018, the Partnership recognized impairments of $230.6 million, including impairments of $125.9 million at the Third Creek gathering system and $8.1 million at the Kitty Draw gathering system. These assets were impaired to their estimated salvage values of $1.8 million and zero, respectively, using the market approach and Level 3 fair value inputs, due to the shutdown of the systems in May 2018. Also during 2018, the Partnership recognized impairments of $38.7 million and $34.6 million at the Hilight and MIGC systems, respectively. These assets were impaired to their estimated fair values of $4.9 million and $15.2 million, respectively, using the income approach and Level 3 fair value inputs, due to a reduction in estimated future cash flows. The remaining $23.3 million of impairments was primarily related to (i) a $10.9 million impairment at the GNB NGL pipeline, which was impaired to its estimated fair value of $10.0 million using the income approach and Level 3 fair value inputs, and (ii) a $5.6 million impairment related to an idle facility at the Chipeta complex, which was impaired to its estimated salvage value of $1.5 million using the market approach and Level 3 fair value inputs.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

8. EQUITY INVESTMENTS

The following table presents the equity investments activity for the ~~three~~six months ended ~~March 31,~~June 30, 2019:


thousands	Balance at December 31, 2018		Acquisitions		Equity income, net			Contributions ⁽¹⁾		Distributions			Distributions in excess of cumulative earnings ⁽²⁾			Balance at March 31, 2019		Balance at December 31, 2018		Acquisitions		Equity income, net			Contributions ⁽¹⁾		Distributions			Distributions in excess of cumulative earnings ⁽²⁾			Balance at June 30, 2019
Fort Union	$	2,259	$	—	$	(573	)	$	—	$	—		$	(237	)	$	1,449	$	2,259	$	—	$	(1,093	)	$	—	$	—		$	(389	)	$	777
White Cliffs	43,020		—		3,225			1,845		(3,079		)	(935		)	44,076		43,020		—		5,689			3,925		(5,398		)	(1,756		)	45,480
Rendezvous	37,841		—		121			—		(607		)	(671		)	36,684		37,841		—		341			—		(1,312		)	(1,614		)	35,256
Mont Belvieu JV	104,949		—		7,127			—		(4,500		)	—			107,576		104,949		—		14,404			—		(14,424		)	(1,376		)	103,553
TEG	19,358		—		830			—		(835		)	(316		)	19,037		19,358		—		1,847			—		(1,858		)	(493		)	18,854
TEP	193,198		—		8,665			6,000		(9,865		)	—			197,998		193,198		—		16,322			11,020		(16,785		)	—			203,755
FRP	176,436		—		7,125			—		(6,480		)	—			177,081		176,436		—		16,251			10,175		(15,483		)	—			187,379
Whitethorn LLC	161,858		—		21,860			3,228		(17,058		)	(5,213		)	164,675		161,858		—		44,921			8,865		(40,359		)	(6,359		)	168,926
Cactus II	106,360		—		—			17,791		—			—			124,151		106,360		—		—			34,643		—			—			141,003
Saddlehorn	108,507		—		4,830			—		(5,189		)	—			108,148		108,507		—		11,438			1,026		(8,180		)	—			112,791
Panola	22,769		—		582			—		(582		)	(228		)	22,541		22,769		—		1,075			—		(1,075		)	(553		)	22,216
Mi Vida	64,632		—		1,685			—		(2,451		)	—			63,866		64,631		—		5,840			—		(6,193		)	(2,743		)	61,535
Ranch Westex	50,901		—		2,027			—		(3,087		)	(132		)	49,709		50,902		—		3,745			—		(5,119		)	(1,465		)	48,063
Red Bluff Express	—		92,546		488			7,679		(488		)	(60		)	100,165		—		92,546		810			7,679		(810		)	(304		)	99,921
Total	$	1,092,088	$	92,546	$	57,992		$	36,543	$	(54,221	)	$	(7,792	)	$	1,217,156	$	1,092,088	$	92,546	$	121,590		$	77,333	$	(116,996	)	$	(17,052	)	$	1,249,509


⁽¹⁾	Includes capitalized interest of ~~$1.5~~$3.1 million related to the construction of the ~~pipeline owned by~~ Cactus ~~II.~~II pipeline.


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

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

9. COMPONENTS OF WORKING CAPITAL

A summary of accounts receivable, net is as follows:



	The Partnership				WES Operating
thousands	June 30, 2019		December 31, 2018		June 30, 2019		December 31, 2018
Trade receivables, net	$	219,924	$	221,119	$	220,352	$	221,328
Other receivables, net	—		45		—		45
Total accounts receivable, net	$	219,924	$	221,164	$	220,352	$	221,373

The Partnership WES Operating
thousands March 31,
2019 December 31,
2018 March 31,
2019 December 31,
2018
Trade receivables, net $ 212,342
$ 221,119
$ 214,067
$ 221,328
Other receivables, net 81
45
81
45
Total accounts receivable, net $ 212,423
$ 221,164
$ 214,148
$ 221,373

A summary of other current assets is as follows:



	The Partnership				WES Operating
thousands	June 30, 2019		December 31, 2018		June 30, 2019		December 31, 2018
NGLs inventory	$	3,589	$	6,466	$	3,589	$	6,466
Imbalance receivables	3,117		9,035		3,117		9,035
Prepaid insurance	1,259		1,972		587		1,972
Contract assets	12,501		5,399		12,501		5,399
Other	—		4,184		—		3,309
Total other current assets	$	20,466	$	27,056	$	19,794	$	26,181

The Partnership WES Operating
thousands March 31,
2019 December 31,
2018 March 31,
2019 December 31,
2018
NGLs inventory $ 6,861
$ 6,466
$ 6,861
$ 6,466
Imbalance receivables 5,800
9,035
5,800
9,035
Prepaid insurance 1,064
1,972
1,026
1,972
Contract assets 7,172
5,399
7,172
5,399
Other 2,575
4,184
2,575
3,309
Total other current assets $ 23,472
$ 27,056
$ 23,434
$ 26,181

A summary of accrued liabilities is as follows:


	The Partnership				WES Operating				The Partnership				WES Operating
thousands	March 31, 2019		December 31, 2018		March 31, 2019		December 31, 2018		June 30, 2019		December 31, 2018		June 30, 2019		December 31, 2018
Accrued interest expense	$	55,831	$	70,968	$	55,831	$	70,959	$	72,309	$	70,968	$	72,309	$	70,959
Short-term asset retirement obligations	23,033		25,938		23,033		25,938		24,564		25,938		24,564		25,938
Short-term remediation and reclamation obligations	863		863		863		863		863		863		863		863
Income taxes payable	861		384		861		384		1,319		384		1,319		384
Contract liabilities	6,364		16,235		6,364		16,235		6,620		16,235		6,620		16,235
Other ⁽¹⁾	54,490		14,760		54,315		13,495		114,051		14,760		113,518		13,495
Total accrued liabilities	$	141,442	$	129,148	$	141,267	$	127,874	$	219,726	$	129,148	$	219,193	$	127,874


⁽¹⁾	Includes amounts related to WES Operating’s interest-rate swaps as of ~~March 31,~~June 30, 2019 and December 31, 2018 (see Note 10). Includes lease liabilities related to the implementation of ASU 2016-02, Leases (Topic 842) as of ~~March 31,~~June 30, 2019 (see Note 1).

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10. DEBT AND INTEREST EXPENSE

WES Operating is the borrower for all existing debt, excluding the WGP RCF, and is expected to be the borrower for all future debt. The following table presents the outstanding debt:


	March 31, 2019						December 31, 2018						June 30, 2019						December 31, 2018
thousands	Principal		Carrying Value		Fair Value ⁽¹⁾		Principal		Carrying Value		Fair Value ⁽¹⁾		Principal		Carrying Value		Fair Value ⁽¹⁾		Principal		Carrying Value		Fair Value ⁽¹⁾
Short-term debt
WGP RCF	$	—	$	—	$	—	$	28,000	$	28,000	$	28,000	$	—	$	—	$	—	$	28,000	$	28,000	$	28,000
364-day Facility	2,000,000		2,000,000		2,000,000		—		—		—
Finance lease liabilities ⁽²⁾													8,381		8,381		8,381		—		—		—
Total short-term debt	$	2,000,000	$	2,000,000	$	2,000,000	$	28,000	$	28,000	$	28,000	$	8,381	$	8,381	$	8,381	$	28,000	$	28,000	$	28,000

Long-term debt
5.375% Senior Notes due 2021	$	500,000	$	497,257	$	518,755	$	500,000	$	496,959	$	515,990	$	500,000	$	497,556	$	520,144	$	500,000	$	496,959	$	515,990
4.000% Senior Notes due 2022	670,000		669,138		680,293		670,000		669,078		662,109		670,000		669,198		679,819		670,000		669,078		662,109
3.950% Senior Notes due 2025	500,000		493,082		493,788		500,000		492,837		466,135		500,000		493,329		496,725		500,000		492,837		466,135
4.650% Senior Notes due 2026	500,000		495,830		507,034		500,000		495,710		483,994		500,000		495,951		507,915		500,000		495,710		483,994
4.500% Senior Notes due 2028	400,000		394,749		400,050		400,000		394,631		377,475		400,000		394,869		400,317		400,000		394,631		377,475
4.750% Senior Notes due 2028	400,000		395,928		407,849		400,000		395,841		384,370		400,000		396,014		407,229		400,000		395,841		384,370
5.450% Senior Notes due 2044	600,000		593,378		573,949		600,000		593,349		522,386		600,000		593,408		565,879		600,000		593,349		522,386
5.300% Senior Notes due 2048	700,000		686,696		664,278		700,000		686,648		605,327		700,000		686,744		650,938		700,000		686,648		605,327
5.500% Senior Notes due 2048	350,000		342,353		341,536		350,000		342,328		311,536		350,000		342,379		335,567		350,000		342,328		311,536
RCF	640,000		640,000		640,000		220,000		220,000		220,000		920,000		920,000		920,000		220,000		220,000		220,000
Term loan facility													2,000,000		2,000,000		2,000,000		—		—		—
APCWH Note Payable	—		—		—		427,493		427,493		427,493		—		—		—		427,493		427,493		427,493
Total long-term debt	$	5,260,000	$	5,208,411	$	5,227,532	$	5,267,493	$	5,214,874	$	4,976,815	$	7,540,000	$	7,489,448	$	7,484,533	$	5,267,493	$	5,214,874	$	4,976,815


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


⁽²⁾	Amounts are considered affiliate. See Note 11.

Debt activity. The following table presents the debt activity for the ~~three~~six months ended ~~March 31,~~June 30, 2019:



thousands	Carrying Value
Balance at December 31, 2018	$	5,242,874
RCF borrowings	700,000
Term loan facility borrowings	2,000,000
APCWH Note Payable borrowings	11,000
Finance lease liabilities	8,381
Repayment of WGP RCF borrowings	(28,000		)
Repayment of APCWH Note Payable	(439,595		)
Other	3,169
Balance at June 30, 2019	$	7,497,829

thousands Carrying Value
Balance at December 31, 2018 $ 5,242,874
RCF borrowings 420,000
364-day Facility borrowings 2,000,000
APCWH Note Payable borrowings 11,000
Repayment of WGP RCF borrowings (28,000 )
Repayment of APCWH Note Payable (439,595 )
Other 2,132
Balance at March 31, 2019 $ 7,208,411

WES Operating Senior Notes. At ~~March 31,~~June 30, 2019, WES Operating was in compliance with all covenants under the indentures governing its outstanding notes.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

10. DEBT AND INTEREST EXPENSE (CONTINUED)

WGP RCF. In February 2018, the Partnership voluntarily reduced the aggregate commitments of the lenders under the WGP RCF to $35.0 million. The WGP RCF, which was previously available to be used to buy WES Operating common units and for general partnership purposes, matured in March 2019 and the $28.0 million of outstanding borrowings were repaid.

~~Table of Contents~~

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

~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~

~~(UNAUDITED)~~

~~10. DEBT AND INTEREST EXPENSE (CONTINUED)~~

Revolving credit facility. In December 2018, WES Operating entered into an amendment to the senior unsecured revolving credit facility (“RCF”) that (i) subject to the consummation of the Merger (see Note 1), increased the size of the RCF from $1.5 billion to $2.0 billion, while leaving the $0.5 billion accordion feature of the RCF unexercised, and (ii) effective on February 15, 2019, exercised one of the one-year extension options to extend the maturity date of the RCF from February 2023 to February 2024.

The RCF is expandable to a maximum of $2.5 billion and bears interest at the London Interbank Offered Rate (“LIBOR”), plus applicable margins ranging from 1.00% to 1.50%, or an alternate base rate equal to the greatest of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.50%, or (c) LIBOR plus 1.00%, in each case plus applicable margins currently ranging from zero to 0.50%, based upon WES Operating’s senior unsecured debt rating. A required quarterly facility fee is paid ranging from 0.125% to 0.250% of the commitment amount (whether used or unused), also based upon the senior unsecured debt rating.

As of ~~March 31,~~June 30, 2019, there was ~~$640.0~~$920.0 million in outstanding borrowings and $4.6 million in outstanding letters of credit, resulting in ~~$1.4~~$1.1 billion available borrowing capacity under the RCF. As of ~~March 31,~~June 30, 2019 and 2018, the interest rate on any outstanding RCF borrowings was ~~3.79%~~3.71% and ~~3.18%~~3.39%, respectively. The facility fee rate was 0.20% at ~~March 31,~~June 30, 2019 and 2018. At ~~March 31,~~June 30, 2019, WES Operating was in compliance with all covenants under the RCF.

~~364-day Facility.~~ Term loan facility. In December 2018, WES Operating entered into a $2.0 billion 364-day senior unsecured credit facility (the ~~“364-day Facility”~~“Term loan facility”), the proceeds of which were used to fund substantially all of the cash portion of the consideration under the Merger Agreement and the payment of related transaction costs (see Note 1). The ~~364-day Facility will mature in February 2020, and~~Term loan facility bears interest at LIBOR, plus applicable margins ranging from 1.000% to 1.625%, or an alternate base rate equal to the greatest of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.50%, or (c) LIBOR plus 1.00%, in each case as defined in the ~~364-day Facility~~Term loan facility and plus applicable margins currently ranging from zero to 0.625%, based upon WES Operating’s senior unsecured debt rating. Net cash proceeds received from future asset sales and debt or equity offerings must be used to repay amounts outstanding under the facility.

In July 2019, WES Operating entered into an amendment to the Term loan facility to (i) extend the maturity date from February 2020 to December 2020, (ii) increase the commitments available under the Term loan facility from $2.0 billion to $3.0 billion, the incremental $1.0 billion of which may be drawn by WES Operating on or before September 30, 2019, and (iii) modify the provision requiring that all debt issuance proceeds be used to repay the Term loan facility to allow for a $1.0 billion carve out of debt offering proceeds.

As of ~~March 31,~~June 30, 2019, there was $2.0 billion in outstanding borrowings under the ~~364-day Facility.~~Term loan facility. As of ~~March 31,~~June 30, 2019, the interest rate on outstanding ~~364-day Facility~~Term loan facility borrowings was ~~3.87%~~3.78% and WES Operating was in compliance with all covenants under the ~~364-day Facility. The 364-day Facility was classified as short-term debt on the consolidated balance sheets at March 31, 2019.~~Term loan facility.

All of WES Operating’s notes and obligations under the RCF and ~~364-day~~Term loan facility are recourse to WES Operating GP. WES Operating GP is indemnified by wholly owned subsidiaries of Anadarko against any claims made against WES Operating GP for WES Operating’s long-term debt and/or borrowings under the RCF and ~~364-day Facility.~~Term loan facility.

APCWH Note Payable. In June 2017, in connection with funding the construction of the APC water systems, which were acquired as part of the AMA acquisition, APCWH entered into an eight-year note payable agreement with Anadarko. This note payable had a maximum borrowing limit of $500.0 million, and accrued interest, which was payable upon maturity, at the applicable mid-term federal rate based on a quarterly compounding basis as determined by the U.S. Secretary of the Treasury. As of ~~March 31,~~June 30, 2018, the interest rate on the outstanding borrowings was ~~2.54%~~2.83%. The APCWH Note Payable was repaid upon the consummation of the Merger. See Note 1 ~~and~~ ~~Note 6~~.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

10. DEBT AND INTEREST EXPENSE (CONTINUED)

Interest-rate swaps. In December 2018 and March 2019, WES Operating entered into interest-rate swap agreements with an aggregate notional amount of $750.0 million and $375.0 million, respectively, to manage interest rate risk associated with anticipated 2019 debt issuances. Pursuant to these swap agreements, a floating interest rate indexed to the three-month LIBOR was exchanged for a fixed interest rate. Depending on market conditions, liability management actions or other factors, WES Operating may settle or amend certain or all of the currently outstanding interest-rate swaps. The following interest-rate swaps were outstanding as of ~~March 31,~~June 30, 2019:



Notional Principal Amount	Reference Period	Mandatory Termination Date	Weighted-Average Interest Rate
$375.0 million	December 2019 - 2024	December 2019	2.662%
$375.0 million	December 2019 - 2029	December 2019	2.802%
$375.0 million	December 2019 - 2049	December 2019	2.885%

The Partnership does not apply hedge accounting and, therefore, gains and losses associated with the interest-rate swaps are recognized currently in earnings. For the three and six months ended ~~March 31,~~June 30, 2019, a non-cash ~~loss~~losses of ~~$35.6~~$59.0 million ~~was~~and $94.6 million, respectively, were recognized, which isare included in Other income (expense), net in the consolidated statements of operations.

Valuation of the interest-rate swaps is based on similar transactions observable in active markets and industry standard models that primarily rely on market-observable inputs. Inputs used to estimate fair value in industry standard models are categorized as Level 2 inputs, because substantially all assumptions and inputs are observable in active markets throughout the full term of the instruments. Inputs used to estimate the fair value include market price curves, contract terms and prices, and credit risk adjustments. The fair value of the interest-rate swaps was a liability of ~~$43.6~~$102.6 million and $8.0 million at ~~March 31,~~June 30, 2019, and December 31, 2018, respectively, which is reported in Accrued liabilities on the consolidated balance sheets.

Credit risk considerations. Over-the-counter traded swaps expose the Partnership to counterparty credit risk. The Partnership monitors the creditworthiness of its counterparties, establishes credit limits according to credit policies and guidelines, and assesses the impact on the fair value of its counterparties’ creditworthiness. Under certain circumstances, the Partnership has the ability to require cash collateral or letters of credit to mitigate its credit risk exposure. The interest-rate swaps are subject to individually negotiated credit provisions that may require collateral of cash or letters of credit depending on the derivative’s portfolio valuation versus negotiated credit thresholds. These credit thresholds generally require full or partial collateralization of the Partnership’s obligations depending on certain credit risk related provisions. Specifically, collateral may be required to be posted with respect to the interest-rate swaps if WES Operating’s credit ratings decline below current levels, the liability associated with the swaps increases substantially or certain credit event of default provisions occur. For example, based on the derivative positions as of ~~March 31,~~June 30, 2019, if WES Operating’s credit ratings from both Standard and Poor’s and Moody’s Investors Service were below the investment grade thresholds of BBB- and Baa3, respectively, collateral would be required to be posted of up to approximately ~~$18.6~~$44.0 million as of ~~March 31,~~June 30, 2019. The aggregate fair value of interest-rate swaps with credit risk related contingent features for which a net liability position existed was ~~$35.1~~$82.3 million and $5.7 million at ~~March 31,~~June 30, 2019, and December 31, 2018, respectively.

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(UNAUDITED)

10. DEBT AND INTEREST EXPENSE (CONTINUED)

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



	Three Months Ended June 30,						Six Months Ended June 30,
thousands	2019			2018			2019			2018
Third parties
Long-term and short-term debt	$	(82,624	)	$	(48,671	)	$	(149,720	)	$	(90,207	)
Amortization of debt issuance costs and commitment fees	(3,170		)	(2,037		)	(6,322		)	(4,901		)
Capitalized interest	6,342			9,872			12,547			16,834
Total interest expense – third parties	(79,452		)	(40,836		)	(143,495		)	(78,274		)
Affiliates
APCWH Note Payable	—			(1,409		)	(1,833		)	(1,986		)
Finance lease liabilities	(20		)	—			(20		)	—
Total interest expense – affiliates	(20		)	(1,409		)	(1,853		)	(1,986		)
Interest expense	$	(79,472	)	$	(42,245	)	$	(145,348	)	$	(80,260	)

Three Months Ended
March 31,
thousands 2019 2018
Third parties
Long-term and short-term debt $ (67,096 ) $ (41,536 )
Amortization of debt issuance costs and commitment fees (3,152 ) (2,864 )
Capitalized interest 6,205
6,962
Total interest expense – third parties (64,043 ) (37,438 )
Affiliates
APCWH Note Payable (1,833 ) (577 )
Total interest expense – affiliates (1,833 ) (577 )
Interest expense $ (65,876 ) $ (38,015 )

11. LEASES

Anadarko, on behalf of the Partnership, has entered into operating leases that extend through 2028 for corporate offices, shared field offices, and equipment supporting the Partnership’s operations, for which Anadarko charges the Partnership rent. The Partnership has also subleased equipment from Anadarko with finance leases ~~for the corporate offices and shared field offices extend~~extending through 2028. Total lease cost, net of sublease income of $0.1 million, was $1.8 million for the three months ended March 31, 2019. Variable lease cost was immaterial for the three months ended March 31, 2019. Lease expense charged to the Partnership was $13.8 million for the three months ended March 31, 2018. Operating cash payments for amounts included in the measurement of lease liabilities was $2.0 million for the three months ended March 31, 2019.April 2020.

The following table summarizes ~~other~~ information related to ~~operating leases:~~the Partnership’s leases at June 30, 2019:


thousands except lease term and discount rate	March 31, 2019			Operating Leases			Finance Leases
Lease assets
Assets
Other assets	$	10,002		$	6,923		$	—
Lease liabilities
Net property, plant and equipment				—			8,374
Total lease assets ⁽¹⁾				$	6,923		$	8,374

Liabilities
Accrued liabilities	7,560			$	4,515		$	—
Short-term debt				—			8,381
Other liabilities	3,343			3,302			—
Total lease liabilities ⁽¹⁾				$	7,817		$	8,381

Weighted-average remaining lease term (years)	4			4			1
Weighted-average discount rate	4.1		%	4.6		%	2.9		%


⁽¹⁾	Includes additions to ROU assets and lease liabilities of $8.5 million related to finance leases for the six months ended June 30, 2019.

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11. LEASES (CONTINUED)

Lease expense charged to the Partnership was $12.9 million and $26.7 million for the three and six months ended June 30, 2018, respectively. The following table summarizes the Partnership’s lease cost for the periods presented below:



thousands	Three Months Ended June 30, 2019			Six Months Ended June 30, 2019
Operating lease cost	$	1,923		$	3,837
Variable lease cost	102			119
Sublease income	(103		)	(207		)
Finance lease cost
Amortization of ROU assets	80			80
Interest on lease liabilities	20			20
Total lease cost	$	2,022		$	3,849

The following table summarizes cash paid for amounts included in the measurement of lease liabilities for the six months ended June 30, 2019:



thousands	Operating Leases
Operating cash flows	$	3,929

The following table reconciles the undiscounted cash flows to the operating and finance lease liabilities at ~~March 31, 2019, that may be assigned or otherwise charged to the Partnership pursuant to the reimbursement provisions~~June 30, 2019:



thousands	Operating Leases		Finance Leases
Remainder of 2019	$	3,114	$	625
2020	1,969		7,934
2021	612		—
2022	618		—
2023	625		—
Thereafter	1,658		—
Total lease payments	8,596		8,559
Less portion representing imputed interest	779		178
Total lease liabilities	$	7,817	$	8,381

Table of ~~the omnibus agreement:~~Contents

WESTERN MIDSTREAM PARTNERS, LP AND WESTERN MIDSTREAM OPERATING, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

thousands
Remainder of 2019 $ 5,588
2020 2,215
2021 612
2022 618
2023 625
Thereafter 1,658
Total lease payments 11,316
Less portion representing imputed interest 413
Total lease liabilities $ 10,903

11. LEASES (CONTINUED)

The amounts in the table below represent contractual operating lease commitments at December 31, 2018, that may be assigned or otherwise charged to the Partnership pursuant to the reimbursement provisions of the omnibus agreement:



thousands
2019	$	8,711
2020	2,236
2021	460
2022	467
2023	473
Thereafter	1,547
Total lease payments	$	13,894

thousands
2019 $ 8,711
2020 2,236
2021 460
2022 467
2023 473
Thereafter 1,547
Total lease payments $ 13,894

12. COMMITMENTS AND CONTINGENCIES

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 short-term payment obligations, or commitments, related to its capital spending programs, as well as those of its unconsolidated affiliates, the majority of which is expected to be paid in the next twelve months. These commitments primarily relate to construction and expansion projects at the West Texas and DJ Basin complexes, DBM oil system and DBM water systems.

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, in which WES Operating is fully consolidated, which are included under Part I, Item 1 of this quarterly report, as well as ~~our~~the historical consolidated financial statements, and the notes thereto of WES and WES Operating, which are included under Part II, Item 8 of ~~our~~the 2018 ~~Form~~Forms 10-K as filed with the SEC on February 20, 2019, certain sections of which were recast to reflect the results attributable to AMA in WES and WES Operating’s Current Reports on Form 8-K, as filed with the SEC on May 17, 2019.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

We have made in this Form 10-Q, and may from time to time 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 such forward-looking statements are reasonable, neither we nor our general partner can give any assurance that such expectations will prove to have been correct. These forward-looking statements involve risks and uncertainties. Important factors that could cause actual results to differ materially from expectations include, but are not limited to, the following:

our ability to pay distributions to our unitholders;

our and Anadarko’s assumptions about the energy market;

future throughput (including Anadarko 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 those resources from Anadarko or through the debt or equity capital markets;

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

commodity price risks inherent in percent-of-proceeds, percent-of-product and keep-whole contracts;

weather and natural disasters;

inflation;

the availability of goods and services;

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

federal, state and local laws as well as state-approved voter ballot initiatives, including those laws or ballot initiatives that limit Anadarko’s and other producers’ hydraulic fracturing 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 Anadarko;

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

changes in Anadarko’s capital program, strategy or desired areas of focus;

our commitments to capital projects;

our ability to use the RCF;

our ability to repay debt;

conflicts of interest among us, our general partner, and affiliates, including Anadarko;

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 Anadarko or third parties, and Anadarko’s ability to generate an inventory of assets suitable for acquisition;

non-payment or non-performance of Anadarko or other significant customers, including under gathering, processing, transportation and disposal agreements and the $260.0 million note receivable from Anadarko;

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 Anadarko and we comply with any regulatory orders or other state or local changes in laws or regulations;

the completion of the proposed merger transaction between ~~Chevron~~Occidental and Anadarko; 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 ~~our~~the WES and WES Operating 2018 Forms 10-K, certain sections of which were recast to reflect the results attributable to AMA in the WES and WES Operating Current Reports on Form ~~10-K, and~~8-K, as filed with the SEC on May 17, 2019, in our quarterly reports on Form 10-Q, and in our other public filings and press releases.

The 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.

EXECUTIVE SUMMARY

We were formed by Anadarko in September 2012 and own a 98.0% limited partner interest in WES Operating, a Delaware limited partnership formed by Anadarko in 2007 to acquire, own, develop and operate midstream assets, and all of the outstanding equity interests of WES Operating GP, which holds the entire non-economic general partner interest in WES Operating. Our consolidated financial statements include the consolidated financial results of WES Operating.

We currently own or have investments in assets located in the Rocky Mountains (Colorado, Utah and Wyoming), North-central Pennsylvania, Texas and New Mexico. We are 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 addition, in our capacity as a processor of natural gas, we also buy and sell natural gas, NGLs and condensate on behalf of ourselves and as agent for our customers under certain of our contracts. We provide these midstream services for Anadarko, as well as for third-party customers. As of ~~March 31,~~June 30, 2019, our assets and investments consisted of the following:



	Owned and Operated	Operated Interests	Non-Operated Interests	Equity Interests
Gathering systems ⁽¹⁾	17	2	3	2
Treating facilities	35	3	—	3
Natural gas processing plants/trains	24	3	—	5
NGLs pipelines	2	—	—	4
Natural gas pipelines	5	—	—	1
Oil pipelines	3	1	—	3


⁽¹⁾	Includes the DBM water systems.

Merger transactions. On February 28, 2019, WES, WES Operating, Anadarko and certain of their affiliates consummated the transactions contemplated by the Contribution Agreement and Agreement and Plan of Merger (the “Merger Agreement”) dated as of November 7, 2018, pursuant to which, among other things, Clarity Merger Sub, LLC, a wholly owned subsidiary of WES, merged with and into WES Operating, with WES Operating continuing as the surviving entity and a subsidiary of WES (the “Merger”). In connection with the closing of the Merger, (i) the common units of WES Operating, which previously traded under the symbol “WES” ceased to trade on the NYSE, (ii) the common units of WES, which previously traded under the symbol “WGP,” began to trade on the NYSE under the symbol “WES,” (iii) WES changed its name from Western Gas Equity Partners, LP to Western Midstream Partners, LP and (iv) WES Operating changed its name from Western Gas Partners, LP to Western Midstream Operating, LP.

The Merger Agreement also provided that WES, WES Operating and Anadarko cause their respective affiliates to cause the following transactions, among others, to occur immediately prior to the Merger becoming effective in the order as follows: (1) Anadarko E&P Onshore LLC and WGR Asset Holding Company LLC (“WGRAH”) (the “Contributing Parties”) contributed to WES Operating all of their interests in each of Anadarko Wattenberg Oil Complex LLC, Anadarko DJ Oil Pipeline LLC, Anadarko DJ Gas Processing LLC, Wamsutter Pipeline LLC, DBM Oil Services, LLC, Anadarko Pecos Midstream LLC, Anadarko Mi Vida LLC and APC Water Holdings 1, LLC (“APCWH”) to WGR Operating, LP, Kerr-McGee Gathering LLC and DBM (each wholly owned by WES Operating) in exchange for aggregate consideration of $1.814 billion in cash from WES Operating, minus the outstanding amount payable pursuant to an intercompany note (“APCWH Note Payable”) assumed by WES Operating in connection with the transaction, and 45,760,201 WES Operating common units; (2) AMH sold to WES Operating its interests in Saddlehorn Pipeline Company, LLC and Panola Pipeline Company, LLC in exchange for aggregate consideration of $193.9 million in cash; (3) WES Operating contributed cash in an amount equal to the outstanding balance of the APCWH Note Payable immediately prior to the effective time to APCWH, and APCWH paid such cash to Anadarko in satisfaction of the APCWH Note Payable; (4) Class C units converted into WES Operating common units on a one-for-one basis; and (5) WES Operating and WES Operating GP caused the conversion of the IDRs and the 2,583,068 general partner units in WES Operating held by WES Operating GP into a non-economic general partner interest in WES Operating and 105,624,704 WES Operating common units. The 45,760,201 WES Operating common units issued to the Contributing Parties, less 6,375,284 WES Operating common units retained by WGRAH, converted into the right to receive an aggregate of 55,360,984 common units of WES upon the consummation of the Merger. Each WES Operating common unit issued and outstanding immediately prior to the closing of the Merger (other than WES Operating common units owned by the Partnership and WES Operating GP, and certain common units held by subsidiaries of Anadarko) was converted into the right to receive 1.525 common units of WES. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

Significant financial and operational events during the ~~three~~six months ended ~~March 31,~~June 30, 2019, included the following:

We raised our distribution to ~~$0.61000~~$0.61800 per unit for the ~~first~~second quarter of 2019, representing a 1% increase over the distribution for the ~~fourth~~first quarter of ~~2018~~2019 and a 7%6% increase over the distribution for the ~~first~~second quarter of 2018.


•	In March 2019, WES Operating entered into interest-rate swap agreements with an aggregate notional amount of $375.0 million. See Liquidity and Capital Resources within this Item 2 for additional information.


•	In January 2019, we acquired a 30% interest in Red Bluff Express from a third party. See Acquisitions and Divestitures within this Item 2 for additional information.

~~In March 2019, WES Operating entered into interest-rate swap agreements with an aggregate notional amount of $375.0 million. See~~ ~~Liquidity and Capital Resources~~ ~~within this Item 2 for additional information.~~

~~In January 2019, we acquired a 30% interest in Red Bluff Express from a third party. See~~ ~~Acquisitions and Divestitures~~ ~~within this Item 2 for additional information.~~

We commenced operation of Mentone Train II at the West Texas complex (with capacity of 200 MMcf/d) at the end of the first quarter of 2019.


•	In March 2019, the WGP RCF matured and the outstanding borrowings were repaid. See Liquidity and Capital Resources within this Item 2 for additional information.


•	In February 2019, WES Operating increased the size of the RCF from $1.5 billion to $2.0 billion and extended the maturity date of the RCF to February 2024. See Liquidity and Capital Resources within this Item 2 for additional information.

~~In March 2019, the WGP RCF matured and the outstanding borrowings were repaid. See~~ ~~Liquidity and Capital Resources~~ ~~within this Item 2 for additional information.~~

~~In February 2019, WES Operating increased the size of the RCF from $1.5 billion to $2.0 billion and extended the maturity date of the RCF to February 2024. See~~ ~~Liquidity and Capital Resources~~ ~~within this Item 2 for additional information.~~

Throughput attributable to Western Midstream Partners, LP for natural gas assets totaled ~~4,199~~4,276 MMcf/d and 4,238 MMcf/d for the three and six months ended ~~March 31,~~June 30, 2019, respectively, representing a ~~13%~~10% and 11% increase, respectively, compared to the ~~three months ended March 31,~~same periods in 2018.

Throughput attributable to Western Midstream Partners, LP for crude oil, NGLs and produced water assets totaled ~~1,102~~1,105 MBbls/d and 1,104 MBbls/d for the three and six months ended ~~March 31,~~June 30, 2019, respectively, representing ~~a 123%~~an 84% and 102% increase, respectively, compared to the ~~three months ended March 31,~~same periods in 2018.

Operating income (loss) was ~~$318.9~~$310.1 million and $629.0 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, representing a ~~42%~~171% and 85% increase, respectively, compared to the ~~three months ended March 31,~~same periods in 2018.


•	Adjusted gross margin for natural gas assets (as defined under the caption Key Performance Metrics within this Item 2) averaged $1.06 per Mcf and $1.08 per Mcf for the three and six months ended June 30, 2019, respectively, representing a 12% and 11% increase, respectively, compared to the same periods in 2018.


•	Adjusted gross margin for crude oil, NGLs and produced water assets (as defined under the caption Key Performance Metrics within this Item 2) averaged $1.83 per Bbl and $1.80 per Bbl for the three and six months ended June 30, 2019, respectively, representing a 6% and 1% increase, respectively, compared to the same periods in 2018.

~~Adjusted gross margin for natural gas assets (as defined under the caption~~ ~~Key Performance Metrics~~ ~~within this Item 2) averaged $1.09 per Mcf for the three months ended March 31, 2019, representing a 9% increase compared to the three months ended March 31, 2018.~~

~~Adjusted gross margin for crude oil, NGLs and produced water assets (as defined under the caption~~ ~~Key Performance Metrics~~ ~~within this Item 2) averaged $1.77 per Bbl for the three months ended March 31, 2019, representing a 5% decrease compared to the three months ended March 31, 2018.~~

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


	Three Months Ended March 31,												Three Months Ended June 30,
	2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)
	Natural gas (MMcf/d)				Crude oil & NGLs (MBbls/d)				Produced water (MBbls/d)				Natural gas (MMcf/d)				Crude oil & NGLs (MBbls/d)				Produced water (MBbls/d)
Delaware Basin	1,178	919	28	%	145	111	31	%	518	78	564	%	1,179	1,044	13	%	141	128	10	%	515	99	420	%
DJ Basin	1,258	1,107	14	%	102	102	—	%	—	—	—	%	1,266	1,119	13	%	112	108	4	%	—	—	—	%
Equity investments	377	294	28	%	304	155	96	%	—	—	—	%	402	296	36	%	310	219	42	%	—	—	—	%
Other	1,562	1,583	(1	)%	55	59	(7	)%	—	—	—	%	1,607	1,620	(1	)%	50	57	(12	)%	—	—	—	%
Total throughput	4,375	3,903	12	%	606	427	42	%	518	78	564	%	4,454	4,079	9	%	613	512	20	%	515	99	420	%

~~Chevron~~



	Six Months Ended June 30,
	2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)
	Natural gas (MMcf/d)				Crude oil & NGLs (MBbls/d)				Produced water (MBbls/d)
Delaware Basin	1,178	982	20	%	143	120	19	%	516	89	480	%
DJ Basin	1,262	1,113	13	%	107	105	2	%	—	—	—	%
Equity investments	390	295	32	%	308	187	65	%	—	—	—	%
Other	1,585	1,602	(1	)%	53	57	(7	)%	—	—	—	%
Total throughput	4,415	3,992	11	%	611	469	30	%	516	89	480	%

Occidental merger. On ~~April 11,~~May 9, 2019, Anadarko, the indirect general partner and majority unitholder of WES, which is the indirect general partner and majority unitholder of WES Operating, (i) terminated its agreement and plan of merger with Chevron Corporation and (ii) entered into the ~~Chevron~~Occidental Merger Agreement pursuant to which, and subject to the conditions of the agreement, all outstanding shares of Anadarko will be acquired by ~~Chevron~~Occidental in a stock and cash transaction. ~~Anadarko expects the acquisition to close in the second half of 2019, although it~~The Occidental Merger is subject to Anadarko stockholder approval ~~regulatory approvals~~ and other customary closing conditions. Anadarko is holding a special meeting of its stockholders on August 8, 2019, for holders of record as of July 11, 2019, to vote on the proposal necessary to complete the Occidental Merger. Assuming all closing conditions are satisfied, including obtaining the requisite approval from the Anadarko stockholders, Occidental and Anadarko expect the Occidental Merger to close shortly after the special meeting of Anadarko stockholders.

ACQUISITIONS AND DIVESTITURES

AMA acquisition. In February 2019, WES Operating acquired AMA from Anadarko. See Note 1—Description of Business and Basis of Presentation and Note 3—Acquisitions and Divestitures in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for further information.

Red Bluff Express acquisition. In January 2019, we acquired a 30% interest in Red Bluff Express, ~~Pipeline, LLC (“Red Bluff Express”),~~ which owns a natural gas pipeline operated by a third party connecting processing plants in Reeves and Loving Counties, Texas to the WAHA hub in Pecos County, Texas. We acquired our 30% interest from a third party via an initial net investment of $92.5 million, which represented our share of costs incurred up to the date of acquisition. The initial investment was funded with cash on hand and the interest in Red Bluff Express is accounted for under the equity method.

Whitethorn LLC acquisition. In June 2018, we acquired a 20% interest in Whitethorn LLC, which owns a crude oil and condensate pipeline that originates in Midland, Texas and terminates in Sealy, Texas (the “Midland-to-Sealy pipeline”) and related storage facilities (collectively referred to as “Whitethorn”). A third party operates Whitethorn and oversees the related commercial activities. In connection with our investment in Whitethorn LLC, we share proportionally in the commercial activities. We acquired our 20% interest via a $150.6 million net investment, which was funded with cash on hand and is accounted for under the equity method.

Cactus II acquisition. In June 2018, we acquired a 15% interest in Cactus II, which will own a crude oil pipeline operated by a third party (the “Cactus II pipeline”) connecting West Texas to the Corpus Christi area. The Cactus II pipeline is under construction and is expected to become operational in late 2019. We acquired our 15% interest from a third party via an initial net investment of $12.1 million, which represented our share of costs incurred up to the date of acquisition. The initial investment was funded with cash on hand and the interest in Cactus II is accounted for under the equity method.

Newcastle system divestiture. In December 2018, the Newcastle system, located in Northeast Wyoming, was sold to a third party for $3.2 million, resulting in a net gain on sale of $0.6 million recorded as Gain (loss) on divestiture and other, net in the consolidated statements of operations. We previously held a 50% interest in, and operated, the Newcastle system.

Presentation of Partnership assets.The term “Partnership assets” includes both the assets owned and the interests accounted for under the equity method by us, through our partnership interests in WES Operating as of ~~March 31,~~June 30, 2019 (see Note 8—Equity Investments in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q). Because we own the entire non-economic general partner interest in and control WES Operating GP, and our general partner is controlled by Anadarko, each acquisition of assets from Anadarko has been considered a transfer of net assets between entities under common control. As such, assets acquired from Anadarko were initially recorded at Anadarko’s historic carrying value, which did not correlate to the total acquisition price paid by us. Further, after an acquisition of assets from Anadarko, we are required to recast our financial statements to include the activities of such assets from the date of common control.

For those periods requiring recast, the consolidated financial statements for periods prior to the acquisition of assets from Anadarko are prepared from Anadarko’s historical cost-basis accounts and may not necessarily be indicative of the actual results of operations that would have occurred if we had owned the assets during the periods reported. For ease of reference, we refer to the historical financial results of the Partnership assets prior to the acquisitions from Anadarko as being “our” historical financial results.

EQUITY OFFERINGS

See Note 5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

WES common units. In February 2019, we issued 234,053,065 common units in connection with the closing of the Merger. See Note 1—Description of Business and Basis of Presentation and Note 5—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

WES Operating common units. In February 2019, WES Operating (i) converted the IDRs and general partner units into 105,624,704 common units in connection with the closing of the Merger and (ii) issued 45,760,201 common units as part of the AMA acquisition.

WES Operating Class C units. All outstanding Class C units converted into WES Operating common units on a one-for-one basis immediately prior to the closing of the Merger.

RESULTS OF OPERATIONS

OPERATING RESULTS

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


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands	2019			2018			2019			2018			2019			2018
Total revenues and other ⁽¹⁾	$	671,883		$	501,054		$	685,054		$	518,078		$	1,356,937		$	1,019,132
Equity income, net – affiliates	57,992			30,229			63,598			49,430			121,590			79,659
Total operating expenses ⁽¹⁾	410,357			306,532			437,531			453,464			847,888			759,996
Gain (loss) on divestiture and other, net	(590		)	116			(1,061		)	170			(1,651		)	286
Operating income (loss)	318,928			224,867			310,060			114,214			628,988			339,081
Interest income – affiliates	4,225			4,225			4,225			4,225			8,450			8,450
Interest expense	(65,876		)	(38,015		)	(79,472		)	(42,245		)	(145,348		)	(80,260		)
Other income (expense), net	(35,206		)	817			(58,477		)	1,277			(93,683		)	2,094
Income (loss) before income taxes	222,071			191,894			176,336			77,471			398,407			269,365
Income tax (benefit) expense	10,092			10,884			1,278			10,304			11,370			21,188
Net income (loss)	211,979			181,010			175,058			67,167			387,037			248,177
Net income attributable to noncontrolling interests	93,319			49,483			5,464			(33,017		)	98,783			16,466
Net income (loss) attributable to Western Midstream Partners, LP ⁽²⁾	$	118,660		$	131,527		$	169,594		$	100,184		$	288,254		$	231,711
Key performance metrics ⁽³⁾
Adjusted gross margin	$	587,694		$	418,834		$	596,476		$	430,873		$	1,184,170		$	849,707
Adjusted EBITDA	428,330			312,140			432,920			311,144			861,250			623,284
Distributable cash flow	340,168			264,088			335,485			249,121			675,653			513,209

⁽¹⁾

Revenues and other include amounts earned from services provided to our affiliates, as well as from the sale of residue and NGLs to our affiliates. Operating expenses include amounts charged by our affiliates for services, as well as reimbursement of amounts paid by affiliates to third parties on our behalf. See Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.


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


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

For purposes of the following discussion, any increases or decreases “for the three months ended ~~March 31,~~June 30, 2019” refer to the comparison of the three months ended ~~March 31,~~June 30, 2019, to the three months ended ~~March 31,~~June 30, 2018; any increases or decreases “for the six months ended June 30, 2019” refer to the comparison of the six months ended June 30, 2019, to the six months ended June 30, 2018; and any increases or decreases “for the three and six months ended June 30, 2019” refer to the comparison of these 2019 periods to the corresponding three and six month periods ended June 30, 2018.

Throughput


	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)		2019	2018	Inc/ (Dec)
Throughput for natural gas assets (MMcf/d)
Gathering, treating and transportation	527	508	4	%	528	540	(2	)%	527	524	1	%
Processing	3,471	3,101	12	%	3,524	3,243	9	%	3,498	3,173	10	%
Equity investment ⁽¹⁾	377	294	28	%	402	296	36	%	390	295	32	%
Total throughput for natural gas assets	4,375	3,903	12	%	4,454	4,079	9	%	4,415	3,992	11	%
Throughput attributable to noncontrolling interests for natural gas assets ⁽²⁾	176	172	2	%	178	174	2	%	177	173	2	%
Total throughput attributable to Western Midstream Partners, LP for natural gas assets	4,199	3,731	13	%	4,276	3,905	10	%	4,238	3,819	11	%
Throughput for crude oil, NGLs and produced water assets (MBbls/d)
Gathering, treating, transportation and disposal	820	350	134	%	817	392	108	%	819	371	121	%
Equity investment ⁽³⁾	304	155	96	%	311	219	42	%	308	187	65	%
Total throughput for crude oil, NGLs and produced water assets	1,124	505	123	%	1,128	611	85	%	1,127	558	102	%
Throughput attributable to noncontrolling interests for crude oil, NGLs and produced water assets ⁽²⁾	22	10	120	%	23	12	92	%	23	11	109	%
Total throughput attributable to Western Midstream Partners, LP for crude oil, NGLs and produced water assets	1,102	495	123	%	1,105	599	84	%	1,104	547	102	%


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

⁽²⁾

For all periods presented, includes (i) the 25% interest in Chipeta held by a third-party member and (ii) the 2.0% limited partner interest in WES Operating held by a subsidiary of Anadarko, which collectively represent WES’s noncontrolling interests as of ~~March 31,~~June 30, 2019. For a discussion of the impact to noncontrolling interests as a result of the Merger closing, see Noncontrolling interests within 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.


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

Natural gas assets

Gathering, treating and transportation throughput decreased by 12 MMcf/d for the three months ended June 30, 2019, primarily due to production declines in the areas around the Springfield gas gathering system and Bison facility. These decreases were partially offset by increased production in the areas around the Marcellus Interest systems.

Gathering, treating and transportation throughput increased by 193 MMcf/d for the ~~three~~six months ended ~~March 31,~~June 30, 2019, primarily due to (i) increased production in the areas around the Marcellus Interest systems and (ii) volumes from the Bison facility being taken to a third-party treater in the first quarter of 2018 and a new contract effective April 2018, ~~and (ii) increased~~partially offset by production declines in the ~~areas around the Marcellus Interest systems.~~area. These increases were partially offset by lower throughput at the Springfield gas gathering system due to production declines in the area.

Processing throughput increased by ~~370~~281 MMcf/d for the three months ended June 30, 2019, primarily due to (i) increased production in the areas around the DJ Basin and West Texas complexes, (ii) the start-up of Mentone Trains I and II at the West Texas complex in November 2018 and March ~~31,~~2019, respectively, and (iii) increased production in the areas around the Granger complex. These increases were partially offset by lower throughput at the Granger straddle plant.

Processing throughput increased by 325 MMcf/d for the six months ended June 30, 2019, primarily due to (i) increased production in the areas around the West Texas and DJ Basin complexes and (ii) the start-up of Mentone ~~Train~~Trains I and II at the West Texas complex in November ~~2018.~~2018 and March 2019, respectively. These increases were partially offset by lower throughput at the Chipeta complex due to production declines in the area.

Equity investment throughput increased by 83106 MMcf/d and 95 MMcf/d for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to the acquisition of the interest in Red Bluff Express in January 2019, partially offset by decreased throughput at ~~(i)~~ the Mi Vida ~~plant~~and Ranch Westex plants due to affiliate volumes being processed at the West Texas complex following the start-up of Mentone ~~Train~~Trains I and ~~(i)~~II in November 2018 and March 2019, respectively. In addition, for the six months ended June 30, 2019, the increase in equity investment throughput was partially offset by lower volumes at the Rendezvous system due to ~~production declines~~downtime at the Granger complex in the ~~area.~~first quarter of 2019.

Crude oil, NGLs and produced water assets

Gathering, treating, transportation and disposal throughput increased by ~~470~~425 MBbls/d and 448 MBbls/d for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) increased throughput at the DBM water systems due to the new water disposal systems that commenced operation during the third and fourth quarters of 2018 and (ii) increased throughput at the DBM oil system due to the ROTFs that commenced operation in the second quarter of 2018 and increased production in the area.

Equity investment throughput increased by ~~149~~92 MBbls/d and 121 MBbls/d for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) the acquisition of the interest in Whitethorn LLC in June 2018 and (ii) increased volumes ~~on TEP and FRP as a result of~~at the Saddlehorn pipeline due to increased ~~NGLs~~ production in the DJ Basin ~~area.~~area and a new tariff structure beginning in the second quarter of 2019. For the three months ended June 30, 2019, these increases were partially offset by lower volumes on TEP due to the start-up of a third-party NGLs pipeline in the first quarter of 2019.

Service Revenues


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages	2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)
Service revenues – fee based	$	579,974	$	393,773	47	%	$	593,544	$	431,861	37	%	$	1,173,518	$	825,634	42	%
Service revenues – product based	19,379		23,423		(17	)%	16,675		22,662		(26	)%	36,054		46,085		(22	)%
Total service revenues	$	599,353	$	417,196	44	%	$	610,219	$	454,523	34	%	$	1,209,572	$	871,719	39	%

Service revenues – fee based increased by ~~$186.2~~$161.7 million for the three months ended ~~March 31,~~June 30, 2019, primarily due to increases of (i) ~~$90.9 million, $26.6~~$73.3 million and ~~$18.0~~$24.4 million at the West Texas ~~complex,~~and DJ Basin ~~complex and DBM oil system,~~complexes, respectively, due to increased throughput, (ii) ~~$36.4~~$35.6 million at the DBM water systems due to increased throughput and new gathering and disposal agreements effective July 1, 2018, ~~and~~ (iii) ~~$13.6~~$13.7 million at the DJ Basin oil system due to increased throughput and a higher gathering ~~fee.~~fee due to a cost of service rate adjustment in the fourth quarter of 2018, and (iv) $13.4 million at the DBM oil system due to increased throughput and a higher average gathering fee due to a new agreement effective May 2018.

Service revenues – fee based increased by $347.9 million for the six months ended June 30, 2019, primarily due to increases of (i) $164.2 million and $50.9 million at the West Texas and DJ Basin complexes, respectively, due to increased throughput, (ii) $72.0 million at the DBM water systems due to increased throughput and new gathering and disposal agreements effective July 1, 2018, (iii) $31.4 million at the DBM oil system due to increased throughput and a higher average gathering fee due to a new agreement effective May 2018, and (iv) $27.3 million at the DJ Basin oil system due to increased throughput and a higher gathering fee due to a cost of service rate adjustment in the fourth quarter of 2018.

Service revenues – product based decreased by ~~$4.0~~$6.0 million and $10.0 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) a contract termination at the West Texas complex in the first quarter of 2019 and (ii) decreased throughput at the Chipeta ~~and Granger complexes.~~complex.

Product Sales


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages and per-unit amounts	2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)
Natural gas sales ⁽¹⁾	$	27,324	$	29,837	(8	)%	$	8,227	$	12,225	(33	)%	$	35,551	$	42,062	(15	)%
NGLs sales ⁽¹⁾	44,809		53,788		(17	)%	66,242		51,090		30	%	111,051		104,878		6	%
Total Product sales	$	72,133	$	83,625	(14	)%	$	74,469	$	63,315	18	%	$	146,602	$	146,940	—	%
Gross average sales price per unit ⁽¹⁾:
Natural gas (per Mcf)	$	2.34	$	2.49	(6	)%	$	1.13	$	1.99	(43	)%	$	1.77	$	2.24	(21	)%
NGLs (per Bbl)	25.54		29.80		(14	)%	20.92		32.12		(35	)%	23.09		31.11		(26	)%

⁽¹⁾

For the three and six months ended ~~March 31,~~June 30, 2018, includes the effects of commodity price swap agreements for the MGR assets and DJ Basin complex, excluding the amounts considered above market with respect to these swap agreements that were recorded as capital contributions in the consolidated statement of equity and partners’ capital. See Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Natural gas sales decreased by ~~$2.5~~$4.0 million for the three months ended ~~March 31,~~June 30, 2019, primarily due to a decrease of ~~$9.1~~$12.6 million at the West Texas complex due to a decrease in average price and volumes sold. This decrease was partially offset by an increase of $8.7 million at the Hilight system primarily due to the reversal of an accrual for anticipated costs recorded in 2018 associated with the shutdown of the Kitty Draw gathering system (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).

Natural gas sales decreased by $6.5 million for the six months ended June 30, 2019, primarily due to a decrease of $21.7 million at the West Texas complex due to a decrease in average price, partially offset by an increase in volumes sold. This decrease was partially offset by an increase of ~~$4.8~~$13.5 million at the Hilight system primarily due to the reversal of an accrual for anticipated costs recorded in 2018 associated with the shutdown of the Kitty Draw gathering system (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),.

NGLs sales increased by $15.2 million for the three months ended June 30, 2019, primarily due to increases of $12.2 million and $4.9 million at the West Texas and DJ Basin complexes, respectively, due to increases in volumes sold, partially offset by decreases in average prices.

NGLs sales increased by $6.2 million for the six months ended June 30, 2019, primarily due to an increase of $15.1 million at the DJ Basin complex due to an increase in volumes sold, partially offset by a decrease in ~~volumes sold.~~

~~NGLs sales decreased~~average price. This increase was partially offset by ~~$9.0 million for the three months ended March 31, 2019, primarily due to~~ decreases of (i) ~~$17.1~~$4.9 million at the West Texas complex due to a decrease in volumes sold, (ii) $3.4 million at the Granger complex due to a decrease in average price, ~~and~~partially offset by an increase in volumes sold, and ~~(ii) $2.7~~(iii) $3.1 million at the MGR assets due to a decrease in volumes sold and ~~a decrease in price due to~~ the expiration of the commodity price swap agreements in December 2018. ~~These decreases were partially offset by an increase of $10.6 million at the DJ Basin complex due to an increase in volumes sold.~~

Equity Income, Net – Affiliates


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages	2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)
Equity income, net – affiliates	$	57,992	$	30,229	92	%	$	63,598	$	49,430	29	%	$	121,590	$	79,659	53	%

Equity income, net – affiliates increased by ~~$27.8~~$14.2 million and $41.9 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) the acquisition of the interest in Whitethorn LLC in June 2018 and (ii) increased volumes at FRP and the ~~TEFR Interests.~~Saddlehorn pipeline. These increases were partially offset by decreases in deficiency fees at TEP.

Cost of Product and Operation and Maintenance Expenses


	Three Months Ended March 31,						Three Months Ended June 30,							Six Months Ended June 30,
thousands except percentages	2019		2018		Inc/ (Dec)		2019		2018			Inc/ (Dec)		2019		2018			Inc/ (Dec)
NGLs purchases	$	79,819	$	60,521	32	%	$	95,856	$	74,039		29	%	$	175,675	$	134,560		31	%
Residue purchases	33,640		32,138		5	%	17,980		24,436			(26	)%	51,620		56,574			(9	)%
Other	604		1,659		(64	)%	9,041		(2,819		)	NM		9,645		(1,160		)	NM
Cost of product	114,063		94,318		21	%	122,877		95,656			28	%	236,940		189,974			25	%
Operation and maintenance	142,829		96,795		48	%	148,431		112,789			32	%	291,260		209,584			39	%
Total Cost of product and Operation and maintenance expenses	$	256,892	$	191,113	34	%	$	271,308	$	208,445		30	%	$	528,200	$	399,558		32	%

NM—Not Meaningful

NGL purchases increased by ~~$19.3~~$21.8 million and $41.1 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to increases of (i) ~~$18.6~~$21.8 million and $40.3 million, respectively, at the West Texas complex due to an increase in volumes purchased, partially offset by a decrease in average price, and (ii) ~~$5.1~~$4.2 million and $9.3 million, respectively, at the DJ Basin complex due to an increase in volumes purchased, partially offset by a decrease in average price. These increases were partially offset by decreases of (i) $3.7 million and $5.3 million, respectively, at the Granger complex due to a decrease ofin average price, partially offset by an increase in volumes purchased, and (ii) $2.5 million and $4.9 million, respectively, at the MGR assets due to a decrease in average price and volumes purchased.

Residue purchases ~~increased~~decreased by ~~$1.5~~$6.5 million for the three months ended ~~March 31,~~June 30, 2019, primarily due to ~~an increase~~a decrease of ~~$4.2~~$7.2 million at the ~~DJ Basin~~West Texas complex due to ~~an increase~~a decrease in average price and volumes purchased. ~~This increase was partially offset~~

Residue purchases decreased by $5.0 million for the six months ended June 30, 2019, primarily due to a decrease of ~~$2.8~~$10.0 million at the West Texas complex due to a decrease in average price, partially offset by an increase in volumes purchased. This decrease was partially offset by an increase of $5.7 million at the DJ Basin complex due to an increase in average price and volumes purchased.

Other items ~~decreased~~increased by ~~$1.1~~$11.9 million and $10.8 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to ~~a decrease~~increases of ~~$5.5~~(i) $8.1 million and $2.9 million, respectively, from changes in imbalance positions at the West Texas complex ~~partially offset by an increase of $2.5~~and (ii) $2.7 million and $4.0 million, respectively, at the ~~West Texas~~DJ Basin complex due to an increase in volumes purchased. In addition, for the six months ended June 30, 2019, other items increased by $2.7 million at the Granger complex due to fees related to the adoption of Revenue from Contracts with Customers (Topic 606) recorded beginning in the third quarter of 2018.

Operation and maintenance expense increased by ~~$46.0~~$35.6 million for the three months ended ~~March 31,~~June 30, 2019, primarily due to increases of (i) ~~$16.5~~$13.3 million at the DBM water systems due to the new water disposal systems that commenced operation during the third and fourth quarters of 2018, (ii) ~~$15.7~~$12.9 million and $4.8 million at the West Texas complex and DBM oil system, respectively, due to increases in surface maintenance and plant repairs, salaries and wages, and utilities expense, and (iii) $2.3 million at the DJ Basin complex due to increases in utilities expense.

Operation and maintenance expense increased by $81.7 million for the six months ended June 30, 2019, primarily due to increases of (i) $29.3 million and $12.1 million at the West Texas complex and DBM oil system, respectively, due to increases in salaries and wages, ~~and utilities expense, (iii) $7.2 million at the DBM oil system due to increases in salaries and wages and~~ surface maintenance and plant repairs, and ~~(iv) $5.0~~utilities expense, (ii) $27.8 million at the DBM water systems due to the new water disposal systems that commenced operation during the third and fourth quarters of 2018, and (iii) $7.7 million at the DJ Basin complex due to increases in utilities expense ~~salaries~~ and ~~wages,~~contract labor and ~~surface maintenance and plant repairs.~~

consulting services.

Other Operating Expenses


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages	2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)
General and administrative	$	22,844	$	15,829	44	%	$	30,027	$	15,597	93	%	$	52,871	$	31,426	68	%
Property and other taxes	16,285		14,600		12	%	14,282		13,750		4	%	30,567		28,350		8	%
Depreciation and amortization	113,946		84,790		34	%	121,117		88,488		37	%	235,063		173,278		36	%
Impairments	390		200		95	%	797		127,184		(99	)%	1,187		127,384		(99	)%
Total other operating expenses	$	153,465	$	115,419	33	%	$	166,223	$	245,019	(32	)%	$	319,688	$	360,438	(11	)%

General and administrative expenses increased by ~~$7.0~~$14.4 million and $21.4 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to personnel costs for which we reimbursed Anadarko pursuant to our omnibus agreement.

Property and other taxes increased by ~~$1.7~~$2.2 million for the ~~three~~six months ended ~~March 31,~~June 30, 2019, primarily due to ad valorem tax increases at the West Texas complex.

Depreciation and amortization ~~expense~~expense increased by ~~$29.2~~$32.6 million forand $61.8 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to increases of (i) ~~$11.2~~$11.5 million and $22.7 million, respectively, at the West Texas complex, (ii) ~~$6.5~~$8.5 million and $15.0 million, respectively, at the DBM water systems, (iii) ~~$5.3~~$5.9 million and $10.3 million, respectively, at the DJ Basin complex, and (iv) $4.6 million and $9.8 million, respectively, at the DBM oil system, ~~and (iv) $4.4 million at the DJ Basin complex,~~ all due to capital projects being placed into service. For further information regarding capital projects, see Liquidity and Capital Resources—Capital expenditures within this Item 2.

Impairment expense for the three and six months ended June 30, 2018, was primarily due to impairments of $120.8 million at the Third Creek gathering system and $6.4 million at the Kitty Draw gathering system. 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.

Interest Income – Affiliates and Interest Expense


	Three Months Ended March 31,								Three Months Ended June 30,								Six Months Ended June 30,
thousands except percentages	2019			2018			Inc/ (Dec)		2019			2018			Inc/ (Dec)		2019			2018			Inc/ (Dec)
Note receivable – Anadarko	$	4,225		$	4,225		—	%	$	4,225		$	4,225		—	%	$	8,450		$	8,450		—	%
Interest income – affiliates	$	4,225		$	4,225		—	%	$	4,225		$	4,225		—	%	$	8,450		$	8,450		—	%
Third parties
Long-term debt	$	(67,096	)	$	(41,536	)	62	%	$	(82,624	)	$	(48,671	)	70	%	$	(149,720	)	$	(90,207	)	66	%
Amortization of debt issuance costs and commitment fees	(3,152		)	(2,864		)	10	%	(3,170		)	(2,037		)	56	%	(6,322		)	(4,901		)	29	%
Capitalized interest	6,205			6,962			(11	)%	6,342			9,872			(36	)%	12,547			16,834			(25	)%
Affiliates
APCWH Note Payable	(1,833		)	(577		)	NM		—			(1,409		)	(100	)%	(1,833		)	(1,986		)	(8	)%
Finance lease liabilities									(20		)	—			NM		(20		)	—			NM
Interest expense	$	(65,876	)	$	(38,015	)	73	%	$	(79,472	)	$	(42,245	)	88	%	$	(145,348	)	$	(80,260	)	81	%

Interest expense increased by ~~$27.9~~$37.2 million and $65.1 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) $26.9 million and $35.9 million, respectively, of interest incurred on the Term loan facility and higher outstanding borrowings on the RCF in 2019, and (ii) $9.7 million and $19.3 million, respectively, of interest incurred on the 4.750% Senior Notes due 2028 and 5.500% Senior Notes due 2048 that were issued in August ~~2018, (ii) $9.4~~2018. In addition, for the six months ended June 30, 2019, interest expense increased due to $9.5 million of interest incurred on the 4.500% Senior Notes due 2028 and 5.300% Senior Notes due 2048 that were issued in March ~~2018, and (iii) $9.0 million of interest incurred on the RCF due to higher outstanding borrowings in 2019.~~2018.

Other Income (Expense), Net


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages	2019			2018		Inc/ (Dec)	2019			2018		Inc/ (Dec)	2019			2018		Inc/ (Dec)
Other income (expense), net	$	(35,206	)	$	817	NM	$	(58,477	)	$	1,277	NM	$	(93,683	)	$	2,094	NM

Other income (expense), net decreased by ~~$36.0~~$59.8 million and $95.8 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to a non-cash ~~loss~~losses of ~~$35.6~~$59.0 million and $94.6 million, respectively, on interest-rate swaps resulting from a decrease in benchmark interest rates. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

Income Tax (Benefit) Expense


	Three Months Ended March 31,								Three Months Ended June 30,								Six Months Ended June 30,
thousands except percentages	2019			2018			Inc/ (Dec)		2019			2018			Inc/ (Dec)		2019			2018			Inc/ (Dec)
Income (loss) before income taxes	$	222,071		$	191,894		16	%	$	176,336		$	77,471		128	%	$	398,407		$	269,365		48	%
Income tax (benefit) expense	10,092			10,884			(7	)%	1,278			10,304			(88	)%	11,370			21,188			(46	)%
Effective tax rate	5		%	6		%			1		%	13		%			3		%	8		%

We are not a taxable entity for U.S. federal income tax purposes. However, our income apportionable to Texas is subject to Texas margin tax. For the periods presented, the variance from the federal statutory rate, which is zero percent as a non-taxable entity, is primarily due to federal and state taxes on pre-acquisition income attributable to assets acquired from Anadarko, and our share of Texas margin tax.

Income attributable to the AMA assets prior to and including February 2019 was subject to federal and state income tax. Income earned on the AMA assets for periods subsequent to February 2019 was only subject to Texas margin tax on income apportionable to Texas.

KEY PERFORMANCE METRICS


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands except percentages and per-unit amounts	2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)		2019		2018		Inc/ (Dec)
Adjusted gross margin for natural gas assets ⁽¹⁾	$	412,428	$	335,614	23	%	$	412,494	$	336,440	23	%	$	824,922	$	672,054	23	%
Adjusted gross margin for crude oil, NGLs and produced water assets ⁽²⁾	175,266		83,220		111	%	183,982		94,433		95	%	359,248		177,653		102	%
Adjusted gross margin ⁽³⁾	587,694		418,834		40	%	596,476		430,873		38	%	1,184,170		849,707		39	%
Adjusted gross margin per Mcf for natural gas assets ⁽⁴⁾	1.09		1.00		9	%	1.06		0.95		12	%	1.08		0.97		11	%
Adjusted gross margin per Bbl for crude oil, NGLs and produced water assets ⁽⁵⁾	1.77		1.87		(5	)%	1.83		1.73		6	%	1.80		1.79		1	%
Adjusted EBITDA ⁽³⁾	428,330		312,140		37	%	432,920		311,144		39	%	861,250		623,284		38	%
Distributable cash flow ⁽³⁾	340,168		264,088		29	%	335,485		249,121		35	%	675,653		513,209		32	%

⁽¹⁾

Adjusted gross margin for natural gas assets is calculated as total revenues and other for natural gas assets (less reimbursements for electricity-related expenses recorded as revenue), less cost of product for natural gas assets, plus distributions from our equity investments, and excluding the noncontrolling interests owners’ proportionate share of revenues and cost of product. See the reconciliation of Adjusted gross margin for natural gas assets to its most comparable GAAP measure below.

⁽²⁾

Adjusted gross margin for crude oil, NGLs and produced water assets is calculated as total revenues and other for crude oil, NGLs and produced water assets (less reimbursements for electricity-related expenses recorded as revenue), less cost of product for crude oil, NGLs and produced water assets, plus distributions from our equity investments, and excluding the noncontrolling interests owners’ proportionate share of revenues and cost of product. See the reconciliation of Adjusted gross margin for crude oil, NGLs and produced water assets to its most comparable GAAP measure below.


⁽³⁾	For a reconciliation of Adjusted gross margin, Adjusted EBITDA and Distributable cash flow to the most directly comparable financial measure calculated and presented in accordance with GAAP, see the ~~description~~descriptions below.


⁽⁴⁾	Average for period. Calculated as Adjusted gross margin for natural gas assets, divided by total throughput (MMcf/d) attributable to Western Midstream Partners, LP for natural gas assets.


⁽⁵⁾	Average for period. Calculated as Adjusted gross margin for crude oil, NGLs and produced water assets, divided by total throughput (MBbls/d) attributable to Western Midstream Partners, LP for crude oil, NGLs and produced water assets.

Adjusted gross margin. We define Adjusted gross margin attributable to Western Midstream Partners, LP (“Adjusted gross margin”) as total revenues and other (less reimbursements for electricity-related expenses recorded as revenue), less cost of product, plus distributions from equity investments, and excluding the noncontrolling interests owners’ proportionate share of revenues and cost of product. We believe Adjusted gross margin is an important performance measure of the core profitability of our operations, as well as our operating performance as compared to that of other companies in the midstream industry.

Adjusted gross margin increased by ~~$168.9~~$165.6 million and $334.5 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) increased throughput at the West Texas and DJ Basin complexes, ~~and DBM oil system,~~ (ii) the start-up of the new water disposal systems during the third and fourth quarters of 2018, (iii) the acquisition of the interest in Whitethorn LLC in June 2018, ~~and~~ (iv) increased throughput and a higher gathering fee due to a cost of service rate adjustment in the fourth quarter of 2018 at the DJ Basin oil system, and (v) increased throughput and a higher average gathering fee due to a new agreement effective May 2018 at the DBM oil system.

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

Adjusted gross margin per Mcf for natural gas assets increased by ~~$0.09~~$0.11 for the three and six months ended ~~March 31,~~June 30, 2019, primarily due to (i) a cost of service rate adjustment at the Springfield gas gathering system in the fourth quarter of 2018 and (ii) increased throughput at the West Texas complex, which has a higher-than-average margin as compared to our other natural gas ~~assets, and (ii) a cost of service rate adjustment at the Springfield gas gathering system in the fourth quarter of 2018.~~assets.

Adjusted gross margin per Bbl for crude oil, NGLs and produced water assets ~~decreased~~increased by $0.10 for the three months ended ~~March 31,~~June 30, 2019, primarily due to (i) the acquisition of the interest in Whitethorn LLC in June 2018, (ii) increased throughput and a higher gathering fee due to a cost of service rate adjustment in the fourth quarter of 2018 at the DJ Basin oil system, and (iii) increased throughput and a higher average gathering fee due to a new agreement effective May 2018 at the DBM oil system. These increases were partially offset by increased throughput at the DBM water systems, which has a lower margin per Bbl than our other crude oil and NGLs assets, partially offset by (i) the acquisition of the interest in Whitethorn LLC in June 2018, (ii) increased throughput and a higher gathering fee at the DJ Basin oil system and (iii) increased throughput at the DBM oil system.assets.

Adjusted EBITDA. We define Adjusted EBITDA attributable to Western Midstream Partners, LP (“Adjusted EBITDA”) as net income (loss), plus distributions from equity investments, non-cash equity-based compensation expense, interest expense, income tax expense, depreciation and amortization, impairments, and other expense (including lower of cost or market inventory adjustments recorded in cost of product), less gain (loss) on divestiture and other, net, income from equity investments, interest income, income tax benefit, and other income and excluding the noncontrolling interests owners’ proportionate share of revenues and expenses. We believe that 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 to assess the following, among other measures:

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 expenditure projects and the returns on investment of various investment opportunities.

Adjusted EBITDA increased by ~~$116.2~~$121.8 million and $238.0 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) ~~a $170.8~~increases of $167.0 million ~~increase~~and $337.8 million, respectively, in total revenues and other and (ii) ~~a $21.6~~increases of $31.8 million ~~increase~~and $53.4 million, respectively, in distributions from equity investments. These amounts were partially offset by (i) ~~a $46.0~~increases of $35.6 million ~~increase~~and $81.7 million, respectively, in operation and maintenance expenses, (ii) ~~a $19.9~~increases of $27.1 million ~~increase~~and $46.9 million, respectively, in cost of product (net of lower of cost or market inventory adjustments), and (iii) ~~a $7.4~~increases of $12.1 million ~~increase~~and $19.5 million, respectively, in general and administrative expenses excluding non-cash equity-based compensation expense.

Distributable cash flow. We define “Distributable cash flow” as Adjusted EBITDA, plus interest income and the net settlement amounts from the sale and/or purchase of natural gas, condensate and NGLs under WES Operating’s commodity price swap agreements to the extent such amounts are not recognized as Adjusted EBITDA, less Service revenues – fee based recognized in Adjusted EBITDA (less than) in excess of customer billings, net cash paid (or to be paid) for interest expense (including amortization of deferred debt issuance costs originally paid in cash, offset by non-cash capitalized interest), maintenance capital expenditures, and income taxes and excluding Distributable cash flow attributable to noncontrolling interests to the extent such amounts are not excluded from Adjusted EBITDA. We compare Distributable cash flow to the cash distributions we expect to pay our unitholders. Using this measure, management can quickly compute the Coverage ratio of Distributable cash flow to planned cash distributions. We believe Distributable cash flow is useful to investors because this measurement is used by many companies, analysts and others in the industry as a performance measurement tool to evaluate our operating and financial performance and compare it with the performance of other publicly traded partnerships.

While Distributable cash flow is a measure we use to assess our ability to make distributions to our unitholders, it should not be viewed as indicative of the actual amount of cash that we have available for distributions or that we plan to distribute for a given period. Furthermore, to the extent Distributable cash flow includes realized amounts recorded as capital contributions from Anadarko attributable to activity under our commodity price swap agreements, it is not a reflection of our ability to generate cash from operations.

Distributable cash flow increased by ~~$76.1~~$86.4 million and $162.4 million for the three and six months ended ~~March 31,~~June 30, 2019, respectively, primarily due to (i) ~~a $116.2~~increases of $121.8 million ~~increase~~and $238.0 million, respectively, in Adjusted EBITDA and (ii) ~~$7.7~~$13.6 million and $21.3 million, respectively, of customer billings in excess of the amount recognized as Service revenues –- fee based. These amounts were partially offset by (i) ~~a $27.1~~increases of $33.7 million ~~increase~~and $60.8 million, respectively, in net cash paid for interest expense, (ii) ~~a $14.5~~decreases of $13.8 million ~~increase in cash paid for maintenance capital expenditures,~~ and ~~(iii) a $6.9~~$20.7 million, ~~decrease~~respectively, in the above-market component of the swap agreements with ~~Anadarko.~~Anadarko, and (iii) increases of $2.2 million and $16.7 million, respectively, in cash paid for maintenance capital expenditures.

Reconciliation of non-GAAP measures.Adjusted gross margin, Adjusted EBITDA and Distributable cash flow are not defined in GAAP. The GAAP measure used by us that is most directly comparable to Adjusted gross margin is operating income (loss), while net income (loss) and net cash provided by operating activities are the GAAP measures used by us that are most directly comparable to Adjusted EBITDA. The GAAP measure used by us that is most directly comparable to Distributable cash flow is net income (loss). Our non-GAAP financial measures of Adjusted gross margin, Adjusted EBITDA and Distributable cash flow should not be considered as alternatives to the GAAP measures of operating income (loss), 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 Distributable cash flow have important limitations as analytical tools because they exclude some, but not all, items that affect operating income (loss), net income (loss) and net cash provided by operating activities. Adjusted gross margin, Adjusted EBITDA and Distributable 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 Distributable cash flow may not be comparable to similarly titled measures of other companies in our industry, thereby diminishing their utility.

Management compensates for the limitations of Adjusted gross margin, Adjusted EBITDA and Distributable cash flow as analytical tools by reviewing the comparable GAAP measures, understanding the differences between Adjusted gross margin, Adjusted EBITDA and Distributable cash flow compared to (as applicable) operating income (loss), 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 uses in evaluating our operating results.

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


	Three Months Ended March 31,					Three Months Ended June 30,					Six Months Ended June 30,
thousands	2019			2018		2019			2018		2019			2018
Reconciliation of Operating income (loss) to Adjusted gross margin
Operating income (loss)	$	318,928		$	224,867	$	310,060		$	114,214	$	628,988		$	339,081
Add:
Distributions from equity investments	62,013			40,426		70,522			38,731		132,535			79,157
Operation and maintenance	142,829			96,795		148,431			112,789		291,260			209,584
General and administrative	22,844			15,829		30,027			15,597		52,871			31,426
Property and other taxes	16,285			14,600		14,282			13,750		30,567			28,350
Depreciation and amortization	113,946			84,790		121,117			88,488		235,063			173,278
Impairments	390			200		797			127,184		1,187			127,384
Less:
Gain (loss) on divestiture and other, net	(590		)	116		(1,061		)	170		(1,651		)	286
Equity income, net – affiliates	57,992			30,229		63,598			49,430		121,590			79,659
Reimbursed electricity-related charges recorded as revenues	16,589			15,457		20,189			17,262		36,778			32,719
Adjusted gross margin attributable to noncontrolling interests ⁽¹⁾	15,550			12,871		16,034			13,018		31,584			25,889
Adjusted gross margin	$	587,694		$	418,834	$	596,476		$	430,873	$	1,184,170		$	849,707
Adjusted gross margin for natural gas assets	$	412,428		$	335,614	$	412,494		$	336,440	$	824,922		$	672,054
Adjusted gross margin for crude oil, NGLs and produced water assets	175,266			83,220		183,982			94,433		359,248			177,653

⁽¹⁾


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands	2019			2018			2019			2018			2019			2018
Reconciliation of Net income (loss) to Adjusted EBITDA
Net income (loss)	$	211,979		$	181,010		$	175,058		$	67,167		$	387,037		$	248,177
Add:
Distributions from equity investments	62,013			40,426			70,522			38,731			132,535			79,157
Non-cash equity-based compensation expense	1,798			2,152			4,343			2,000			6,141			4,152
Interest expense	65,876			38,015			79,472			42,245			145,348			80,260
Income tax expense	10,092			10,884			1,278			10,304			11,370			21,188
Depreciation and amortization	113,946			84,790			121,117			88,488			235,063			173,278
Impairments	390			200			797			127,184			1,187			127,384
Other expense	35,213			143			58,639			8			93,852			151
Less:
Gain (loss) on divestiture and other, net	(590		)	116			(1,061		)	170			(1,651		)	286
Equity income, net – affiliates	57,992			30,229			63,598			49,430			121,590			79,659
Interest income – affiliates	4,225			4,225			4,225			4,225			8,450			8,450
Other income	—			817			—			1,277			—			2,094
Adjusted EBITDA attributable to noncontrolling interests ⁽¹⁾	11,350			10,093			11,544			9,881			22,894			19,974
Adjusted EBITDA	$	428,330		$	312,140		$	432,920		$	311,144		$	861,250		$	623,284
Reconciliation of Net cash provided by operating activities to Adjusted EBITDA
Net cash provided by operating activities	$	343,073		$	300,151		$	343,458		$	329,175		$	686,531		$	629,326
Interest (income) expense, net	61,651			33,790			75,247			38,020			136,898			71,810
Uncontributed cash-based compensation awards	(570		)	522			1,218			465			648			987
Accretion and amortization of long-term obligations, net	(1,511		)	(2,103		)	(1,337		)	(1,273		)	(2,848		)	(3,376		)
Current income tax (benefit) expense	6,027			(13,335		)	458			(14,335		)	6,485			(27,670		)
Other (income) expense, net⁽²⁾	(432		)	(817		)	(470		)	(1,277		)	(902		)	(2,094		)
Distributions from equity investments in excess of cumulative earnings – affiliates	7,792			8,850			9,260			4,782			17,052			13,632
Changes in assets and liabilities:
Accounts receivable, net	(9,486		)	29,632			6,818			(21,060		)	(2,668		)	8,572
Accounts and imbalance payables and accrued liabilities, net	55,529			(28,904		)	25,669			(13,136		)	81,198			(42,040		)
Other items, net	(22,393		)	(5,553		)	(15,857		)	(336		)	(38,250		)	(5,889		)
Adjusted EBITDA attributable to noncontrolling interests ⁽¹⁾	(11,350		)	(10,093		)	(11,544		)	(9,881		)	(22,894		)	(19,974		)
Adjusted EBITDA	$	428,330		$	312,140		$	432,920		$	311,144		$	861,250		$	623,284
Cash flow information
Net cash provided by operating activities	$	343,073		$	300,151								$	686,531		$	629,326
Net cash used in investing activities	(2,515,732		)	(524,219		)							(2,865,168		)	(1,287,904		)
Net cash provided by (used in) financing activities	2,180,564			668,166									2,182,290			634,307

⁽¹⁾


⁽²⁾	Excludes ~~the~~ non-cash ~~loss~~losses on interest-rate swaps of ~~$35.6~~$59.0 million and $94.6 million for the three and six months ended ~~March 31, 2019.~~June 30, 2019, respectively. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.


	Three Months Ended March 31,							Three Months Ended June 30,						Six Months Ended June 30,
thousands except Coverage ratio	2019				2018			2019				2018		2019				2018
Reconciliation of Net income (loss) to Distributable cash flow and calculation of the Coverage ratio
Net income (loss)	$	211,979			$	181,010		$	175,058			$	67,167	$	387,037			$	248,177
Add:
Distributions from equity investments	62,013				40,426			70,522				38,731		132,535				79,157
Non-cash equity-based compensation expense	1,798				2,152			4,343				2,000		6,141				4,152
Income tax (benefit) expense	10,092				10,884			1,278				10,304		11,370				21,188
Depreciation and amortization	113,946				84,790			121,117				88,488		235,063				173,278
Impairments	390				200			797				127,184		1,187				127,384
Above-market component of swap agreements with Anadarko ⁽¹⁾	7,407				14,282			—				13,839		7,407				28,121
Other expense	35,213				143			58,639				8		93,852				151
Less:
Recognized Service revenues – fee based (less than) in excess of customer billings	(6,258		)		1,400			(12,038		)		1,557		(18,296		)		2,957
Gain (loss) on divestiture and other, net	(590		)		116			(1,061		)		170		(1,651		)		286
Equity income, net – affiliates	57,992				30,229			63,598				49,430		121,590				79,659
Cash paid for maintenance capital expenditures	35,691				21,228			29,899				27,689		65,590				48,917
Capitalized interest	6,205				6,962			6,342				9,872		12,547				16,834
Cash paid for (reimbursement of) income taxes	96				(87		)	—				—		96				(87		)
Other income	—				817			—				1,277		—				2,094
Distributable cash flow attributable to noncontrolling interests ⁽²⁾	9,534				9,134			9,529				8,605		19,063				17,739
Distributable cash flow	$	340,168			$	264,088		$	335,485			$	249,121	$	675,653			$	513,209
Distributions declared
Distributions from WES Operating	$	277,604						$	282,319					$	559,923
Less: Cash reserve for the proper conduct of WES’s business	1,280							2,360						3,640
Distributions to WES unitholders ⁽³⁾	$	276,324						$	279,959					$	556,283
Coverage ratio	1.23			x				1.20			x			1.21			x


⁽¹⁾	See Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

⁽²⁾


⁽³⁾	Reflects a cash ~~distribution~~distributions of ~~$0.61000~~$0.61800 and $1.22800 per unit declared for the three and six months ended ~~March 31, 2019.~~June 30, 2019, respectively.

LIQUIDITY AND CAPITAL RESOURCES

Our primary cash requirements are for acquisitions and capital expenditures, debt service, customary operating expenses, quarterly distributions to our limited partners and to our general partner, and distributions to our noncontrolling interest owner. Our sources of liquidity as of ~~March 31,~~June 30, 2019, included cash and cash equivalents, cash flows generated from operations, interest income on our $260.0 million note receivable from Anadarko, available borrowing capacity under the RCF, and issuances of additional equity or debt securities. As of July 1, 2019, we have an additional $1.0 billion in available commitments under the Term loan facility, which may be drawn by WES Operating on or before September 30, 2019. We believe that cash flows generated from these sources will be sufficient to satisfy our short-term working capital requirements and long-term maintenance and expansion capital expenditure requirements. The amount of future distributions to unitholders will depend on our results of operations, financial condition, capital requirements and other factors and will be determined by the Board of Directors on a quarterly basis. Due to our cash distribution policy, we expect to rely on external financing sources, including equity and debt issuances, to fund expansion capital expenditures and future acquisitions. However, to limit interest expense, we may use operating cash flows to fund expansion capital expenditures or acquisitions, which could result in subsequent borrowings under the RCF to pay distributions or fund other short-term working capital requirements.

Our partnership agreement requires that we distribute all of our available cash (as defined in our partnership agreement) within 55 days of the end of each quarter. Our cash flow and resulting ability to make cash distributions are completely dependent upon our ability to generate favorable 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. We have made cash distributions to our unitholders each quarter since our IPO in 2012 and have increased our quarterly distribution each quarter since the fourth quarter of 2012. The Board of Directors declared a cash distribution to unitholders for the ~~first~~second quarter of 2019 of ~~$0.61000~~$0.61800 per unit, or ~~$276.3~~$280.0 million in aggregate. The cash distribution is payable on ~~May 14,~~August 13, 2019, to our unitholders of record at the close of business on ~~May 1,~~July 31, 2019.

Management continuously monitors our leverage position and coordinates our capital expenditure program, quarterly distributions and acquisition strategy with our expected cash flows and projected debt-repayment schedule. We will continue to evaluate funding alternatives, including additional borrowings and the issuance of debt or equity securities, to secure funds as needed or to refinance outstanding debt balances with longer term notes. 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. As of ~~March 31,~~June 30, 2019, we had a ~~$2.2 billion~~$163.1 million working capital deficit, which we define as the amount by which current liabilities exceed current assets. Working capital is an indication of liquidity and potential need for short-term funding. Working capital requirements are driven by changes in accounts receivable and accounts payable and 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 expansion activity. The working capital deficit as of ~~March 31,~~June 30, 2019, was primarily due to ~~(i) the borrowings under the 364-day Facility used to fund substantially all of the cash portion of the consideration under the Merger Agreement and the payment of related transaction costs and (ii)~~ the costs incurred related to continued construction and expansion at the West Texas and DJ Basin complexes, DBM oil system and DBM water systems. As of ~~March 31,~~June 30, 2019, there was ~~$1.4~~$1.1 billion available for borrowing under the RCF. See Note 9—Components of Working Capital and Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Capital expenditures. Our business is capital intensive, requiring significant investment to maintain and improve existing facilities or develop new midstream infrastructure. We categorize capital expenditures as either of the following:

maintenance capital expenditures, which include those expenditures required to maintain the existing operating capacity and service capability of our assets, such as to replace system components and equipment that have been subject to significant use over time, become obsolete or reached the end of their useful lives, to remain in compliance with regulatory or legal requirements or to complete additional well connections to maintain existing system throughput and related cash flows; or

expansion capital expenditures, which include expenditures to construct new midstream infrastructure and those expenditures incurred to extend the useful lives of our assets, reduce costs, increase revenues or increase system throughput or capacity from current levels, including well connections that increase existing system throughput.

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:


	Three Months Ended March 31,				Six Months Ended June 30,
thousands	2019		2018		2019		2018
Acquisitions	$	2,100,804	$	—	$	2,100,804	$	161,858

Expansion capital expenditures	$	350,430	$	511,957	$	638,786	$	1,063,540
Maintenance capital expenditures	35,714		21,228		65,639		48,934
Total capital expenditures ^{(1) (2)}	$	386,144	$	533,185	$	704,425	$	1,112,474

Capital incurred ^{(1) (3)}	$	315,020	$	587,561	$	570,886	$	1,127,531


⁽¹⁾	For the ~~three~~six months ended ~~March 31,~~June 30, 2019 and 2018, included ~~$4.7~~$9.5 million and ~~$7.0~~$16.8 million, respectively, of capitalized interest.


⁽²⁾	Capital expenditures for the ~~three~~six months ended ~~March 31,~~June 30, 2018, included ~~$230.9~~$462.4 million of pre-acquisition capital expenditures for AMA.


⁽³⁾	Capital incurred for the ~~three~~six months ended ~~March 31,~~June 30, 2018, included ~~$260.1~~$499.5 million of pre-acquisition capital incurred for AMA.

Acquisitions during 2019 included AMA and the 30% interest in Red Bluff Express. Acquisitions during 2018 included a 20% interest in Whitethorn LLC and a 15% interest in Cactus II. See Note 3—Acquisitions and Divestitures and Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Capital expenditures, excluding acquisitions, decreased by ~~$147.0~~$408.0 million for the ~~three~~six months ended ~~March 31,~~June 30, 2019. Expansion capital expenditures decreased by ~~$161.5~~$424.8 million (including a ~~$2.3~~$7.3 million decrease in capitalized interest) for the ~~three~~six months ended ~~March 31,~~June 30, 2019, primarily due to decreases of (i) ~~$82.4~~$237.0 million at the West Texas complex primarily due to the completion of Mentone ~~Train~~Trains I and II that commenced operation in November 2018 and March 2019, respectively, (ii) ~~$66.0~~$165.4 million at the DBM oil system primarily due to the completion of the ROTFs that commenced operation in the second quarter of 2018, and (iii) $110.5 million at the DBM water systems due to the completion of the water systems that commenced operation in the third and fourth quarters of ~~2018 and (iii) $62.9 million at the DBM oil system primarily due to the completion of the ROTFs that commenced operation in the second quarter of~~ 2018. These decreases were partially offset by an increase of ~~$47.6~~$80.7 million at the DJ Basin complex primarily due to ongoing construction of the Latham processing plant. Maintenance capital expenditures increased by ~~$14.5~~$16.7 million for the ~~three~~six months ended ~~March 31,~~June 30, 2019, primarily due to increases at the DBM oil system, ~~and the~~ DJ Basin complex and ~~West Texas complexes.~~DJ Basin oil system.

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


	Three Months Ended March 31,						Six Months Ended June 30,
thousands	2019			2018			2019			2018
Net cash provided by (used in):
Operating activities	$	343,073		$	300,151		$	686,531		$	629,326
Investing activities	(2,515,732		)	(524,219		)	(2,865,168		)	(1,287,904		)
Financing activities	2,180,564			668,166			2,182,290			634,307
Net increase (decrease) in cash and cash equivalents	$	7,905		$	444,098		$	3,653		$	(24,271	)

Operating Activities. Net cash provided by operating activities increased for the ~~three~~six months ended ~~March 31,~~June 30, 2019, primarily due to the impact of changes in working capital items and increases in distributions from equity investments. Refer to Operating Results within this Item 2 for a discussion of our results of operations as compared to the prior periods.

Investing Activities. Net cash used in investing activities for the ~~three~~six months ended ~~March 31,~~June 30, 2019, included the following:

$2.0 billion of cash paid for the acquisition of AMA;

$~~386.1~~704.4 million of capital expenditures, primarily related to construction and expansion at the West Texas and DJ Basin complexes, DBM oil system and DBM water systems;

$92.5 million of cash paid for the acquisition of the interest in Red Bluff Express;

$~~36.5~~77.3 million of capital contributions primarily paid to Cactus II, ~~Red Bluff Express,~~ the TEFR Interests, Whitethorn LLC, Red Bluff Express and White Cliffs for construction activities; and

$~~7.8~~17.1 million of distributions received from equity investments in excess of cumulative earnings.

Net cash used in investing activities for the ~~three~~six months ended ~~March 31,~~June 30, 2018, included the following:

$~~533.2 million~~1.1 billion of capital expenditures, primarily related to construction and expansion at the West Texas and DJ Basin complexes, DBM oil system and DBM water systems;

$161.9 million of cash paid for the acquisitions of the interests in Whitethorn LLC and Cactus II;

$27.5 million of capital contributions paid to Cactus II, Whitethorn LLC and White Cliffs for construction activities; and

$~~8.9~~13.6 million of distributions received from equity investments in excess of cumulative earnings.

Financing Activities. Net cash provided by financing activities for the ~~three~~six months ended ~~March 31,~~June 30, 2019, included the following:

$2.0 billion of borrowings under the ~~364-day Facility,~~Term loan facility, net of issuance costs, which were used to fund the acquisition of AMA and to repay the APCWH Note Payable;

$~~451.6 million of net contributions from Anadarko representing intercompany transactions attributable to the acquisition of AMA;~~

~~$439.6 million of repayments of the total outstanding balance under the APCWH Note Payable;~~

~~$420.0~~700.0 million of borrowings under the RCF, which were used for general partnership purposes, including to fund capital expenditures;

$~~131.9~~456.9 million of net contributions from Anadarko representing intercompany transactions attributable to the acquisition of AMA;

$439.6 million of repayments of the total outstanding balance under the APCWH Note Payable;

$408.2 million of distributions paid to WES unitholders;

$~~101.0~~106.7 million of distributions paid to the noncontrolling interest owners of WES Operating;

$28.0 million of repayments of the total outstanding balance under the WGP RCF, which matured in March 2019;

$11.0 million of borrowings under the APCWH Note Payable, which were used to fund the construction of the DBM water systems;

$7.4 million of capital contributions from Anadarko related to the above-market component of swap agreements; and

$~~1.9~~3.8 million of distributions paid to the noncontrolling interest owner of Chipeta.

Net cash provided by financing activities for the ~~three~~six months ended ~~March 31,~~June 30, 2018, included the following:

$1.08 billion of net proceeds from the offering of the 4.500% Senior Notes due 2028 and 5.300% Senior Notes due 2048 in March 2018, after underwriting and original issue discounts and offering costs, which were used to repay amounts outstanding under the RCF and for general partnership purposes, including to fund capital expenditures;

$630.0 million of repayments of outstanding borrowings under the RCF;

$256.8 million of borrowings under the RCF, net of extension costs, which were used for general partnership purposes, including to fund capital expenditures;

$~~120.1~~244.7 million of distributions paid to WES unitholders;

$~~106.6~~190.1 million of distributions paid to the noncontrolling interest owners of WES Operating;

$187.9 million of borrowings under the APCWH Note Payable, which were used to fund the construction of the DBM water systems;

$~~94.3 million of distributions paid to the noncontrolling interest owners of WES Operating;~~

~~$64.3~~157.3 million of net contributions from Anadarko representing intercompany transactions attributable to the acquisition of AMA;

$~~14.3~~28.1 million of capital contributions from Anadarko related to the above-market component of swap agreements; and

$~~3.4~~6.4 million of distributions paid to the noncontrolling interest owner of Chipeta.

Debt and credit facilities. As of ~~March 31,~~June 30, 2019, the carrying value of outstanding debt was ~~$7.2~~$7.5 billion. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Senior Notes. At ~~March 31,~~June 30, 2019, WES Operating was in compliance with all covenants under the indentures governing its outstanding notes.

WGP RCF. In February 2018, we voluntarily reduced the aggregate commitments of the lenders under the WGP RCF to $35.0 million. The WGP RCF, which was previously available to be used to buy WES Operating common units and for general partnership purposes, matured in March 2019 and the $28.0 million of outstanding borrowings were repaid.

Revolving credit facility. In December 2018, WES Operating entered into an amendment to the RCF that (i) subject to the consummation of the Merger (see Executive Summary—Merger transactions within this Item 2), increased the size of the RCF from $1.5 billion to $2.0 billion, while leaving the $0.5 billion accordion feature of the RCF unexercised, and (ii) effective on February 15, 2019, exercised one of the one-year extension options to extend the maturity date of the RCF from February 2023 to February 2024.

The RCF is expandable to a maximum of $2.5 billion and bears interest at LIBOR, plus applicable margins ranging from 1.00% to 1.50%, or an alternate base rate equal to the greatest of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.50%, or (c) LIBOR plus 1.00%, in each case plus applicable margins currently ranging from zero to 0.50%, based upon WES Operating’s senior unsecured debt rating. A required quarterly facility fee is paid ranging from 0.125% to 0.250% of the commitment amount (whether used or unused), also based upon the senior unsecured debt rating.

The RCF contains certain covenants that limit, among other things, WES Operating’s ability, and that of certain of its subsidiaries, to incur additional indebtedness, grant certain liens, merge, consolidate or allow any material change in the character of its business, enter into certain affiliate transactions and use proceeds other than for partnership purposes. The RCF also contains various customary covenants, customary events of default and a maximum consolidated leverage ratio as of the end of each fiscal quarter (which is defined as the ratio of consolidated indebtedness as of the last day of a fiscal quarter to Consolidated Earnings Before Interest, Taxes, Depreciation and Amortization for the most recent four consecutive fiscal quarters ending on such day) of 5.0 to 1.0, or a consolidated leverage ratio of 5.5 to 1.0 with respect to quarters ending in the 270-day period immediately following certain acquisitions.

As of ~~March 31,~~June 30, 2019, there was ~~$640.0~~$920.0 million in outstanding borrowings and $4.6 million in outstanding letters of credit, resulting in ~~$1.4~~$1.1 billion available for borrowing under the RCF. At ~~March 31,~~June 30, 2019, the interest rate on the RCF was ~~3.79%~~3.71% and the facility fee rate was 0.20%. At ~~March 31,~~June 30, 2019, WES Operating was in compliance with all covenants under the RCF.

~~364-day Facility.~~Term loan facility.In December 2018, WES Operating entered into a $2.0 billion 364-day senior unsecured credit facility, the proceeds of which were used to fund substantially all of the cash portion of the consideration under the Merger Agreement and the payment of related transaction costs (see Executive Summary—Merger transactions within this Item 2). The ~~364-day Facility will mature in February 2020, and~~Term loan facility bears interest at LIBOR, plus applicable margins ranging from 1.000% to 1.625%, or an alternate base rate equal to the greatest of (a) the Prime Rate, (b) the Federal Funds Effective Rate plus 0.50%, or (c) LIBOR plus 1.00%, in each case as defined in the ~~364-day Facility~~Term loan facility and plus applicable margins currently ranging from zero to 0.625%, based upon WES Operating’s senior unsecured debt rating. Net cash proceeds received from future asset sales and debt or equity offerings must be used to repay amounts outstanding under the facility. The ~~364-day Facility~~Term loan facility contains covenants and customary events of default that are substantially similar to those contained in the RCF.

As of ~~March 31,~~June 30, 2019, there was $2.0 billion in outstanding borrowings under the ~~364-day Facility.~~Term loan facility. As of ~~March 31,~~June 30, 2019, the interest rate on outstanding ~~364-day Facility~~Term loan facility borrowings was ~~3.87%~~3.78% and WES Operating was in compliance with all covenants under the ~~364-day Facility. It is management’s intent to refinance the obligations under the 364-day Facility prior to its maturity in February 2020.~~Term loan facility.

All of WES Operating’s notes and obligations under the RCF and ~~364-day Facility~~Term loan facility are recourse to WES Operating GP. WES Operating GP is indemnified by wholly owned subsidiaries of Anadarko against any claims made against WES Operating GP for WES Operating’s long-term debt and/or borrowings under the RCF and ~~364-day Facility.~~Term loan facility.

APCWH Note Payable. In June 2017, in connection with funding the construction of the APC water systems, which were acquired as part of the AMA acquisition, APCWH entered into an eight-year note payable agreement with Anadarko. This note payable had a maximum borrowing limit of $500.0 million, and accrued interest, which was payable upon maturity, at the applicable mid-term federal rate based on a quarterly compounding basis as determined by the U.S. Secretary of the Treasury. The APCWH Note Payable was repaid upon the consummation of the Merger (see Executive Summary—Merger transactions within this Item 2).

We do not apply hedge accounting and, therefore, gains and losses associated with the interest-rate swaps are recognized currently in earnings. For the three and six months ended ~~March 31,~~June 30, 2019, a non-cash ~~loss~~losses of ~~$35.6~~$59.0 million ~~was~~and $94.6 million, respectively, were recognized, which isare included in Other income (expense), net in the consolidated statements of operations. The fair value of the interest-rate swaps was a liability of ~~$43.6~~$102.6 million and $8.0 million at ~~March 31,~~June 30, 2019, and December 31, 2018, respectively, which is reported in Accrued liabilities on the consolidated balance sheets. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for additional information.

Credit risk. We bear credit risk through exposure to non-payment or non-performance by our counterparties, including Anadarko, 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 or volumes owed pursuant to gas imbalance agreements. We examine and monitor the creditworthiness of third-party customers and may establish credit limits for third-party customers.

We do not, however, maintain a credit limit with respect to Anadarko. Consequently, we are subject to the risk of non-payment or late payment by Anadarko for gathering, processing, transportation and disposal fees and for proceeds from the sale of residue, NGLs and condensate to Anadarko.

We expect our exposure to concentrated risk of non-payment or non-performance to continue for as long as we remain substantially dependent on Anadarko for our revenues. Additionally, we are exposed to credit risk on the note receivable from Anadarko. We are also party to agreements with Anadarko under which Anadarko is required to indemnify us for certain environmental claims, losses arising from rights-of-way claims, failures to obtain required consents or governmental permits and income taxes with respect to the assets acquired from Anadarko. See Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

Our ability to make distributions to our unitholders may be adversely impacted if Anadarko becomes unable to perform under the terms of gathering, processing, transportation and disposal agreements, natural gas and NGLs purchase agreements, Anadarko’s note payable to WES Operating, our and WES Operating’s omnibus agreements, the services and secondment agreement, or the contribution agreements.

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


	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
thousands	2019			2018			2019			2018			2019			2018
Net income (loss) attributable to WES	$	118,660		$	131,527		$	169,594		$	100,184		$	288,254		$	231,711
Limited partner interests in WES Operating not held by WES ⁽¹⁾	91,465			46,498			3,497			(35,828		)	94,962			10,670
General and administrative expenses ⁽²⁾	2,284			832			1,926			696			4,210			1,528
Other income (expense), net	(58		)	(35		)	(5		)	(48		)	(63		)	(83		)
Interest expense	245			1,063			—			308			245			1,371
Net income (loss) attributable to WES Operating	$	212,596		$	179,885		$	175,012		$	65,312		$	387,608		$	245,197

⁽¹⁾

Represents the portion of net income (loss) allocated to the limited partner interests in WES Operating not held by WES. As of ~~March 31,~~June 30, 2019 and 2018, the public held a 0% and ~~59.6%~~59.5% limited partner interest in WES Operating, respectively. Other subsidiaries of Anadarko separately held a 2.0% and ~~9.2%~~9.3% limited partner interest in WES Operating as of ~~March 31,~~June 30, 2019 and 2018, respectively. Immediately prior to the closing of the Merger, the IDRs and the general partner units were converted into a non-economic general partner interest in WES Operating and WES Operating common units, and upon consummation of the Merger, all WES Operating common units held by the public and subsidiaries of Anadarko (other than common units held by WES, WES Operating GP and 6.4 million common units held by a subsidiary of Anadarko) were converted into WES common units. 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.


⁽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:


	Three Months Ended March 31,						Six Months Ended June 30,
thousands	2019			2018			2019			2018
WES net cash provided by operating activities	$	343,073		$	300,151		$	686,531		$	629,326
General and administrative expenses ⁽¹⁾	2,284			832			4,210			1,528
Non-cash equity-based compensation expense	(252		)	(67		)	(611		)	(148		)
Changes in working capital	(1,229		)	(388		)	355			(254		)
Other income (expense), net	(58		)	(35		)	(63		)	(83		)
Interest expense	245			1,063			245			1,371
Debt related amortization and other items, net	(21		)	(725		)	(21		)	(750		)
WES Operating net cash provided by operating activities	$	344,042		$	300,831		$	690,646		$	630,990

WES net cash provided by (used in) financing activities	$	2,180,564		$	668,166		$	2,182,290		$	634,307
Distributions to WES unitholders ⁽²⁾	131,910			120,140			408,234			244,658
Distributions to WES from WES Operating ⁽³⁾	(162,359		)	(122,314		)	(439,963		)	(247,638		)
Registration expenses related to the issuance of WES common units	855			—			855			—
WGP RCF costs	—			8			—			8
WGP RCF repayments	28,000			—			28,000			—
WES Operating net cash provided by (used in) financing activities	$	2,178,970		$	666,000		$	2,179,416		$	631,335


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


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


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

Noncontrolling interest. WES Operating’s noncontrolling interest consists of the 25% interest in Chipeta held by a third-party member (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 for further information).

WES Operating distributions. Prior to the closing of the Merger, WES Operating’s partnership agreement required WES Operating to distribute all of its available cash (as defined in its partnership agreement) to WES Operating unitholders of record on the applicable record date within 45 days of the end of each quarter.

Immediately prior to the closing of the Merger, the IDRs and the general partner units were converted into WES Operating common units, and upon consummation of the Merger, all WES Operating common units held by the public and subsidiaries of Anadarko (other than common units held by WES, WES Operating GP and 6.4 million common units held by a subsidiary of Anadarko) were converted into WES common units. Beginning in the first quarter of 2019, WES Operating ~~will make~~makes distributions to WES and a subsidiary of Anadarko in respect of their proportionate share of limited partner interests in WES Operating. For the ~~three months~~quarter ended March 31, 2019, WES Operating ~~will distribute~~distributed $283.3 million to its limited partners. For the quarter ended June 30, 2019, WES Operating will distribute $288.1 million to its limited partners. See Note 5.

WES Operating LTIP. Concurrently with the closing of the Merger, we assumed the Western Gas Partners, LP 2017 Long-Term Incentive Plan. See Note 6—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for further information.

CONTRACTUAL OBLIGATIONS

Our contractual obligations include, among other things, a revolving credit facility, other third-party long-term debt, capital obligations related to expansion projects and various operating and finance leases. Refer to Note 10—Debt and Interest Expense, Note 12—Commitments and Contingencies and Note 11—Leases in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q for an update to contractual obligations as of ~~March 31,~~June 30, 2019.

OFF-BALANCE SHEET ARRANGEMENTS

We do not have any off-balance sheet arrangements other than short-term operating leases and standby letters of credit. The information pertaining to operating leases and standby letters of credit required for this item is provided under Note 1—Description of Business and Basis of Presentation, Note 11—Leases and Note 10—Debt and Interest Expense, respectively, included in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

RECENT ACCOUNTING DEVELOPMENTS

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.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

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

For the ~~three~~six months ended ~~March 31,~~June 30, 2019, ~~90%~~93% of our wellhead natural gas volumes (excluding equity investments) and 100% of our crude oil and produced water throughput (excluding equity investments) were attributable to fee-based contracts. A 10% increase or decrease in commodity prices would not have a material impact on our operating income (loss), financial condition or cash flows for the next twelve months, excluding the effect of imbalances described below.

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

Interest rate risk. The Federal Open Market Committee raised its target range for the federal funds rate four separate times during 2018. These increases, and any future increases, in the federal funds rate will ultimately result in an increase in financing costs. As of ~~March 31,~~June 30, 2019, we had ~~$640.0~~$920.0 million in outstanding borrowings under the RCF and $2.0 billion in outstanding borrowings under the ~~364-day Facility.~~Term loan facility. The RCF and ~~364-day Facility~~Term loan facility each bear interest at a rate based on LIBOR 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 outstanding borrowings under the RCF and ~~364-day Facility,~~Term loan facility, it would impact the fair value of the Senior Notes at ~~March 31,~~June 30, 2019.

In December 2018 and March 2019, WES Operating entered into interest-rate swap agreements to manage interest rate risk associated with anticipated 2019 debt issuances. At ~~March 31,~~June 30, 2019, we had a net derivative liability position of ~~$43.6~~$102.6 million related to interest-rate swaps. A 10% increase or decrease in the LIBOR interest rate curve would change the aggregate fair value of outstanding interest-rate swap agreements by ~~$32.5~~$28.6 million. However, any change in the interest rate derivative gain or loss could be substantially offset by changes in actual borrowing costs associated with anticipated 2019 debt issuances. See Note 10—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Part I, Item 1 of this Form 10-Q.

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

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures. The Chief Executive Officer and Chief Financial Officer of WES’s general partner and WES Operating GP (for purposes of this Item 4, “Management”) performed an evaluation of WES and WES Operating’s disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Exchange Act. WES 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 and WES Operating’s disclosure controls and procedures were effective as of ~~March 31,~~June 30, 2019.

Changes in Internal Control Over Financial Reporting. There were no changes in WES or WES Operating’s internal control over financial reporting during the quarter ended ~~March 31,~~June 30, 2019, that have materially affected, or are reasonably likely to materially affect, WES or WES Operating’s internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Kerr-McGee Gathering LLC, a wholly owned subsidiary of WES, is currently in negotiations with the U.S. Environmental Protection Agency (the “EPA”) and the ~~Department~~State of ~~Justice~~Colorado with respect to alleged non-compliance with the leak detection and repair requirements of the federal Clean Air Act (“LDAR requirements”) at its Fort Lupton facility in the DJ Basin complex and WGR Operating, LP, another wholly owned subsidiary of WES, is in negotiations with the EPA and the State of Wyoming with respect to alleged non-compliance with LDAR requirements at its Granger, Wyoming facility. Although management cannot predict the outcome of settlement discussions in these matters, management believes that it is reasonably likely a resolution of these matters will result in a fine or penalty for each matter in excess of $100,000.

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.

Item 1A. Risk Factors

Security holders and potential investors in our securities should carefully consider the risk factors included below, as well as those set forth under Part I, Item 1A in our Form 10-K for the year ended December 31, 2018, together with all of the other information included in this document, and in our other public filings, press releases and public discussions with management. Additionally, for a full discussion of the risks associated with Anadarko’s business, see Item 1A under Part I in Anadarko’s Form 10-K for the year ended December 31, 2018, Anadarko’s quarterly reports on Form 10-Q and Anadarko’s other public filings, press releases and public discussions with Anadarko management. We have identified these risk factors as important factors that could cause our actual results to differ materially from those contained in any written or oral forward-looking statements made by us or on our behalf.

Our general partner is owned by Anadarko, which ~~recently~~has announced its entry into the ~~Chevron~~Occidental Merger Agreement. If the ~~Chevron~~Occidental Merger is completed, ~~Chevron~~Occidental will own and control our general partner. ~~Chevron’s~~Occidental’s ownership of our general partner may result in conflicts of interest.

Anadarko ~~recently~~ entered into the ~~Chevron~~Occidental Merger Agreement in May 2019, which provides for a series of transactions whereby Anadarko will be merged with and into an indirect wholly owned subsidiary of ~~Chevron.~~Occidental. Following the completion of the ~~Chevron~~Occidental Merger, the directors and officers of our general partner and its affiliates will have duties to manage our general partner in a manner that is beneficial to ~~Chevron,~~Occidental, who would be the owner of our general partner. At the same time, our general partner will have duties to manage us in a manner that is beneficial to our unitholders. Therefore, following the completion of the ~~Chevron~~Occidental Merger, our general partner’s duties to us may conflict with the duties of its officers and directors to ~~Chevron in the future.~~Occidental. As a result of these conflicts of interest following the ~~Chevron~~Occidental Merger, our general partner may favor its own interest or the interests of ~~Chevron~~Occidental or its owners or affiliates over the interest of our unitholders.

Furthermore, we rely on Anadarko for a substantial portion of the natural gas, crude oil, NGLs and produced water that we gather, treat, process, transport and/or ~~dispose.~~dispose of. Following the completion of the ~~Chevron~~Occidental Merger, our future prospects will depend upon ~~Chevron’s~~Occidental’s growth strategy and drilling program, including the level of drilling and completion activity by ~~Chevron~~Occidental in acreage dedicated to us. Additional conflicts may also arise in the future following the ~~Chevron~~Occidental Merger associated with (1) the allocation of capital and the allocation of costs between ~~Chevron~~Occidental and us, (2) the amount of time devoted by the officers and directors of ~~Chevron~~Occidental to its business in relation to us and (3) future business opportunities that are pursued by ~~Chevron~~Occidental and us.

We will be subject to business uncertainties while the ~~Chevron~~Occidental Merger is pending, which could adversely affect our businesses.

Uncertainty about the effect of the ~~Chevron~~Occidental Merger ~~or a merger with any other company,~~ on employees and customers may have an adverse effect on us. These uncertainties may impair Anadarko’s ability to attract, retain and motivate key personnel involved in our operations until the ~~merger~~Occidental Merger is completed and for a period of time thereafter and could cause customers and others that deal with us to seek to change their existing business relationships with us. Anadarko’s employee retention may be challenging during the pendency of the merger, as employees may experience uncertainty about their future roles. In addition, the ~~Chevron~~Occidental Merger Agreement restricts Anadarko and us from entering into certain corporate transactions, entering into certain material contracts, making certain changes to our capital budget, incurring certain indebtedness and taking other specified actions without the consent of ~~Chevron,~~Occidental, and generally requires us to continue our operations in the ordinary course of business during the pendency of the ~~Chevron~~Occidental Merger. ~~Any alternative merger agreement would likely contain similar restrictions.~~ These restrictions may prevent us from pursuing attractive business opportunities or adjusting our capital plan prior to the completion of ~~a merger transaction by Anadarko.~~the Occidental Merger.

Anadarko may be subject to lawsuits relating to the ~~Chevron~~Occidental Merger, which, because we are substantially dependent on Anadarko as our primary customer and the controlling party of our general partner, could adversely affect our business, financial condition and operating results.

Anadarko, ~~Chevron~~Occidental and/or their respective directors and officers, including certain of Anadarko’s officers that serve as members of our general partner’s Board of Directors, may be subject to lawsuits relating to the ~~Chevron~~Occidental Merger. Such litigation is very common in connection with acquisitions of public companies, regardless of any merits related to the underlying acquisition. While Anadarko will evaluate and defend against any actions vigorously, the costs of the defense of such lawsuits and other effects of such litigation could, because we are substantially dependent on Anadarko as our primary customer and the controlling party of our general partner, have an adverse effect on our business, financial condition and operating results.

Completion of the ~~Chevron~~Occidental Merger is subject to a number of conditions, and if these conditions are not satisfied or waived, the ~~Chevron~~Occidental Merger will not be completed. Failure to complete, or significant delays in completing, the ~~Chevron~~Occidental Merger could negatively affect the trading ~~prices~~price of our common units and our future business and financial results.

Completion of the ~~Chevron~~Occidental Merger is subject to satisfaction or waiver of certain closing conditions, including (1) the adoption of the ~~Chevron~~Occidental Merger Agreement by Anadarko stockholders, (2) the expiration or termination of the waiting period under the Hart-Scott-Rodino Act, as amended, applicable to the ~~Chevron~~Occidental Merger (the U.S. Federal Trade Commission granted early termination of the applicable waiting period on June 3, 2019), (3) the absence of any order or law prohibiting consummation of the ~~Chevron~~Occidental Merger, (4) the effectiveness of the Registration Statement on Form S-4 ~~to be~~(the “Registration Statement”) filed by ~~Chevron~~Occidental pursuant to which the shares of ~~Chevron~~Occidental common stock to be issued in connection with the ~~Chevron~~Occidental Merger will be registered with the SEC (the Registration Statement was declared effective on July 11, 2019) and (5) the authorization for listing on the NYSE of the shares of ~~Chevron~~Occidental common stock to be issued in connection with the ~~Chevron~~Occidental Merger. There can be no assurance that the conditions to the completion of the ~~Chevron~~Occidental Merger will be satisfied or waived or that the ~~Chevron~~Occidental Merger will be completed.

If the ~~Chevron~~Occidental Merger is not completed, or if there are significant delays in completing the ~~Chevron~~Occidental Merger, the trading ~~prices~~price of our common units and our future business and financial results could be negatively affected, and we will be subject to several risks, including the following:

the requirement that Anadarko pay ~~Chevron~~Occidental a termination fee of $1$1.0 billion under certain circumstances provided in the ~~Chevron~~Occidental Merger Agreement;

negative reactions from the financial markets, including declines in the ~~prices~~price of our common units due to the fact that the current ~~prices~~price may reflect a market assumption that the ~~Chevron~~Occidental Merger will be completed;

Anadarko having to pay certain ~~significant~~transaction expenses and other costs relating to the ~~Chevron~~Occidental Merger; and

the attention of Anadarko’s management, including certain of Anadarko’s officers that also serve as our officers or members of our general partner’s Board of Directors, ~~will~~may have been diverted to the ~~Chevron~~Occidental Merger rather than Anadarko’s own operations and pursuit of other opportunities that could have been beneficial to Anadarko and to us.

The ~~Chevron~~Occidental Merger Agreement limits Anadarko’s ability to pursue alternatives to the ~~Chevron~~Occidental Merger.

The ~~Chevron~~Occidental Merger Agreement contains provisions that may discourage a third party from submitting a competing proposal that might result in greater value to Anadarko stockholders, and ultimately to our unitholders, than the ~~Chevron~~Occidental Merger. These provisions include a general prohibition on Anadarko from soliciting or, subject to certain exceptions relating to the exercise of fiduciary duties by its board, entering into discussions with any third party regarding any competing proposal or offer for a competing transaction.

Implementation of new Colorado ~~legislation and further rule making~~Senate Bill 19-181 may increase costs and limit oil and natural gas exploration and production operations in the state, which could have a material adverse effect on our customers in Colorado and significantly reduce demand for our services in the state.

On April 16, 2019, Senate Bill 19-181 was signed into law in Colorado. The new legislation ~~was passed in Colorado that will reform~~reforms oversight of oil and natural gas exploration and production activities ~~by the oil and gas industry~~ in the ~~state including, among other things, revising the~~state. The mission of the Colorado Oil and Gas Conservation Commission (“COGCC”) has changed from fostering energy development in the state, to instead ~~focusing on~~ regulating the industry in a manner that is protective of public health and safety and the ~~environment, as well as authorizing~~environment. The new legislation also authorizes Colorado cities and counties to ~~regulate~~take on an increased role in regulating oil and natural gas operations within their ~~jurisdiction as they do other development. This legislation~~jurisdictions including in a manner that may be more stringent than state-level rules, and a few local governments have passed temporary moratorium on new oil and natural gas projects until the local governments have passed their own rules implementing the new law. The composition of the COGCC commissioners has also been changed under the new law, with the COGCC adding a commissioner with public health expertise. The COGCC is ~~expected~~now tasked with undertaking several reviews of existing regulations and new or amended rulemakings, with priority given to ~~require further rule making,~~implementing the new public health, safety and environmental priorities, cumulative impacts, and local government assistance and interaction. Moreover, the new law requires the Colorado Department of Public Health and Environment’s Air Division to adopt additional air quality rules to minimize emissions from oil and natural gas activities. While the COGCC has already rejected calls for a complete moratorium on new oil and natural gas projects, it issued a set of “Objective Criteria” in May 2019 upon which the COGCC will determine whether a pending permit will be subject to “additional review” to determine compliance with Senate Bill 19-181, pending completion of certain COGCC rulemakings necessary to implement the new law. Timing for issuance of new or amended rules pursuant to Senate Bill 19-181 is currently unknown, with hearings planned in late 2019 and extending into 2020. Implementation of this new law could ~~lead~~limit operations, including due to ~~a possible significant delay~~delays in the state in issuing new drilling permits, ~~while the COGCC codifies the new law. This new law~~ and ~~further related rule making~~result in increased operational costs, which developments could have a material adverse effect on our customers in Colorado, which could significantly reduce demand for our midstream services in the state.

We are exposed to the credit risk of third-party customers, and any material non-payment or non-performance by these parties, including with respect to our gathering, processing, transportation and disposal agreements, could reduce our ability to make distributions to our unitholders.

On some of our systems, we rely on third-party customers for substantially all of our revenues related to those assets. The loss of all or even a portion of the contracted volumes of these customers, as a result of competition, creditworthiness, inability to negotiate extensions, replacements of contracts or otherwise, could reduce our ability to make cash distributions to our unitholders. Further, to the extent any of our third-party customers is in financial distress or enters bankruptcy proceedings, the related customer contracts may be renegotiated at lower rates or rejected altogether. For example, Sanchez Energy Corporation, which is the upstream operator for substantially all of the natural gas, crude oil and NGLs we gather and process in the Eagleford Basin, and which directly represents 9% of our natural gas gathering, treating and transportation volumes, 1% of our crude oil, NGLs and produced water volumes (excluding equity investment volumes), and directly and indirectly 7% of our natural gas processing volumes, has recently elected to defer making an interest payment on its 6.125% Senior Notes due 2023. The indenture governing the 6.125% Senior Notes provides for a 30-day grace period, which expires on August 14, 2019, to make the scheduled interest payment. If Sanchez were to enter bankruptcy, our earnings in the Eagleford Basin could be materially and adversely impacted. Any materially negative impact on such earnings may also result in impairments to the carrying value of our Eagleford assets.

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

The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial interpretation at any time. From time to time, members of Congress have proposed and considered substantive changes to the existing U.S. federal income tax laws that would affect publicly traded partnerships, including elimination of partnership tax treatment for publicly traded partnerships. For example, the “Clean Energy for America Act”, which is similar to legislation that was commonly proposed during the Obama Administration, was introduced in the Senate on May 2, 2019. If enacted, this proposal would, among other things, repeal Section 7704(d)(1)(E) of the Code, upon which we rely for our status as a partnership for U.S. federal income tax purposes.

In addition, the Treasury Department has issued, and in the future may issue, regulations interpreting those laws that affect publicly traded partnerships. There can be no assurance that there will not be further changes to U.S. federal income tax laws or the Treasury Department’s interpretation of the qualifying income rules in a manner that could impact our ability to qualify as a partnership in the future. We believe the income that we treat as qualifying satisfies the requirements under current regulations.

We are unable to predict whether any changes or proposals will ultimately be enacted. Any modification to the U.S. federal income tax laws and interpretations thereof may or may not be retroactively applied and could make it more difficult or impossible for us to meet the exception to be treated as a partnership for U.S. federal income tax purposes and could negatively impact the value of an investment in our common units.

You are urged to consult with your own tax advisor with respect to the status of regulatory or administrative developments and proposals and their potential effect on your investment in our common units.

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

PIK Class C units. During the three months ended March 31, 2019, in connection with the quarterly distribution for the Class C units, WES Operating issued 308,723 additional Class C units to AMH, a subsidiary of Anadarko.

WES Operating common units issued in connection with the Merger. On February 28, 2019, WES, WES Operating, Anadarko and certain of their affiliates consummated the transactions contemplated by the Merger Agreement. Immediately prior to the closing, (i) the Class C units converted into WES Operating common units on a one-for-one basis; (ii) WES Operating and WES Operating GP caused the conversion of the IDRs and the 2,583,068 general partner units in WES Operating held by WES Operating GP into a non-economic general partner interest in WES Operating and 105,624,704 WES Operating common units, and (iii) WES Operating issued 45,760,201 common units to subsidiaries of Anadarko as consideration for AMA.

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 Number	Exhibit Number		Description	Exhibit Number		Description
#	2.	1	Contribution, Conveyance and Assumption Agreement by and among Western Gas Partners, LP, Western Gas Holdings, LLC, Anadarko Petroleum Corporation, WGR Holdings, LLC, Western Gas Resources, Inc., WGR Asset Holding Company LLC, Western Gas Operating, LLC and WGR Operating, LP, dated as of May 14, 2008 (incorporated by reference to Exhibit 10.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 14, 2008, File No. 001-34046).	2.	1	Contribution, Conveyance and Assumption Agreement by and among Western Gas Partners, LP, Western Gas Holdings, LLC, Anadarko Petroleum Corporation, WGR Holdings, LLC, Western Gas Resources, Inc., WGR Asset Holding Company LLC, Western Gas Operating, LLC and WGR Operating, LP, dated as of May 14, 2008 (incorporated by reference to Exhibit 10.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 14, 2008, File No. 001-34046).
#	2.	2	Contribution Agreement, dated as of November 11, 2008, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 10.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on November 13, 2008, File No. 001-34046).	2.	2	Contribution Agreement, dated as of November 11, 2008, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 10.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on November 13, 2008, File No. 001-34046).
#	2.	3	Contribution Agreement, dated as of July 10, 2009, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, Anadarko Uintah Midstream, LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 23, 2009, File No. 001-34046).	2.	3	Contribution Agreement, dated as of July 10, 2009, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, Anadarko Uintah Midstream, LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 23, 2009, File No. 001-34046).
#	2.	4	Contribution Agreement, dated as of January 29, 2010 by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, Mountain Gas Resources LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on February 3, 2010 File No. 001-34046).	2.	4	Contribution Agreement, dated as of January 29, 2010 by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, Mountain Gas Resources LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on February 3, 2010 File No. 001-34046).
#	2.	5	Contribution Agreement, dated as of July 30, 2010, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 5, 2010, File No. 001-34046).	2.	5	Contribution Agreement, dated as of July 30, 2010, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 5, 2010, File No. 001-34046).
#	2.	6	Purchase and Sale Agreement, dated as of January 14, 2011, by and among Western Gas Partners, LP, Kerr-McGee Gathering LLC and Encana Oil & Gas (USA) Inc. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on January 18, 2011 File No. 001-34046).	2.	6	Purchase and Sale Agreement, dated as of January 14, 2011, by and among Western Gas Partners, LP, Kerr-McGee Gathering LLC and Encana Oil & Gas (USA) Inc. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on January 18, 2011 File No. 001-34046).
#	2.	7	Contribution Agreement, dated as of December 15, 2011, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on December 15, 2011, File No. 001-34046).	2.	7	Contribution Agreement, dated as of December 15, 2011, by and among Western Gas Resources, Inc., WGR Asset Holding Company LLC, WGR Holdings, LLC, Western Gas Holdings, LLC, WES GP, Inc., Western Gas Partners, LP, Western Gas Operating, LLC and WGR Operating, LP. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on December 15, 2011, File No. 001-34046).
#	2.	8	Contribution Agreement, dated as of February 27, 2013, by and among Anadarko Marcellus Midstream, L.L.C., Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP, Anadarko Petroleum Corporation and Anadarko E&P Onshore LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 5, 2013, File No. 001-34046).	2.	8	Contribution Agreement, dated as of February 27, 2013, by and among Anadarko Marcellus Midstream, L.L.C., Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP, Anadarko Petroleum Corporation and Anadarko E&P Onshore LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 5, 2013, File No. 001-34046).
#				2.	9	Contribution Agreement, dated as of February 27, 2014, by and among WGR Asset Holding Company LLC, APC Midstream Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.9 to Western Gas Partners, LP’s Annual Report on Form 10-K filed on February 28, 2014, File No. 001-34046).
#				2.	10	Agreement and Plan of Merger, dated October 28, 2014, by and among Western Gas Partners, LP, Maguire Midstream LLC and Nuevo Midstream, LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on October 28, 2014, File No. 001-34046).
#				2.	11	Purchase and Sale Agreement, dated as of March 2, 2015, by and among WGR Asset Holding Company LLC, Delaware Basin Midstream, LLC, Western Gas Partners, LP, and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 3, 2015, File No. 001-34046).
#				2.	12	Amendment No. 1 to Purchase and Sale Agreement, dated as of May 22, 2017, by and between WGR Asset Holding Company LLC and Delaware Basin Midstream, LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 23, 2017, File No. 001-34046).


Exhibit Number	Exhibit Number		Description	Exhibit Number		Description
#	2.	9	Contribution Agreement, dated as of February 27, 2014, by and among WGR Asset Holding Company LLC, APC Midstream Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.9 to Western Gas Partners, LP’s Annual Report on Form 10-K filed on February 28, 2014, File No. 001-34046).
#	2.	10	Agreement and Plan of Merger, dated October 28, 2014, by and among Western Gas Partners, LP, Maguire Midstream LLC and Nuevo Midstream, LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on October 28, 2014, File No. 001-34046).
#	2.	11	Purchase and Sale Agreement, dated as of March 2, 2015, by and among WGR Asset Holding Company LLC, Delaware Basin Midstream, LLC, Western Gas Partners, LP, and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 3, 2015, File No. 001-34046).
#	2.	12	Amendment No. 1 to Purchase and Sale Agreement, dated as of May 22, 2017, by and between WGR Asset Holding Company LLC and Delaware Basin Midstream, LLC (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 23, 2017, File No. 001-34046).
#	2.	13	Contribution Agreement, dated as of February 24, 2016, by and among WGR Asset Holding Company, LLC, APC Midstream Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 1, 2016, File No. 001-34046).	2.	13	Contribution Agreement, dated as of February 24, 2016, by and among WGR Asset Holding Company, LLC, APC Midstream Holdings, LLC, Western Gas Partners, LP, Western Gas Operating, LLC, WGR Operating, LP and Anadarko Petroleum Corporation (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 1, 2016, File No. 001-34046).
#	2.	14	Interest Swap and Purchase Agreement, dated February 9, 2017, among Western Gas Partners, LP, WGR Operating, LP, Delaware Basin JV Gathering, LLC, Williams Partners L.P., Williams Midstream Gas Services LLC and Appalachia Midstream Services, L.L.C. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on February 9, 2017, File No. 001-34046).	2.	14	Interest Swap and Purchase Agreement, dated February 9, 2017, among Western Gas Partners, LP, WGR Operating, LP, Delaware Basin JV Gathering, LLC, Williams Partners L.P., Williams Midstream Gas Services LLC and Appalachia Midstream Services, L.L.C. (incorporated by reference to Exhibit 2.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on February 9, 2017, File No. 001-34046).
#	2.	15	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).	2.	15	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.	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.	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	First Amended and Restated Agreement of Limited Partnership of Western Gas Equity Partners, LP, dated as of December 12, 2012 (incorporated by reference to Exhibit 3.1 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on December 12, 2012, File No. 001-35753).	3.	3	First Amended and Restated Agreement of Limited Partnership of Western Gas Equity Partners, LP, dated as of December 12, 2012 (incorporated by reference to Exhibit 3.1 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on December 12, 2012, File No. 001-35753).
	3.	4	Amendment No. 1 to First Amended and Restated Agreement of Limited Partnership of Western Gas Equity Partners, LP, dated November 9, 2017 (incorporated by reference to Exhibit 3.1 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on November 9, 2017, File No. 001-35753).	3.	4	Amendment No. 1 to First Amended and Restated Agreement of Limited Partnership of Western Gas Equity Partners, LP, dated November 9, 2017 (incorporated by reference to Exhibit 3.1 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on November 9, 2017, File No. 001-35753).
	3.	5	Amendment No. 2 to the First Amended and Restated Agreement of Limited Partnership of Western Midstream Partners, LP, dated as of February 28, 2019 (incorporated by reference to Exhibit 3.6 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).	3.	5	Amendment No. 2 to the First Amended and Restated Agreement of Limited Partnership of Western Midstream Partners, LP, dated as of February 28, 2019 (incorporated by reference to Exhibit 3.6 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
	3.	6	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.	6	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.	7	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.	7	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.	8	Amended and Restated Limited Liability Company Agreement of Western Gas Equity Holdings, LLC, dated as of December 12, 2012 (incorporated by reference to Exhibit 3.2 to Western Gas Equity Partners, LP’s Current Report on Form 8-K filed on December 12, 2012, File No. 001-35753).	3.	8	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.	9	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.	9	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.	10	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.	11	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.	12	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.	13	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).

Exhibit
Number Description
3. 10
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. 11
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. 12
Second Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated March 14, 2016 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 16, 2016, File No. 001-34046).
3. 13
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. 14
Amendment No. 1 to Second Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated March 14, 2016 (incorporated by reference to Exhibit 3.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 16, 2016, File No. 001-34046).
3. 15
Amendment No. 2 to Second Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated February 22, 2017 (incorporated by reference to Exhibit 3.4 to Western Gas Partners, LP’s Annual Report on Form 10-K filed on February 23, 2017, File No. 001-34046).
3. 16
Amendment No. 3 to Second Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated November 9, 2017 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on November 9, 2017, File No. 001-34046).
3. 17
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. 18
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. 19
Second Amended and Restated Limited Liability Company Agreement of Western Gas Holdings, LLC, dated December 12, 2012 (incorporated by reference to Exhibit 3.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on December 12, 2012, File No. 001-34046).
3. 20
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. 21
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).
4. 1
Specimen Unit Certificate for the Common Units (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Quarterly Report on Form 10-Q filed on June 13, 2008, File No. 001-34046).
4. 2
Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 3
First Supplemental Indenture, dated as of May 18, 2011, among Western Gas Partners, LP, as Issuer, the Subsidiary Guarantors named therein, as Guarantors, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 4
Form of 5.375% Senior Notes due 2021 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A to Exhibit 4.2, to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4. 5
Fourth Supplemental Indenture, dated as of June 28, 2012, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).
4. 6
Form of 4.000% Senior Notes due 2022 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 28, 2012, File No. 001-34046).



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

Exhibit
Number Description
4. 7
Sixth Supplemental Indenture, dated as of March 20, 2014, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
4. 8
Form of 5.450% Senior Notes due 2044 (incorporated by reference to Exhibit 4.4, which is included as Exhibit A to Exhibit 4.2, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 20, 2014, File No. 001-34046).
4. 9
Seventh Supplemental Indenture, dated as of June 4, 2015, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
4. 10
Form of 3.950% Senior Notes due 2025 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on June 4, 2015, File No. 001-34046).
4. 11
Eighth Supplemental Indenture, dated as of July 12, 2016, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
4. 12
Form of 4.650% Senior Notes due 2026 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 12, 2016, File No. 001-34046).
4. 13
Ninth Supplemental Indenture, dated as of March 2, 2018, among Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 14
Form of 4.500% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 15
Form of 5.300% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 2, 2018, File No. 001-34046).
4. 16
Tenth Supplemental Indenture, dated as of August 9, 2018, by and between Western Gas Partners, LP, as Issuer, and Wells Fargo Bank, National Association, as Trustee (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 9, 2018, File No. 001-34046).
4. 17
Form of 4.750% Senior Notes due 2028 (incorporated by reference to Exhibit 4.2, which is included as Exhibit A-1 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K file on August 9, 2018, File No. 001-34046).
4. 18
Form of 5.500% Senior Notes due 2048 (incorporated by reference to Exhibit 4.3, which is included as Exhibit A-2 to Exhibit 4.1, to Western Gas Partners, LP’s Current Report on Form 8-K file on August 9, 2018, File No. 001-34046).
10. 1
WGRAH Indemnification Agreement, dated as of February 28, 2019, by and between WGR Asset Holding Company LLC and Western Gas Holdings, LLC (incorporated by reference to Exhibit 10.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on February 28, 2019, File No. 001-35753).
* 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. 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.
** 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.

Exhibit
Number

Description

Exhibit
Number

Description

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 file on August 9, 2018, File No. 001-34046).

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 file on August 9, 2018, File No. 001-34046).

10.

First Amendment to 364-Day Credit Agreement, dated as of July 1, 2019, among Western Midstream Operating, LP, as the Borrower, Barclays Bank PLC, as Administrative Agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to Western Midstream Partners, LP’s Current Report on Form 8-K filed on July 3, 2019, File No. 001-35753).

31.

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

31.

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

31.

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

31.

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

32.

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

32.

101.

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XBRL Calculation Linkbase Document

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#	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.

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

~~May 1,~~July 31, 2019
	/s/ Robin H. Fielder
	Robin H. Fielder President and Chief Executive Officer Western Midstream Holdings, LLC (as general partner of Western Midstream Partners, LP)

~~May 1,~~July 31, 2019
	/s/ Jaime R. Casas
	Jaime R. Casas Senior Vice President, Chief Financial Officer and Treasurer Western Midstream Holdings, LLC (as general partner of Western Midstream Partners, LP)


	WESTERN MIDSTREAM OPERATING, LP

~~May 1,~~July 31, 2019
	/s/ Robin H. Fielder
	Robin H. Fielder President and Chief Executive Officer Western Midstream Operating GP, LLC (as general partner of Western Midstream Operating, LP)

~~May 1,~~July 31, 2019
	/s/ Jaime R. Casas
	Jaime R. Casas Senior Vice President, Chief Financial Officer and Treasurer Western Midstream Operating GP, LLC (as general partner of Western Midstream Operating, LP)

7580



thousands
Remainder of 2019	$	532,477
2020	862,428
2021	911,450
2022	976,136
2023	932,921
Thereafter	4,500,175
Total	$	8,715,587



thousands
Remainder of 2019	$	5,588
2020	2,215
2021	612
2022	618
2023	625
Thereafter	1,658
Total lease payments	11,316
Less portion representing imputed interest	413
Total lease liabilities	$	10,903