WES 10-Q Quarterly Report Sept. 30, 2013

WES 10-Q Quarter ended Sept. 30, 2013

WESTERN MIDSTREAM PARTNERS, LP

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10-Q 1 wgp09301310q.htm FORM 10-Q WGP 09.30.13 10Q

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


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

For the quarterly period ended September 30, 2013


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

For the transition period from to

Commission file number: 001-35753

WESTERN GAS EQUITY PARTNERS, LP

(Exact name of registrant as specified in its charter)



Delaware		46-0967367
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1201 Lake Robbins Drive The Woodlands, Texas		77380 (Zip Code)
(Address of principal executive offices)

(832) 636-6000

(Registrant’s telephone number, including area code)

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. Yes þ No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes þ No ¨

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

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

There were 218,895,515 common units outstanding as of November 4, 2013 .

Table of Contents

TABLE OF CONTENTS



PART I		FINANCIAL INFORMATION	PAGE

	Item 1.	Financial Statements

		Consolidated Statements of Income for the three and nine months ended September 30, 2013 and 2012	4

		Consolidated Balance Sheets as of September 30, 2013, and December 31, 2012	5

		Consolidated Statement of Equity and Partners’ Capital for the nine months ended September 30, 2013	6

		Consolidated Statements of Cash Flows for the nine months ended September 30, 2013 and 2012	7

		Notes to Consolidated Financial Statements	8

	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25

		Cautionary Note Regarding Forward-Looking Statements	25

		Executive Summary	27

		Acquisitions	29

		Equity Offerings	30

		Items Affecting the Comparability of Our Financial Results to Those of WES	31

		Results of Operations	34

		Operating Results	34

		Key Performance Metrics	42

		Liquidity and Capital Resources	45

		Contractual Obligations	51

		Off-Balance Sheet Arrangements	51

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	51

	Item 4.	Controls and Procedures	52

PART II		OTHER INFORMATION

	Item 1.	Legal Proceedings	53

	Item 1A.	Risk Factors	53

	Item 6.	Exhibits	54

Table of Contents

DEFINITIONS

As generally used within the energy industry and in this quarterly report on Form 10-Q, the identified terms have the following meanings:

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

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

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, such as liquid nitrogen or liquid helium, are used to bring 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.

Drip condensate: Heavier hydrocarbon liquids that fall out of the natural gas stream and are recovered in the gathering system without processing.

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.

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

MBbls/d: One thousand barrels per day.

MMBtu: One million British thermal units.

MMcf/d: One million cubic feet per day.

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.

Residue: The natural gas remaining after being processed or treated.

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

WESTERN GAS EQUITY PARTNERS, LP

CONSOLIDATED STATEMENTS OF INCOME

(UNAUDITED)



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except unit and per-unit amounts	2013			2012 ⁽¹⁾			2013			2012 ⁽¹⁾
Revenues – affiliates
Gathering, processing and transportation of natural gas and natural gas liquids	$	83,606		$	61,388		$	218,680		$	182,448
Natural gas, natural gas liquids and condensate sales	129,411			115,132			371,077			324,793
Equity income and other, net	4,607			4,085			13,457			12,219
Total revenues – affiliates	217,624			180,605			603,214			519,460
Revenues – third parties
Gathering, processing and transportation of natural gas and natural gas liquids	47,175			32,545			124,791			96,518
Natural gas, natural gas liquids and condensate sales	11,915			20,974			31,539			62,025
Other, net	1,287			610			3,330			1,717
Total revenues – third parties	60,377			54,129			159,660			160,260
Total revenues	278,001			234,734			762,874			679,720
Operating expenses
Cost of product ⁽²⁾	93,516			89,107			270,059			254,719
Operation and maintenance ⁽²⁾	42,757			35,493			121,165			103,304
General and administrative ⁽²⁾	7,962			15,039			25,100			35,623
Property and other taxes	6,649			5,328			18,520			14,998
Depreciation, amortization and impairments	37,615			28,455			106,551			83,263
Total operating expenses	188,499			173,422			541,395			491,907
Operating income	89,502			61,312			221,479			187,813
Interest income, net – affiliates	4,225			4,225			12,675			12,675
Interest expense ⁽³⁾	(13,018		)	(10,977		)	(37,483		)	(30,118		)
Other income (expense), net	466			522			1,686			(287		)
Income before income taxes	81,175			55,082			198,357			170,083
Income tax expense	58			14,166			4,431			43,790
Net income	81,117			40,916			193,926			126,293
Net income attributable to noncontrolling interests	36,779			21,605			82,562			71,258
Net income attributable to Western Gas Equity Partners, LP	$	44,338		$	19,311		$	111,364		$	55,035
Limited partners’ interest in net income:
Net income attributable to Western Gas Equity Partners, LP	$	44,338					$	111,364
Pre-acquisition net (income) loss allocated to Anadarko	—						(4,637		)
Limited partners’ interest in net income ⁽⁴⁾	$	44,338					$	106,727
Net income per common unit – basic and diluted	$	0.20					$	0.49
Weighted average common units outstanding – basic and diluted	218,896						218,896


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to the Non-Operated Marcellus Interest. See Note 2 .

⁽²⁾

Cost of product includes product purchases from Anadarko (as defined in Note 1 ) of $33.8 million and $97.8 million for the three and nine months ended September 30, 2013 , respectively, and $42.8 million and $115.6 million for the three and nine months ended September 30, 2012 , respectively. Operation and maintenance includes charges from Anadarko of $13.5 million and $41.0 million for the three and nine months ended September 30, 2013 , respectively, and $12.6 million and $38.0 million for the three and nine months ended September 30, 2012 , respectively. General and administrative includes charges from Anadarko of $6.1 million and $18.0 million for the three and nine months ended September 30, 2013 , respectively, and $14.2 million and $30.8 million for the three and nine months ended September 30, 2012 , respectively. See Note 5 .


⁽³⁾	Includes affiliate (as defined in Note 1 ) interest expense of zero for the three and nine months ended September 30, 2013 , and $0.1 million and $2.7 million for the three and nine months ended September 30, 2012 , respectively. See Note 8 .


⁽⁴⁾	Represents net income for periods including and subsequent to the acquisition of WES assets (as defined in Note 1 ). See Note 4 .

See accompanying Notes to Consolidated Financial Statements.

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WESTERN GAS EQUITY PARTNERS, LP

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)



thousands except number of units	September 30, 2013		December 31, 2012 ⁽¹⁾
ASSETS
Current assets
Cash and cash equivalents	$	57,083	$	422,556
Accounts receivable, net ⁽²⁾	75,695		48,550
Other current assets ⁽³⁾	8,912		6,998
Total current assets	141,690		478,104
Note receivable – Anadarko	260,000		260,000
Property, plant and equipment
Cost	4,061,389		3,432,392
Less accumulated depreciation	817,489		714,436
Net property, plant and equipment	3,243,900		2,717,956
Goodwill	105,336		105,336
Other intangible assets	54,436		55,490
Equity investments	227,566		106,130
Other assets	28,078		27,798
Total assets	$	4,061,006	$	3,750,814
LIABILITIES, EQUITY AND PARTNERS’ CAPITAL
Current liabilities
Accounts and natural gas imbalance payables ⁽⁴⁾	$	19,131	$	25,154
Accrued ad valorem taxes	18,472		11,949
Income taxes payable	190		552
Accrued liabilities ⁽⁵⁾	140,323		148,600
Total current liabilities	178,116		186,255
Long-term debt – third parties	1,518,110		1,168,278
Deferred income taxes	1,830		47,153
Asset retirement obligations and other	76,336		68,749
Total long-term liabilities	1,596,276		1,284,180
Total liabilities	1,774,392		1,470,435
Equity and partners’ capital
Common units (218,895,515 units issued and outstanding at September 30, 2013, and December 31, 2012)	825,074		912,376
Net investment by Anadarko	—		199,960
Total partners’ capital	825,074		1,112,336
Noncontrolling interests	1,461,540		1,168,043
Total equity and partners’ capital	2,286,614		2,280,379
Total liabilities, equity and partners’ capital	$	4,061,006	$	3,750,814


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to the Non-Operated Marcellus Interest. See Note 2 .


⁽²⁾	Accounts receivable, net includes amounts receivable from affiliates (as defined in Note 1 ) of $40.0 million and $17.5 million as of September 30, 2013 , and December 31, 2012 , respectively.


⁽³⁾	Other current assets includes natural gas imbalance receivables from affiliates of $0.1 million and $0.4 million as of September 30, 2013 , and December 31, 2012 , respectively.


⁽⁴⁾	Accounts and natural gas imbalance payables includes amounts payable to affiliates of $2.8 million and $2.5 million as of September 30, 2013 , and December 31, 2012 , respectively.


⁽⁵⁾	Accrued liabilities include amounts payable to affiliates of $0.1 million as of September 30, 2013 and December 31, 2012 .

See accompanying Notes to Consolidated Financial Statements.

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WESTERN GAS EQUITY PARTNERS, LP

CONSOLIDATED STATEMENT OF EQUITY AND PARTNERS’ CAPITAL

(UNAUDITED)



	Partners’ Capital
thousands	Net Investment by Anadarko			Common Units			Noncontrolling Interests			Total
Balance at December 31, 2012 ⁽¹⁾	$	199,960		$	912,376		$	1,168,043		$	2,280,379
Net income	4,637			106,727			82,562			193,926
WES equity transactions, net ⁽²⁾	—			108,077			310,440			418,517
Contributions received from Chipeta noncontrolling interest owners	—			—			2,247			2,247
Distributions to Chipeta noncontrolling interest owners	—			—			(8,001		)	(8,001		)
Distributions to WES common unitholders	—			—			(94,117		)	(94,117		)
Distributions to WGP unitholders	—			(90,211		)	—			(90,211		)
Acquisitions from affiliates	(255,635		)	(209,865		)	—			(465,500		)
Contributions of equity-based compensation from Anadarko	—			2,093			58			2,151
Net pre-acquisition contributions from (distributions to) Anadarko	4,508			—			—			4,508
Net distributions of other assets to Anadarko	—			(4,080		)	—			(4,080		)
Elimination of net deferred tax liabilities	46,530			—			—			46,530
Other	—			(43		)	308			265
Balance at September 30, 2013	$	—		$	825,074		$	1,461,540		$	2,286,614


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to the Non-Operated Marcellus Interest. See Note 2 .

⁽²⁾

Includes the impact of Western Gas Partners, LP’s equity offerings as described in Note 4 and common units issued in connection with the acquisition of the Non-Operated Marcellus Interest as described in Note 2 . The $108.1 million increase to partners’ capital, together with net income attributable to Western Gas Equity Partners, LP, totaled $219.4 million for the nine months ended September 30, 2013 .

See accompanying Notes to Consolidated Financial Statements.

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WESTERN GAS EQUITY PARTNERS, LP

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)



	Nine Months Ended September 30,
thousands	2013			2012 ⁽¹⁾
Cash flows from operating activities
Net income	$	193,926		$	126,293
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and impairments	106,551			83,263
Non-cash equity-based compensation expense	2,783			2,769
Deferred income taxes	1,207			(11,275		)
Debt-related amortization and other items, net	1,756			1,728
Changes in assets and liabilities:
(Increase) decrease in accounts receivable, net	(27,539		)	47,272
Increase (decrease) in accounts and natural gas imbalance payables and accrued liabilities, net	6,700			29,272
Change in other items, net	687			2,234
Net cash provided by operating activities	286,071			281,556
Cash flows from investing activities
Capital expenditures	(469,678		)	(403,949		)
Acquisitions from affiliates	(469,884		)	(605,960		)
Acquisitions from third parties	(240,274		)	—
Investments in equity affiliates	(45,126		)	(147		)
Proceeds from the sale of assets to affiliates	82			760
Other	(1,524		)	—
Net cash used in investing activities	(1,226,404		)	(1,009,296		)
Cash flows from financing activities
Borrowings, net of debt issuance costs	842,566			885,291
Repayments of debt	(495,000		)	(549,000		)
Increase (decrease) in outstanding checks	(3,335		)	2,534
Offering expenses from the issuance of WGP common units	(2,367		)	—
Proceeds from the issuance of WES common units, net of offering expenses	418,570			211,965
Distributions to WGP unitholders	(90,211		)	—
Contributions received from Chipeta noncontrolling interest owners (including Anadarko)	2,247			26,888
Distributions to Chipeta noncontrolling interest owners (including Anadarko)	(8,001		)	(14,303		)
Distributions to WES common unitholders	(94,117		)	(71,890		)
Net contributions from (distributions to) Anadarko	4,508			57,190
Net cash provided by financing activities	574,860			548,675
Net increase (decrease) in cash and cash equivalents	(365,473		)	(179,065		)
Cash and cash equivalents at beginning of period	422,556			226,559
Cash and cash equivalents at end of period	$	57,083		$	47,494

Supplemental disclosures
Net distributions to (contributions from) Anadarko of other assets	$	4,080		$	10,790
Interest paid, net of capitalized interest	$	34,974		$	16,460
Taxes paid	$	—		$	495


⁽¹⁾	Financial information has been recast to include the financial position and results attributable to the Non-Operated Marcellus Interest. See Note 2 .

See accompanying Notes to Consolidated Financial Statements.

Table of Contents

WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1. DESCRIPTION OF BUSINESS AND BASIS OF PRESENTATION

General. Western Gas Equity Partners, LP is a Delaware master limited partnership formed in September 2012 to own partnership interests in Western Gas Partners, LP, a publicly traded partnership. Western Gas Equity Partners, LP was formed by converting WGR Holdings, LLC into a limited partnership and changing its name. Western Gas Partners, LP (together with its subsidiaries, “WES”) is a Delaware master limited partnership formed by Anadarko Petroleum Corporation in 2007 to own, operate, acquire and develop midstream energy assets.

For purposes of these consolidated financial statements, “WGP” refers to Western Gas Equity Partners, LP in its individual capacity or to Western Gas Equity Partners, LP and its subsidiaries, including Western Gas Holdings, LLC and WES, as the context requires. “WES GP” refers to Western Gas Holdings, LLC, individually as the general partner of WES, and excludes WES itself. WGP’s general partner, Western Gas Equity Holdings, LLC (“WGP GP”), is a wholly owned subsidiary of Anadarko Petroleum Corporation. “Anadarko” refers to Anadarko Petroleum Corporation and its consolidated subsidiaries, excluding WGP and WGP GP. “WGP and Affiliates” refers to subsidiaries of Anadarko, including WGP in its individual capacity, and “affiliates” refers to subsidiaries of Anadarko, excluding WGP and its consolidated subsidiaries, and includes the interests in Fort Union Gas Gathering, LLC (“Fort Union”), White Cliffs Pipeline, LLC (“White Cliffs”), Rendezvous Gas Services, LLC (“Rendezvous”), and a joint venture, Enterprise EF78 LLC (“Mont Belvieu JV”). See Note 2 . “Equity investment throughput” refers to WES’s 14.81% share of Fort Union and 22% share of Rendezvous gross volumes.

WGP owns the following types of partnership interests in WES: (i) the 2.0% general partner interest in WES, held through a wholly owned subsidiary, WES GP; (ii) 100% of the incentive distribution rights (“IDRs”) in WES, held through WES GP, which entitle WGP to receive increasing percentages, up to the maximum level of 48.0% , of any incremental cash distributed by WES as certain target distribution levels are reached in any quarter; and (iii) a significant limited partner interest in WES. WES GP’s 2.0% general partner interest in WES constitutes substantially all of WES GP’s business, which primarily is to manage the affairs and operations of WES. Refer to Note 4 for a discussion of WGP’s holdings of WES equity.

In December 2012, WGP completed its initial public offering (“IPO”) of 19,758,150 common units representing limited partner interests at a price of $22.00 per common unit, generating net proceeds of $412.0 million . WGP used approximately $409.4 million of the net proceeds from its IPO to purchase common and general partner units of WES.

WES is engaged in the business of gathering, processing, compressing, treating and transporting natural gas, condensate, NGLs and crude oil for Anadarko, as well as third-party producers and customers. As of September 30, 2013 , WES’s assets, exclusive of interests in Fort Union, White Cliffs, Rendezvous and the Mont Belvieu JV accounted for under the equity method, consisted of the following:



	Owned and Operated	Operated Interests	Non-Operated Interests
Natural gas gathering systems	13	1	5
Natural gas treating facilities	8	—	—
Natural gas processing facilities	8	3	—
NGL pipelines	3	—	—
Natural gas pipelines	3	—	—

These assets are located in South, East and West Texas, the Rocky Mountains (Colorado, Utah and Wyoming), north-central Pennsylvania, and the Mid-Continent (Kansas and Oklahoma). WES was also constructing the Lancaster processing facility in Northeast Colorado at the end of the third quarter of 2013 .

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

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

Basis of presentation. 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 WGP and entities in which it holds a controlling financial interest, including WES and WES GP. All significant intercompany transactions have been eliminated. Investments in noncontrolled entities over which WES, or WGP through its investment in WES, exercises significant influence are accounted for under the equity method. WGP proportionately consolidates WES’s 33.75% share of the assets, liabilities, revenues and expenses attributable to the Non-Operated Marcellus Interest and Anadarko-Operated Marcellus Interest (see Note 2 ) and WES’s 50% share of the assets, liabilities, revenues and expenses attributable to the Newcastle system in the accompanying consolidated financial statements.

The consolidated financial results of WES are included in WGP’s consolidated financial statements due to WGP’s 100% ownership interest in WES GP and WES GP’s control of WES. Throughout these notes to the consolidated financial statements, and to the extent material, any differences between the consolidated financial results of WGP and WES are discussed separately. WGP has no independent operations or material assets other than its partnership interests in WES. WGP’s consolidated financial statements differ from those of WES primarily as a result of (i) the presentation of noncontrolling interest ownership (attributable to the limited partner interests in WES held by the public and Anadarko Marcellus Midstream, L.L.C. (“AMM”) (see Note 2 )), (ii) the elimination of WES GP’s investment in WES with WES GP’s underlying capital account, (iii) income tax expense and liabilities incurred by WGR Holdings, LLC, computed on a separate-return basis prior to its conversion into a limited partnership, and (iv) the general and administrative expenses incurred by WGP, which are separate from, and in addition to, those incurred by WES.

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, utilizing historical experience and other methods considered reasonable under the particular circumstances. 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 furnished 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.

For the nine months ended September 30, 2012 , operating cash inflows and investing cash outflows in the unaudited consolidated statements of cash flows include a reduction of $35.7 million attributable to the correction of an error discovered during analysis of accounts payable balances. This analysis revealed that certain 2012 invoices received, but not yet paid, were properly attributable to WES’s ongoing capital projects rather than to operating expenses. Management concluded that this misstatement was not material relative to the nine months ended September 30, 2012 , and has corrected the error within the unaudited statement of cash flows for the nine months ended September 30, 2012 , as included in this report.

Certain information and note disclosures commonly included in annual financial statements have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, the accompanying consolidated financial statements and notes should be read in conjunction with WGP’s 2012 Form 10-K, as filed with the SEC on March 28, 2013. Management believes that the disclosures made are adequate to make the information not misleading.

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

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

Noncontrolling interests. The interests in Chipeta Processing LLC (“Chipeta”) held by a third-party member, and the limited partner interests in WES held by AMM and the public, are reflected as noncontrolling interests in the consolidated financial statements for all periods presented.

Chipeta . In July 2009, WES acquired a 51% interest in Chipeta and became party to Chipeta’s limited liability company agreement. On August 1, 2012, WES acquired Anadarko’s then remaining 24% membership interest in Chipeta (the “additional Chipeta interest”). Prior to this transaction, the interests in Chipeta held by Anadarko and a third-party member were reflected as noncontrolling interests in the consolidated financial statements. The acquisition of Anadarko’s then remaining 24% interest was accounted for on a prospective basis as WES acquired an additional interest in an already-consolidated entity. As such, effective August 1, 2012, noncontrolling interest excludes the financial results and operations of the additional Chipeta interest. The remaining 25% membership interest held by the third-party member is reflected within noncontrolling interests in the consolidated financial statements for all periods presented. See Note 2 .

WES . The publicly held limited partner interests in WES are reflected as noncontrolling interests in the consolidated financial statements for all periods presented. In addition, in March 2013, WES acquired a 33.75% interest in both the Liberty and Rome gas gathering systems from AMM, a wholly owned subsidiary of Anadarko. As part of the consideration paid, WES issued 449,129 WES common units to AMM. The limited partner interest in WES held by AMM is reflected within noncontrolling interests in the consolidated financial statements as of and for the three and nine months ended September 30, 2013 . See Note 2 .

Presentation of WES assets. References to “WES assets” refer collectively to the assets indirectly owned by WGP, through its partnership interests in WES, as of September 30, 2013 . Because Anadarko controls WES through its ownership and control of WGP, which owns WES GP, each of WES’s acquisitions of assets from Anadarko has been considered a transfer of net assets between entities under common control. As such, WES assets acquired from Anadarko were initially recorded at Anadarko’s historic carrying value, which did not correlate to the total acquisition price paid by WES. Further, after an acquisition of assets from Anadarko, WES and WGP (by virtue of its consolidation of WES) may be required to recast their financial statements to include the activities of such assets as of the date of common control. See Note 2 .

For those periods requiring recast, the consolidated financial statements for periods prior to the acquisition of WES assets from Anadarko, including the Non-Operated Marcellus Interest, 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 WES had owned the assets during the periods reported. Net income attributable to WES assets for periods prior to WES’s acquisition of such assets is not allocated to the limited partners for purposes of calculating net income per common unit.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. ACQUISITIONS

The following table presents the acquisitions completed by WES during 2012 and 2013 , and identifies the funding sources for such acquisitions:



thousands except unit and percent amounts	Acquisition Date	Percentage Acquired		Borrowings		Cash On Hand		WES Common Units Issued	WES GP Units Issued
MGR ⁽¹⁾	01/13/2012	100	%	$	299,000	$	159,587	632,783	12,914
Chipeta ⁽²⁾	08/01/2012	24	%	—		128,250		151,235	3,086
Non-Operated Marcellus Interest ⁽³⁾	03/01/2013	33.75	%	250,000		215,500		449,129	—
Anadarko-Operated Marcellus Interest ⁽⁴⁾	03/08/2013	33.75	%	133,500		—		—	—
Mont Belvieu JV ⁽⁵⁾	06/05/2013	25	%	—		78,129		—	—
OTTCO ⁽⁶⁾	09/03/2013	100	%	27,500		—		—	—

⁽¹⁾

The assets acquired from Anadarko consist of (i) the Red Desert complex, which is located in the greater Green River Basin in southwestern Wyoming, and includes the Patrick Draw processing plant, the Red Desert processing plant, gathering lines, and related facilities, (ii) a 22% interest in Rendezvous, which owns a gathering system serving the Jonah and Pinedale Anticline fields in southwestern Wyoming, and (iii) certain additional midstream assets and equipment. These assets are collectively referred to as the “MGR assets” and the acquisition as the “MGR acquisition.”

⁽²⁾

WES acquired Anadarko’s then remaining 24% membership interest in Chipeta (as described in Note 1 ). WES received distributions related to the additional interest beginning July 1, 2012. This transaction brought WES’s total membership interest in Chipeta to 75% . The remaining 25% membership interest in Chipeta held by a third-party member is reflected as noncontrolling interests in the consolidated financial statements for all periods presented.

⁽³⁾

WES acquired Anadarko’s 33.75% interest (non-operated) in the Liberty and Rome gas gathering systems, serving production from the Marcellus shale in north-central Pennsylvania. The interest acquired is referred to as the “Non-Operated Marcellus Interest” and the acquisition as the “Non-Operated Marcellus Interest acquisition.” In connection with the issuance of WES common units, WES GP purchased 9,166 general partner units for consideration of $0.5 million in order to maintain its 2.0% general partner interest in WES. See Non-Operated Marcellus Interest acquisition below for further information.

⁽⁴⁾

The interest acquired from a third party consisted of a 33.75% interest in each of the Larry’s Creek, Seely and Warrensville gas gathering systems, which are operated by Anadarko and serve production from the Marcellus shale in north-central Pennsylvania. The interest acquired is referred to as the “Anadarko-Operated Marcellus Interest” and the acquisition as the “Anadarko-Operated Marcellus Interest acquisition.” See Anadarko-Operated Marcellus Interest acquisition below for further information, including the final allocation of the purchase price as of September 30, 2013 .

⁽⁵⁾

The acquisition from a third party consisted of a 25% interest in Enterprise EF78 LLC, an entity formed to design, construct, and own two fractionators located in Mont Belvieu, Texas. The interest acquired is accounted for under the equity method of accounting and is referred to as the “Mont Belvieu JV” and the acquisition as the “Mont Belvieu JV acquisition.” See Mont Belvieu JV acquisition below for further information.


⁽⁶⁾	WES acquired Overland Trail Transmission, LLC (“OTTCO”), a Delaware limited liability company, from a third party. OTTCO owns and operates an intrastate pipeline which connects WES’s Red Desert and Granger complexes in southwestern Wyoming. The assets acquired are referred to as the “OTTCO pipeline” and the acquisition as the “OTTCO acquisition.”

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. ACQUISITIONS (CONTINUED)

Non-Operated Marcellus Interest acquisition . Because the Non-Operated Marcellus Interest acquisition was a transfer of net assets between entities under common control, WGP’s historical financial statements previously filed with the SEC have been recast in this Form 10-Q to include the results attributable to the Non-Operated Marcellus Interest as if WES owned such assets for all periods presented. The consolidated financial statements for periods prior to WES’s acquisition of WES assets from Anadarko, including the Non-Operated Marcellus Interest, 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 WES had owned the assets during the periods reported.

The following table presents the revenue and net income impact of the Non-Operated Marcellus Interest on revenue and net income as presented in the historical consolidated statements of income:



	Three Months Ended September 30, 2012
thousands	WGP Historical		Non-Operated Marcellus Interest		Combined
Revenues	$	219,020	$	15,714	$	234,734
Net income	33,854		7,062		40,916



	Nine Months Ended September 30, 2012
thousands	WGP Historical		Non-Operated Marcellus Interest		Combined
Revenues	$	636,603	$	43,117	$	679,720
Net income	106,711		19,582		126,293

Anadarko-Operated Marcellus Interest acquisition . The Anadarko-Operated Marcellus Interest acquisition has been accounted for under the acquisition method of accounting. The assets acquired and liabilities assumed in the Anadarko-Operated Marcellus Interest acquisition were recorded in the consolidated balance sheet at their estimated fair values as of the acquisition date. Results of operations attributable to the Anadarko-Operated Marcellus Interest were included in the consolidated statements of income beginning on the acquisition date in the first quarter of 2013.

The following is the final allocation of the purchase price as of September 30, 2013 , including $1.1 million of post-closing purchase price adjustments, to the assets acquired and liabilities assumed in the Anadarko-Operated Marcellus Interest acquisition as of the acquisition date:



thousands
Property, plant and equipment	$	134,819
Asset retirement obligations	(174		)
Total purchase price	$	134,645

The purchase price allocation is based on an assessment of the fair value of the assets acquired and liabilities assumed in the Anadarko-Operated Marcellus Interest acquisition. The fair values of the interests in the land, right-of-way contracts, and gathering systems were based on the market and income approaches. All fair-value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and thus represent Level 3 inputs.

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

2. ACQUISITIONS (CONTINUED)

The following table presents the pro forma condensed financial information as if the Anadarko-Operated Marcellus Interest acquisition had occurred on January 1, 2012:



	Nine Months Ended September 30,
thousands except per-unit amounts	2013		2012
Revenues	$	764,128	$	682,820
Net income	194,074		124,221
Net income attributable to Western Gas Equity Partners, LP	111,512		52,963
Net income per common unit - basic and diluted	$	0.49	n/a

The pro forma information is presented for illustration purposes only and is not necessarily indicative of the operating results that would have occurred had the Anadarko-Operated Marcellus Interest acquisition been completed at the assumed date, nor is it necessarily indicative of future operating results of the combined entity. The pro forma information in the table above includes $8.1 million of revenues and $0.5 million of operating expenses, excluding depreciation, amortization and impairments, attributable to the Anadarko-Operated Marcellus Interest that are included in the consolidated statement of income for the nine months ended September 30, 2013 . The pro forma adjustments reflect pre-acquisition results of the Anadarko-Operated Marcellus Interest including (a) estimated revenues and expenses; (b) estimated depreciation and amortization based on the purchase price allocated to property, plant and equipment and estimated useful lives; and (c) interest on borrowings under WES’s revolving credit facility to finance the Anadarko-Operated Marcellus Interest acquisition. The pro forma adjustments include estimates and assumptions based on currently available information. Management believes the estimates and assumptions are reasonable, and the relative effects of the transaction are properly reflected. The pro forma information does not reflect any cost savings or other synergies anticipated as a result of the Anadarko-Operated Marcellus Interest acquisition, nor any future acquisition related expenses.

Mont Belvieu JV acquisition . The acquisition purchase price represented WES’s 25% share of construction costs incurred by the joint venture partner and 25% of the capitalized interest charged to the financial statements of the Mont Belvieu JV up to the date of acquisition. The allocated capitalized interest is reflected as a component of the equity investment balance recorded upon acquisition. Based on the total estimated net project cost, the construction of the fractionation facilities owned by the Mont Belvieu JV is considered a significant project and satisfies criteria for capitalization of interest. Capitalization of interest subsequent to the acquisition is treated as a basis difference between the cost of the investment and the underlying equity in the net assets of the Mont Belvieu JV. WES will begin to amortize the capitalized interest recognized subsequent to the acquisition upon completion of the facilities, and will reflect the amortization as an adjustment to equity earnings from the Mont Belvieu JV.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

3. PARTNERSHIP DISTRIBUTIONS

WGP partnership distributions. WGP’s partnership agreement requires WGP to distribute all of its available cash (as defined in its partnership agreement) to WGP unitholders of record on the applicable record date within 55 days of the end of each quarter, beginning with the quarter ended December 31, 2012. The board of directors of WGP GP declared the following cash distributions to WGP unitholders for the periods presented:



thousands except per-unit amounts Quarters Ended	Total Quarterly Distribution per Unit		Total Quarterly Cash Distribution		Date of Distribution
2012
December 31 (pro-rated from IPO date)	$	0.03587	$	7,852	February 2013
2013
March 31	$	0.17875	$	39,128	May 2013
June 30	$	0.19750	$	43,232	August 2013
September 30 ⁽¹⁾	$	0.21375	$	46,789	November 2013


⁽¹⁾	On October 16, 2013 , the board of directors of WGP GP declared a cash distribution to WGP unitholders of $0.21375 per unit, or $46.8 million in aggregate. The cash distribution is payable on November 21, 2013 , to WGP unitholders of record at the close of business on October 31, 2013 .

WES partnership distributions. WES’s partnership agreement requires WES to distribute all of its available cash (as defined in WES’s partnership agreement) to WES unitholders of record on the applicable record date within 45 days of the end of each quarter. The board of directors of WES GP declared the following cash distributions to WES unitholders for the periods presented:



thousands except per-unit amounts Quarters Ended	Total Quarterly Distribution per Unit		Total Quarterly Cash Distribution		Date of Distribution
2012
March 31	$	0.460	$	46,053	May 2012
June 30	$	0.480	$	52,425	August 2012
September 30	$	0.500	$	56,346	November 2012
2013
March 31	$	0.540	$	70,143	May 2013
June 30	$	0.560	$	79,315	August 2013
September 30 ⁽¹⁾	$	0.580	$	83,986	November 2013


⁽¹⁾	On October 16, 2013 , the board of directors of WES GP declared a cash distribution to WES unitholders of $0.58 per unit, or $84.0 million in aggregate, including incentive distributions. The cash distribution is payable on November 12, 2013 , to WES unitholders of record at the close of business on October 31, 2013 .

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

4. EQUITY AND PARTNERS’ CAPITAL

Holdings of WGP equity. WGP’s common units are listed on the New York Stock Exchange under the symbol “WGP.” As of September 30, 2013 , Anadarko held 199,137,365 WGP common units, representing a 91.0% limited partner interest in WGP, and, through its ownership of WGP GP, Anadarko indirectly held a non-economic general partner interest in WGP. The public held 19,758,150 WGP common units, representing a 9.0% limited partner interest in WGP.

Net income per common unit. Net income attributable to periods prior to WGP’s IPO is attributable to subsidiaries of Anadarko and therefore not allocated to the limited partners for purposes of calculating net income per common unit. As a result, pre-IPO net income, representing the financial results prior to WGP’s IPO on December 12, 2012, has been excluded from the limited partners’ interest in net income.

Holdings of WES equity. As of September 30, 2013 , WGP held 49,296,205 WES common units, representing a 43.1% limited partner interest in WES, and, through its ownership of WES GP, WGP indirectly held 2,288,573 general partner units, representing a 2.0% general partner interest in WES, and 100% of WES’s IDRs. As of September 30, 2013 , AMM, a subsidiary of Anadarko, separately held 449,129 WES common units, representing a 0.4% limited partner interest in WES, and the public held 62,429,577 WES common units, representing a 54.5% limited partner interest in WES, which are both reflected as noncontrolling interests within the consolidated financial statements of WGP (see Note 1 and Note 2 ).

WES public equity offerings. WES completed the following public offerings of its common units during 2012 and 2013 :



thousands except unit and per-unit amounts	WES Common Units Issued ⁽¹⁾	WES GP Units Issued ⁽²⁾	Price Per Unit		Underwriting Discount and Other Offering Expenses		Net Proceeds to WES
June 2012 equity offering	5,000,000	102,041	$	43.88	$	7,468	$	216,409
May 2013 equity offering	7,015,000	143,163	61.18		13,203		424,733


⁽¹⁾	Includes the issuance of 915,000 WES common units pursuant to the full exercise of the underwriters’ over-allotment option granted in connection with the May 2013 equity offering.


⁽²⁾	Represents general partner units of WES issued to WES GP in exchange for WES GP’s proportionate capital contribution to maintain its 2.0% general partner interest.

In addition, pursuant to WES’s registration statement filed with the SEC in August 2012 authorizing the issuance of up to an aggregate of $125.0 million of WES common units (the “Continuous Offering Program”), WES initiated trades totaling 218,750 common units during the three and nine months ended September 30, 2013 , at an average price per unit of $58.22 , generating gross proceeds of $12.7 million (including WES GP’s proportionate capital contribution and before $0.1 million of invoiced offering expenses), of which $2.7 million had been received as of September 30, 2013 .

WES common and general partner units . The following table summarizes WES common and general partner units issued during the nine months ended September 30, 2013 :



	WES Common Units	WES General Partner Units	Total
Balance at December 31, 2012	104,660,553	2,135,930	106,796,483
Non-Operated Marcellus Interest acquisition	449,129	9,166	458,295
Long-Term Incentive Plan awards	6,879	140	7,019
May 2013 equity offering	7,015,000	143,163	7,158,163
Continuous Offering Program	43,350	174	43,524
Balance at September 30, 2013	112,174,911	2,288,573	114,463,484

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. TRANSACTIONS WITH AFFILIATES

Affiliate transactions. Revenues from affiliates include amounts earned by WES from services provided to Anadarko as well as from the sale of residue, condensate and NGLs to Anadarko. In addition, WES purchases natural gas from an affiliate of Anadarko pursuant to gas purchase agreements. Operating and maintenance expense includes amounts accrued for or paid to affiliates for the operation of WES 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 WES and WGP. 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. See Note 2 for further information related to contributions of assets to WES by Anadarko.

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 WES assets, third-party sales and purchases related to such assets were received or paid in cash by Anadarko within its centralized cash management system. Anadarko charged or credited WES interest at a variable rate on outstanding affiliate balances for the periods these balances remained outstanding. The outstanding affiliate balances were entirely settled through an adjustment to net investment by Anadarko in connection with the acquisition of WES assets. Subsequent to the acquisition of WES assets from Anadarko, transactions related to such assets are cash-settled directly with third parties and with Anadarko affiliates, and affiliate-based interest expense on current intercompany balances is not charged. Chipeta cash settles its transactions directly with third parties and Anadarko, as well as with the other subsidiaries of WES.

Note receivable from and amounts payable to Anadarko. Concurrently with the closing of WES’s May 2008 IPO, WES 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 approximately $301.5 million and $334.8 million at September 30, 2013 , and December 31, 2012 , 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.

In 2008, WES entered into a five-year $175.0 million term loan agreement with Anadarko, which was repaid in full in June 2012 using the proceeds from the issuance of 4.000% Senior Notes due 2022. See Note 8 .

Commodity price swap agreements. WES has commodity price swap agreements with Anadarko to mitigate exposure to commodity price volatility that would otherwise be present as a result of the purchase and sale of natural gas, condensate or NGLs. Notional volumes for each of the commodity price swap agreements are not specifically defined; instead, the commodity price swap agreements apply to the actual volume of natural gas, condensate and NGLs purchased and sold at the Granger, Hilight, Hugoton, Newcastle, MGR and Wattenberg assets, with various expiration dates through December 2016 . The commodity price swap agreements do not satisfy the definition of a derivative financial instrument and, therefore, are not required to be measured at fair value. WES has not entered into any new commodity price swap agreements since the fourth quarter of 2011.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Below is a summary of the fixed price ranges on WES’s outstanding commodity price swap agreements as of September 30, 2013 :



per barrel except natural gas	2013				2014				2015				2016
Ethane	$	18.32	−	30.10	$	18.36	−	30.53	$	18.41	−	23.41	$	23.11
Propane	$	45.90	−	55.84	$	46.47	−	53.78	$	47.08	−	52.99	$	52.90
Isobutane	$	60.44	−	77.66	$	61.24	−	75.13	$	62.09	−	74.02	$	73.89
Normal butane	$	53.20	−	68.24	$	53.89	−	66.01	$	54.62	−	65.04	$	64.93
Natural gasoline	$	70.89	−	92.23	$	71.85	−	83.04	$	72.88	−	81.82	$	81.68
Condensate	$	74.04	−	85.84	$	75.22	−	83.04	$	76.47	−	81.82	$	81.68
Natural gas (per MMbtu)	$	3.75	−	6.09	$	4.45	−	6.20	$	4.66	−	5.96	$	4.87

The following table summarizes realized gains and losses on commodity price swap agreements:



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands	2013			2012			2013			2012
Gains (losses) on commodity price swap agreements related to sales: ⁽¹⁾
Natural gas sales	$	6,923		$	9,132		$	14,707		$	30,728
Natural gas liquids sales	27,541			25,986			83,049			46,020
Total	34,464			35,118			97,756			76,748
Losses on commodity price swap agreements related to purchases ⁽²⁾	(23,902		)	(25,803		)	(66,613		)	(70,342		)
Net gains (losses) on commodity price swap agreements	$	10,562		$	9,315		$	31,143		$	6,406


⁽¹⁾	Reported in affiliate natural gas, NGLs and condensate sales in the consolidated statements of income in the period in which the related sale is recorded.


⁽²⁾	Reported in cost of product in the consolidated statements of income in the period in which the related purchase is recorded.

Gas gathering and processing agreements. WES has significant gas gathering and processing arrangements with affiliates of Anadarko on a majority of its systems. Approximately 56% and 63% of WES’s gathering, transportation and treating throughput (excluding equity investment throughput and volumes measured in barrels) for the three months ended September 30, 2013 and 2012 , respectively, and 58% and 64% for the nine months ended September 30, 2013 and 2012 , respectively, was attributable to natural gas production owned or controlled by Anadarko. Approximately 58% and 61% of WES’s processing throughput (excluding equity investment throughput and volumes measured in barrels) for the three months ended September 30, 2013 and 2012 , respectively, and 56% and 59% for the nine months ended September 30, 2013 and 2012 , respectively, was attributable to natural gas production owned or controlled by Anadarko.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Equipment purchases and sales. The following table summarizes WES’s purchases from and sales to Anadarko of pipe and equipment:



	Nine Months Ended September 30,
	2013		2012		2013		2012
thousands	Purchases				Sales
Consideration ⁽¹⁾	$	6,167	$	18,946	$	82	$	760
Net carrying value	2,039		6,765		34		392
Partners’ capital adjustment	$	4,128	$	12,181	$	48	$	368


⁽¹⁾	Includes a payable of $1.8 million for pipe and equipment purchased in September 2013.

Western Gas Equity Partners, LP 2012 Long-Term Incentive Plan ( “ WGP LTIP ” ). During the nine months ended September 30, 2013 , WGP GP awarded phantom units under the WGP LTIP to its independent directors, which will vest in January 2014, which is one year from the grant date. Compensation expense is recognized ratably over the vesting period and was approximately $0.1 million and $0.2 million for the three and nine months ended September 30, 2013 , respectively.

Western Gas Partners, LP 2008 Long-Term Incentive Plan ( “ WES LTIP ” ). WES GP awards phantom units under the WES LTIP primarily to its independent directors and its Chief Executive Officer. 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. Compensation expense is recognized over the vesting period and was $0.1 million and $0.4 million for the three and nine months ended September 30, 2013 , respectively, and $0.1 million and $0.3 million for the three and nine months ended September 30, 2012 , respectively.

Equity incentive plan and Anadarko incentive plans. General and administrative expenses include equity-based compensation costs allocated by Anadarko for grants made pursuant to (i) the Western Gas Holdings, LLC Equity Incentive Plan, as amended and restated (the “Incentive Plan”) and (ii) the Anadarko Petroleum Corporation 2008 and 2012 Omnibus Incentive Compensation Plans (“Anadarko Incentive Plans”).

General and administrative expenses included $0.8 million and $2.2 million for the three and nine months ended September 30, 2013 , respectively, and $0.8 million and $2.4 million for the three and nine months ended September 30, 2012 , respectively, of equity-based compensation expense for awards granted to the executive officers of WES GP and other employees under the Anadarko Incentive Plans, which was allocated to WES by Anadarko.

For the three and nine months ended September 30, 2012 , general and administrative expenses included $8.6 million and $13.9 million , respectively, of compensation expense for grants of Unit Value Rights, Unit Appreciation Rights (“UARs”) and Distribution Equivalent Rights under the Incentive Plan to certain executive officers of WES GP as a component of their compensation, which was allocated to WES by Anadarko. Awards outstanding under the Incentive Plan at September 30, 2012 , were valued at $1,053 per UAR. WGP’s IPO in December 2012 resulted in the vesting of all then unvested Incentive Plan awards and the effective termination of the Incentive Plan.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

5. TRANSACTIONS WITH AFFILIATES (CONTINUED)

Summary of affiliate transactions. The following table summarizes affiliate transactions, which include revenue from affiliates, reimbursement of operating expenses and purchases of natural gas:



	Three Months Ended September 30,				Nine Months Ended September 30,
thousands	2013		2012		2013		2012
Revenues ⁽¹⁾	$	217,624	$	180,605	$	603,214	$	519,460
Cost of product ⁽¹⁾	33,753		42,839		97,801		115,603
Operation and maintenance ⁽²⁾	13,469		12,638		41,021		38,040
General and administrative ⁽³⁾	6,090		14,227		17,981		30,811
Operating expenses	53,312		69,704		156,803		184,454
Interest income, net ⁽⁴⁾	4,225		4,225		12,675		12,675
Interest expense ⁽⁵⁾	—		81		—		2,684
Distributions to WGP unitholders ⁽⁶⁾	39,329		—		82,068		—
Distributions to WES unitholders ⁽⁷⁾	252		—		494		—
Contributions from Anadarko as a Chipeta noncontrolling interest owner ⁽⁸⁾	—		2,148		—		12,588
Distributions to Anadarko as a Chipeta noncontrolling interest owner ⁽⁸⁾	—		1,464		—		6,528


⁽¹⁾	Represents amounts recognized under gathering, treating or processing agreements, and purchase and sale agreements.


⁽²⁾	Represents expenses incurred on and subsequent to the date of the acquisition of WES assets, as well as expenses incurred by Anadarko on a historical basis related to WES assets prior to the acquisition of such assets by WES.

⁽³⁾

Represents general and administrative expense incurred on and subsequent to the date of WES’s acquisition of WES assets, as well as a management services fee for reimbursement of expenses incurred by Anadarko for periods prior to the acquisition of WES assets by WES. These amounts include equity-based compensation expense allocated to WES by Anadarko (see Equity incentive plan and Anadarko incentive plans within this Note 5 ) and amounts charged by Anadarko under the WGP omnibus agreement.


⁽⁴⁾	Represents interest income recognized on the note receivable from Anadarko.

⁽⁵⁾

For the three and nine months ended September 30, 2012 , includes interest expense recognized on the WES note payable to Anadarko (see Note 8 ) and interest imputed on the reimbursement payable to Anadarko for certain expenditures Anadarko incurred in 2011 related to the construction of the Brasada and Lancaster plants. WES repaid the WES note payable to Anadarko in June 2012, and repaid the reimbursement payable to Anadarko related to the construction of the Brasada and Lancaster plants in the fourth quarter of 2012. See Note receivable from and amounts payable to Anadarko within this Note 5 .


⁽⁶⁾	Represents distributions paid under WGP’s partnership agreement.


⁽⁷⁾	Represents distributions paid under WES’s partnership agreement (see Holdings of WES equity in Note 4 ).


⁽⁸⁾	As described in Note 2 , WES acquired Anadarko’s then remaining 24% membership interest in Chipeta on August 1, 2012, and accounted for the acquisition on a prospective basis. As such, contributions from noncontrolling interest owners and distributions to noncontrolling interest owners subsequent to the acquisition date no longer reflect contributions from or distributions to Anadarko.

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

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

6. PROPERTY, PLANT AND EQUIPMENT

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



thousands	Estimated Useful Life	September 30, 2013		December 31, 2012
Land	n/a	$	2,584	$	501
Gathering systems	3 to 47 years	3,610,879		2,911,572
Pipelines and equipment	15 to 45 years	119,278		91,126
Assets under construction	n/a	318,107		422,002
Other	3 to 25 years	10,541		7,191
Total property, plant and equipment		4,061,389		3,432,392
Accumulated depreciation		817,489		714,436
Net property, plant and equipment		$	3,243,900	$	2,717,956

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. See Note 7 .

During the second quarter of 2013, WES recognized a $1.0 million impairment primarily related to the cancellation of various capital projects by the third-party operator of the Non-Operated Marcellus Interest.

7. COMPONENTS OF WORKING CAPITAL

A summary of other current assets is as follows:



thousands	September 30, 2013		December 31, 2012
Natural gas liquids inventory	$	2,438	$	1,678
Natural gas imbalance receivables	2,729		1,663
Prepaid insurance	2,083		1,897
Other	1,662		1,760
Total other current assets	$	8,912	$	6,998

A summary of accrued liabilities is as follows:



thousands	September 30, 2013		December 31, 2012
Accrued capital expenditures	$	100,876	$	112,311
Accrued plant purchases	20,738		16,350
Accrued interest expense	16,620		15,868
Short-term asset retirement obligations	1,187		1,711
Short-term remediation and reclamation obligations	609		799
Other	293		1,561
Total accrued liabilities	$	140,323	$	148,600

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

8. DEBT AND INTEREST EXPENSE

The following table presents outstanding debt as of September 30, 2013 , and December 31, 2012 :



	September 30, 2013						December 31, 2012
thousands	Principal		Carrying Value		Fair Value ⁽¹⁾		Principal		Carrying Value		Fair Value ⁽¹⁾
4.000% Senior Notes due 2022	$	670,000	$	673,363	$	651,580	$	670,000	$	673,617	$	669,928
5.375% Senior Notes due 2021	500,000		495,042		531,210		500,000		494,661		499,946
WES revolving credit facility	100,000		100,000		100,000		—		—		—
2.600% Senior Notes due 2018	250,000		249,705		249,134		—		—		—
Total debt outstanding	$	1,520,000	$	1,518,110	$	1,531,924	$	1,170,000	$	1,168,278	$	1,169,874


⁽¹⁾	Fair value is measured using Level 2 inputs.

Debt activity. The following table presents the debt activity for the nine months ended September 30, 2013 :



thousands	Carrying Value
Balance as of December 31, 2012	$	1,168,278
WES revolving credit facility borrowings	595,000
Repayments of WES revolving credit facility	(495,000		)
Issuance of 2.600% Senior Notes due 2018	250,000
Other	(168		)
Balance as of September 30, 2013	$	1,518,110

WES Senior Notes. In August 2013, WES completed the offering of $250.0 million aggregate principal amount of 2.600% Senior Notes due 2018 (the “2018 Notes”) at a price to the public of 99.879% of the face amount. Including the effects of the issuance and underwriting discounts, the effective interest rate of the 2018 Notes is 2.806% . Interest will be paid semi-annually on February 15 and August 15 of each year, commencing on February 15, 2014. The 2018 Notes will mature on August 15, 2018 , unless redeemed, in whole or in part, prior to maturity. Proceeds (net of underwriting discount of $1.5 million , original issue discount and debt issuance costs) were used to repay amounts then outstanding under WES’s $800.0 million senior unsecured revolving credit facility (“WES RCF”).

In June 2012, WES completed the offering of $520.0 million aggregate principal amount of 4.000% Senior Notes due 2022 at a price to the public of 99.194% of the face amount. In October 2012, WES issued an additional $150.0 million in aggregate principal amount of 4.000% Senior Notes due 2022 at a price to the public of 105.178% of the face amount. The October 2012 notes and the June 2012 notes were issued under the same indenture and are considered a single class of securities, collectively referred to as the “2022 Notes.”

In May 2011, WES completed the offering of $500.0 million aggregate principal amount of 5.375% Senior Notes due 2021 (the “2021 Notes”) at a price to the public of 98.778% of the face amount.

At September 30, 2013 , WES was in compliance with all covenants under the indentures governing the 2021 Notes, 2022 Notes and the 2018 Notes.

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

8. DEBT AND INTEREST EXPENSE (CONTINUED)

Interest rate agreements. In May 2012, WES entered into U.S. Treasury Rate lock agreements to mitigate the risk of rising interest rates prior to the issuance of the 2022 Notes. WES settled the rate lock agreements simultaneously with the June 2012 offering of the 2022 Notes, realizing a loss of $1.7 million , which is included in other income (expense), net in the consolidated statements of income.

WES note payable to Anadarko . In 2008, WES entered into a five-year $175.0 million term loan agreement with Anadarko. The interest rate was fixed at 2.82% prior to June 2012 when the WES note payable to Anadarko was repaid in full with proceeds from the June 2012 offering of the 2022 Notes.

WES revolving credit facility. At September 30, 2013 , and December 31, 2012 , the interest rate on the WES RCF was 1.68% and 1.71% , respectively. WES is required to pay a quarterly facility fee currently ranging from 0.20% to 0.35% of the commitment amount (whether used or unused), based upon its senior unsecured debt rating. The facility fee rate was 0.25% at September 30, 2013 , and December 31, 2012 .

At September 30, 2013 , WES had $100.0 million of outstanding borrowings, $12.8 million in outstanding letters of credit issued and $687.2 million available for borrowing under the WES RCF. At September 30, 2013 , WES was in compliance with all covenants under the WES RCF.

The 2021 Notes, the 2022 Notes, the 2018 Notes and obligations under the WES RCF are recourse to WES GP, and as of December 31, 2012, WES GP was indemnified by a wholly owned subsidiary of Anadarko, Western Gas Resources, Inc. (“WGRI”), against any claims made against WES GP under the 2022 Notes, the 2021 Notes and/or the WES RCF.

In connection with the acquisition of the Non-Operated Marcellus Interest in March 2013, WES GP and another wholly owned subsidiary of Anadarko entered into an indemnification agreement (the “2013 Indemnification Agreement”) whereby such subsidiary agreed to indemnify WES GP for any recourse liability it may have for WES RCF borrowings, or other debt financing, attributable to the acquisitions of the Non-Operated Marcellus Interest or the Anadarko-Operated Marcellus Interest. As of September 30, 2013 , the 2013 Indemnification Agreement applied to the $250.0 million of 2018 Notes. WES GP and WGRI also amended and restated the existing indemnity agreement between them to reduce the amount for which WGRI would indemnify WES GP by an amount equal to any amounts payable to WES GP under the 2013 Indemnification Agreement.

WGP working capital facility. On November 1, 2012, WGP entered into a $30.0 million working capital facility (the “WGP WCF”) with Anadarko as the lender. The facility is available exclusively to fund WGP’s working capital borrowings. Borrowings under the facility will mature on November 1, 2017, and will bear interest at London Interbank Offered Rate (“LIBOR”) plus 1.50% . The interest rate was 1.68% and 1.71% at September 30, 2013 , and December 31, 2012 , respectively.

WGP is required to reduce all borrowings under the WGP WCF to zero for a period of at least 15 consecutive days during the twelve month period commencing on November 1, 2012, and during the twelve month period commencing on each anniversary thereof. As of September 30, 2013 , WGP had no outstanding borrowings under the WGP WCF, and WGP was in compliance with all covenants under the WGP WCF.

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

8. DEBT AND INTEREST EXPENSE (CONTINUED)

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



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands	2013			2012			2013			2012
Third parties
Interest expense on long-term debt	$	14,994		$	11,919		$	43,783		$	28,036
Amortization of debt issuance costs and commitment fees ⁽¹⁾	1,135			1,201			3,252			3,225
Capitalized interest	(3,111		)	(2,224		)	(9,552		)	(3,827		)
Total interest expense – third parties	13,018			10,896			37,483			27,434
Affiliates
Interest expense on WES note payable to Anadarko ⁽²⁾	—			—			—			2,440
Interest expense on affiliate balances ⁽³⁾	—			81			—			244
Total interest expense – affiliates	—			81			—			2,684
Interest expense	$	13,018		$	10,977		$	37,483		$	30,118

⁽¹⁾

For the three and nine months ended September 30, 2013 , includes $0.3 million and $0.8 million , respectively, of amortization of (i) the original issue discount for the June 2012 offering of the 2022 Notes, partially offset by the original issue premium for the October 2012 offering of the 2022 Notes, (ii) original issue discount for the 2021 Notes and 2018 Notes and (iii) underwriters’ fees. For the three and nine months ended September 30, 2012 , includes $0.4 million and $0.8 million , respectively, of amortization of the original issue discount and underwriters’ fees for the 2022 Notes issued in June 2012 and the 2021 Notes.


⁽²⁾	In June 2012, the WES note payable to Anadarko was repaid in full. See WES note payable to Anadarko within this Note 8 .


⁽³⁾	Imputed interest expense on the reimbursement payable to Anadarko for certain expenditures Anadarko incurred in 2011 related to the construction of the Brasada and Lancaster plants. In the fourth quarter of 2012, WES repaid the reimbursement payable to Anadarko associated with the construction of the Brasada and Lancaster plants.

9. COMMITMENTS AND CONTINGENCIES

Litigation and legal proceedings. In March 2011, DCP Midstream LP (“DCP”) filed a lawsuit against Anadarko and others, including a subsidiary of WES, Kerr-McGee Gathering LLC, in Weld County District Court (the “Court”) in Colorado, alleging that Anadarko and its affiliates diverted gas from DCP’s gathering and processing facilities in breach of certain dedication agreements. In addition to various claims against Anadarko, DCP is claiming unjust enrichment and other damages against Kerr-McGee Gathering LLC, the entity which holds the Wattenberg assets. Anadarko countersued DCP asserting that DCP has not properly allocated values and charges to Anadarko for the gas that DCP gathers and/or processes, and seeks a judgment that DCP has no valid gathering or processing rights to much of the gas production it is claiming, in addition to other claims.

In July 2011, the Court denied the defendants’ motion to dismiss without ruling on the merits and the case is in the discovery phase. Trial is set for April 2014. Management does not believe the outcome of this proceeding will have a material effect on the financial condition, results of operations or cash flows of WGP. WES intends to vigorously defend this litigation. Furthermore, without regard to the merit of DCP’s claims, management believes that WES has adequate contractual indemnities covering the claims against it in this lawsuit.

In addition, from time to time, WGP, through its partnership interests in WES, 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 a final disposition could have a material adverse effect on the financial condition, results of operations or cash flows of WGP.

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WESTERN GAS EQUITY PARTNERS, LP

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

9. COMMITMENTS AND CONTINGENCIES (CONTINUED)

Other commitments. WES has short-term payment obligations, or commitments, related to its capital spending programs, as well as those of its unconsolidated affiliates. As of September 30, 2013 , WES had unconditional payment obligations for services to be rendered or products to be delivered in connection with its capital projects of approximately $61.3 million , the majority of which is expected to be paid in the next twelve months. These commitments relate primarily to the continued construction of the Lancaster plant and an expansion project at the Fort Lupton compressor station in the Wattenberg system. In addition, as of September 30, 2013 , and in conjunction with the Mont Belvieu JV acquisition, WES is committed to fund 25% , or approximately $13.6 million , of the total remaining estimated net project cost to complete the construction of the fractionation facilities over the next six months (see Note 2 ).

Lease commitments. Anadarko, on WES’s behalf, has entered into lease agreements for corporate offices, shared field offices and a warehouse supporting WES’s operations. The leases for the corporate offices and shared field offices extend through 2017 and 2018, respectively, and the lease for the warehouse extends through February 2014 and includes an early termination clause.

Rent expense associated with the office, warehouse and equipment leases was $0.6 million and $2.0 million for the three and nine months ended September 30, 2013 , respectively, and $0.8 million and $2.3 million for the three and nine months ended September 30, 2012 , respectively.

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

The following discussion analyzes our financial condition and results of operations and should be read in conjunction with the consolidated financial statements and notes to consolidated financial statements, which are included under Part I, Item 1 of this quarterly report, as well as our historical consolidated financial statements, and the notes thereto, which are included in Part I, Item 8 of our 2012 Form 10-K as filed with the Securities and Exchange Commission, or “SEC,” on March 28, 2013, and our other public filings and press releases. Unless the context otherwise requires, references to “WGP,” “we,” “us,” “our,” or “Western Gas Equity Partners” refer to Western Gas Equity Partners, LP in its individual capacity or to Western Gas Equity Partners, LP and its subsidiaries, as the context requires. Our general partner, Western Gas Equity Holdings, LLC (“WGP GP”), is a wholly owned subsidiary of Anadarko Petroleum Corporation. The general partner of Western Gas Partners, LP (“WES”) is Western Gas Holdings, LLC (“WES GP”), our wholly owned subsidiary. “Anadarko” refers to Anadarko Petroleum Corporation and its consolidated subsidiaries, excluding us and WGP GP. “WGP and Affiliates” refers to subsidiaries of Anadarko, including us in our individual capacity, and “affiliates” refers to subsidiaries of Anadarko excluding us, and includes the interests in Fort Union Gas Gathering, LLC, (“Fort Union”), White Cliffs Pipeline, LLC (“White Cliffs”), Rendezvous Gas Services, LLC (“Rendezvous”), and a joint venture, Enterprise EF78 LLC (“Mont Belvieu JV”). “Equity investment throughput” refers to WES’s 14.81% share of Fort Union and 22% share of Rendezvous gross volumes.

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

We have made in this report, and may from time to time otherwise make in other public filings, press releases and discussions by management, forward-looking statements concerning operations, economic performance and financial condition. These statements can be identified by the use of forward-looking terminology including “may,” “will,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” or other similar words. These statements discuss future expectations, contain projections of results of operations or financial condition or include other “forward-looking” information. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will be realized.

These forward-looking statements involve risks and uncertainties. Important factors that could cause actual results to differ materially from our expectations include, but are not limited to, the following risks and uncertainties:


•	our ability to pay distributions to our unitholders;


•	our expected receipt of, and the amounts of, distributions from WES;


•	WES’s and Anadarko’s assumptions about the energy market;


•	WES’s future throughput, including Anadarko’s production, which is gathered or processed by or transported through WES’s assets;


•	operating results of WES;


•	competitive conditions;


•	technology;


•	availability of capital resources to fund acquisitions, capital expenditures and other contractual obligations of WES, and WES’s ability to access those resources from Anadarko or through the debt or equity capital markets;


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


•	weather;


•	inflation;


•	availability of goods and services;

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•	general economic conditions, either internationally or domestically or in the jurisdictions in which WES is doing business;


•	changes in regulations at the federal, state and local level or WES’s inability to timely obtain or maintain permits that could affect WES’s and WES’s customers’ activities; environmental risks; regulations by the Federal Energy Regulatory Commission (“FERC”); and liability under federal and state laws and regulations;


•	legislative or regulatory changes affecting our or WES’s status as a partnership for federal income tax purposes;


•	changes in the financial or operational condition of WES or Anadarko;


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


•	WES’s commitments to capital projects;


•	ability of WES to utilize its revolving credit facility (“WES RCF”);


•	creditworthiness of Anadarko or WES’s other counterparties, including financial institutions, operating partners, and other parties;


•	our and WES’s ability to repay debt;


•	WES’s ability to mitigate commodity price risks inherent in its percent-of-proceeds and keep-whole contracts;


•	conflicts of interest among WES, WES GP, WGP and WGP GP, and affiliates, including Anadarko;


•	WES’s ability to maintain and/or obtain rights to operate its assets on land owned by third parties;


•	our or WES’s ability to acquire assets on acceptable terms;


•	non-payment or non-performance of Anadarko or WES’s other significant customers, including under WES’s gathering, processing and transportation agreements and its $ 260.0 million note receivable from Anadarko;


•	timing, amount and terms of our or WES’s future issuances of equity and debt securities; and


•	other factors discussed below, in “Risk Factors” included in our 2012 Form 10-K, in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates,” in our quarterly reports on Form 10-Q and elsewhere in our other public filings and press releases.

The risk factors and other factors noted throughout or incorporated by reference in this report could cause our actual results to differ materially from those contained in any forward-looking statement. We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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EXECUTIVE SUMMARY

We were formed by Anadarko in September 2012 by converting WGR Holdings, LLC into a limited partnership and changing its name to Western Gas Equity Partners, LP. We closed our IPO in December 2012 and own WES GP and a significant limited partner interest in WES, a growth-oriented Delaware master limited partnership organized by Anadarko to own, operate, acquire and develop midstream energy assets. WES currently owns assets located in East, West and South Texas, the Rocky Mountains (Colorado, Utah and Wyoming), north-central Pennsylvania, and the Mid-Continent (Kansas and Oklahoma) and is engaged in the business of gathering, processing, compressing, treating and transporting natural gas, condensate, NGLs and crude oil for Anadarko and its consolidated subsidiaries, as well as for third-party producers and customers. As of September 30, 2013 , WES owned and operated thirteen natural gas gathering systems, eight natural gas treating facilities, eight natural gas processing facilities, three NGL pipelines and three natural gas pipelines. In addition, WES had interests in five non-operated natural gas gathering systems, one operated natural gas gathering system and three operated natural gas processing facilities, with separate interests accounted for under the equity method in two natural gas gathering systems, a crude oil pipeline and two NGL fractionators currently under construction. WES also had the Lancaster processing facility under construction in Northeast Colorado at the end of the third quarter of 2013.

Significant financial highlights during the first nine months of 2013 included the following:


•	We raised our distribution to $0.21375 per unit for the third quarter of 2013, representing an 8% increase over the distribution for the second quarter of 2013.


•	WES issued $250.0 million aggregate principal amount of 2.600% Senior Notes due 2018. Net proceeds were used to repay amounts then outstanding under the WES RCF. See Liquidity and Capital Resources within this Item 2 for additional information.


•	WES completed construction and commenced operations in June 2013 of the 200 MMcf/d Brasada gas processing plant and related facilities in the Eagleford shale area of South Texas.


•	WES announced a project to expand the processing capacity at its Lancaster plant, which is currently under construction, by another 300 MMcf/d with a second cryogenic processing train.


•	WES completed the acquisition of a 25% interest in the Mont Belvieu JV, which is constructing NGL fractionators located in Mont Belvieu, Texas, and the acquisition of Overland Trail Transmission, LLC, which owns and operates an intrastate pipeline connecting WES’s Red Desert and Granger complexes in southwestern Wyoming. See Acquisitions below.


•	WES issued 7,058,350 common units to the public, generating net proceeds of $427.3 million, including WES GP’s proportionate capital contribution to maintain its 2.0% general partner interest. Net proceeds were used to repay a portion of the amount outstanding under the WES RCF, with the remaining net proceeds used for general partnership purposes, including the funding of capital expenditures.

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•	WES completed the acquisition of Anadarko’s 33.75% interest (non-operated) in the Liberty and Rome gas gathering systems in north-central Pennsylvania and the acquisition from a third party of a 33.75% interest (operated by Anadarko) in each of the Larry’s Creek, Seely and Warrensville gas gathering systems, also in north-central Pennsylvania. See Acquisitions below.


•	WES raised its distribution to $0.58 per unit for the third quarter of 2013 , representing a 4% increase over the distribution for the second quarter of 2013, a 16% increase over the distribution for the third quarter of 2012, and its eighteenth consecutive quarterly increase.

Significant operational highlights during the first nine months of 2013 included the following:


•	Throughput attributable to WES totaled 3,285 MMcf/d and 3,111 MMcf/d for the three and nine months ended September 30, 2013 , respectively, representing a 16% and a 13% increase , respectively, compared to the same periods in 2012 .


•	Gross margin (total revenues less cost of product) attributable to WES averag ed $0.59 per Mcf and $0.57 per Mcf for the three and nine months ended September 30, 2013 , respectively, representing a 9% and 6% increase , respectively, compared to the same periods in 2012 .

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ACQUISITIONS

Acquisitions. The following table presents the acquisitions completed by WES during 2012 and 2013 , and identifies the funding sources for such acquisitions.



thousands except unit and percent amounts	Acquisition Date	Percentage Acquired		Borrowings		Cash On Hand		WES Common Units Issued	WES GP Units Issued
MGR ⁽¹⁾	01/13/2012	100	%	$	299,000	$	159,587	632,783	12,914
Chipeta ⁽²⁾	08/01/2012	24	%	—		128,250		151,235	3,086
Non-Operated Marcellus Interest ⁽³⁾	03/01/2013	33.75	%	250,000		215,500		449,129	—
Anadarko-Operated Marcellus Interest ⁽⁴⁾	03/08/2013	33.75	%	133,500		—		—	—
Mont Belvieu JV ⁽⁵⁾	06/05/2013	25	%	—		78,129		—	—
OTTCO ⁽⁶⁾	09/03/2013	100	%	27,500		—		—	—

⁽¹⁾

The assets acquired from Anadarko consist of (i) the Red Desert complex, which is located in the greater Green River Basin in southwestern Wyoming, and includes the Patrick Draw processing plant with a capacity of 125 MMcf/d, the Red Desert processing plant with a capacity of 48 MMcf/d, 1,295 miles of gathering lines, and related facilities, (ii) a 22% interest in Rendezvous, which owns a 338-mile mainline gathering system serving the Jonah and Pinedale Anticline fields in southwestern Wyoming, and (iii) certain additional midstream assets and equipment. These assets are collectively referred to as the “MGR assets” and the acquisition as the “MGR acquisition.”

⁽²⁾

WES acquired Anadarko’s then remaining 24% membership interest in Chipeta (as described in

Note 1—Description of Business and Basis of Presentation in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q). WES received distributions related to the additional interest beginning July 1, 2012. This transaction brought WES’s total membership interest in Chipeta to 75%. The remaining 25% membership interest in Chipeta held by a third-party member is reflected as noncontrolling interests in our consolidated financial statements for all periods presented.

⁽³⁾

⁽⁴⁾

The interest acquired from a third party consisted of a 33.75% interest in each of the Larry’s Creek, Seely and Warrensville gas gathering systems, which are operated by Anadarko and serve production from the Marcellus shale in north-central Pennsylvania. The interest acquired is referred to as the “Anadarko-Operated Marcellus Interest” and the acquisition as the “Anadarko-Operated Marcellus Interest acquisition.” See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

⁽⁵⁾

The acquisition from a third party consisted of a 25% interest in Enterprise EF78 LLC, an entity formed to design, construct, and own two fractionators located in Mont Belvieu, Texas. The interest acquired is accounted for under the equity method of accounting and is referred to as the “Mont Belvieu JV” and the acquisition as the “Mont Belvieu JV acquisition.” See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

⁽⁶⁾

WES acquired Overland Trail Transmission, LLC (“OTTCO”), a Delaware limited liability company, from a third party. OTTCO owns and operates an intrastate pipeline which connects WES’s Red Desert and Granger complexes in southwestern Wyoming. The assets acquired are referred to as the “OTTCO pipeline” and the acquisition as the “OTTCO acquisition.” See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

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Presentation of WES assets. References to “WES assets” refer collectively to the assets indirectly owned by WGP, through its partnership interests in WES, as of September 30, 2013 . Because Anadarko controls WES through its ownership and control of WGP, which owns WES GP, each of WES’s acquisitions of assets from Anadarko has been considered a transfer of net assets between entities under common control. As such, WES assets acquired from Anadarko were initially recorded at Anadarko’s historic carrying value, which did not correlate to the total acquisition price paid by WES (see Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q). Further, as a result of asset acquisitions between entities under common control, WES and WGP (by virtue of its consolidation of WES) may be required to recast their financial statements to include the activities of such assets as of the date of common control.

WGP’s historical financial statements include the results attributable to the Non-Operated Marcellus Interest as if WES owned such assets for all periods presented. The consolidated financial statements for periods prior to WES’s acquisition of WES assets from Anadarko, including the Non-Operated Marcellus Interest, 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 WES had owned the assets during the periods reported.

EQUITY OFFERINGS

WGP initial public offering. On December 12, 2012, we closed our IPO of 19,758,150 common units at a price of $22.00 per common unit. Pursuant to a unit purchase agreement among us, WES and WES GP, we used $409.4 million of the net proceeds from the IPO to purchase 8,722,966 WES common units, and made a corresponding capital contribution to WES on behalf of WES GP to allow WES GP to maintain its 2.0% general partner interest in WES, in exchange for 178,019 WES general partner units, in each case at a price of $46.00 per unit.

WES equity offerings

Public equity offerings. WES completed the following public equity offerings during 2012 and 2013 :



thousands except unit and per-unit amounts	WES Common Units Issued ⁽¹⁾	WES GP Units Issued ⁽²⁾	Price Per Unit		Underwriting Discount and Other Offering Expenses		Net Proceeds to WES
June 2012 equity offering	5,000,000	102,041	$	43.88	$	7,468	$	216,409
May 2013 equity offering	7,015,000	143,163	61.18		13,203		424,733


⁽¹⁾	Includes the issuance of 915,000 WES common units pursuant to the full exercise of the underwriters’ over-allotment option granted in connection with the May 2013 equity offering.


⁽²⁾	Represents general partner units of WES issued to WES GP in exchange for WES GP’s proportionate capital contribution to maintain its 2.0% general partner interest.

Other equity offerings. Pursuant to WES’s registration statement filed with the SEC in August 2012 authorizing the issuance of up to an aggregate of $125.0 million of WES common units (the “Continuous Offering Program”), WES initiated trades totaling 218,750 common units during the three and nine months ended September 30, 2013 , at an average price per unit of $58.22 , generating gross proceeds of $12.7 million (including WES GP’s proportionate capital contribution and before $0.1 million of invoiced offering expenses), of which $2.7 million had been received as of September 30, 2013 .

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ITEMS AFFECTING THE COMPARABLITY OF OUR FINANCIAL RESULTS TO THOSE OF WES

Our consolidated financial statements include the consolidated financial results of WES due to our 100% ownership interest in WES GP and WES GP’s control of WES. Our only cash-generating assets consist of our partnership interests in WES, and we currently have no independent operations. As a result, our results of operations do not differ materially from the results of operations of WES, which are reconciled below. The primary items which result in differences between our and WES’s results of operations and cash flows are summarized below.

Income taxes . Prior to our conversion from WGR Holdings, LLC to a limited partnership in September 2012, we were a single-member limited liability company. The separate existence of a limited liability company is disregarded for U.S. federal income tax purposes, resulting in the treatment of WGR Holdings, LLC as a division of Anadarko and its inclusion in Anadarko’s consolidated income tax return for federal and state tax purposes. The income tax expense recorded on the financial statements of WGR Holdings, LLC, and now included in our consolidated financial statements, reflects our income tax expense and liability on a separate-return basis.

The deferred federal and state income taxes included in our consolidated financial statements are primarily attributable to the temporary differences between the financial statement carrying amount of our investment in WES and our outside tax basis with respect to our partnership interests in WES. When determining the deferred income tax asset and liability balances attributable to our partnership interests in WES, we applied an accounting policy that looks through our investment in WES. The application of such accounting policy resulted in no deferred income taxes being created on the difference between the book and tax basis on the non-tax deductible goodwill portion of our investment in WES in our consolidated financial statements.

Upon the completion of our IPO in December 2012, we became a publicly traded limited partnership for U.S. federal and state income tax purposes and therefore are not subject to U.S. federal and state income taxes, except for Texas margin tax.

General and administrative expenses. As a separate publicly traded partnership, we incur general and administrative expenses which are separate from, and in addition to, those incurred by WES. In connection with our IPO in December 2012, we entered into an omnibus agreement with WGP GP and Anadarko that governs the following: (i) our obligation to reimburse Anadarko for expenses incurred or payments made on our behalf in conjunction with Anadarko’s provision of general and administrative services to us, including our public company expenses and general and administrative expenses; (ii) our obligation to pay Anadarko, in quarterly installments, an administrative services fee of $250,000 per year (subject to an annual increase as described in the agreement); and (iii) our obligation to reimburse Anadarko for all insurance coverage expenses it incurs or payments it makes on our behalf.

Noncontrolling interests. The publicly held common units of WES are reflected as noncontrolling interests in our consolidated financial statements, and are in addition to the noncontrolling interests in Chipeta, which are already reflected as noncontrolling interests in WES’s consolidated financial statements. In addition, in March 2013, WES acquired a 33.75% interest in the Liberty and Rome gas gathering systems from Anadarko Marcellus Midstream, L.L.C. (“AMM”), a wholly owned subsidiary of Anadarko. As part of the consideration paid, WES issued 449,129 WES common units to AMM. The limited partner interest in WES held by AMM is reflected within noncontrolling interests in our consolidated financial statements for the three and nine months ended September 30, 2013 .

Distributions. 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 only cash-generating assets are our partnership interests in WES, consisting of general partner units, common units and incentive distribution rights, on which we expect to receive quarterly distributions from WES. Our cash flow and resulting ability to make cash distributions are therefore completely dependent upon WES’s ability to make cash distributions with respect to our partnership interests in WES. 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.

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Western Gas Equity Partners, LP 2012 Long-Term Incentive Plan. Concurrently with our IPO, WGP GP adopted the Western Gas Equity Partners, LP 2012 Long-Term Incentive Plan (“WGP LTIP”). Upon vesting of each phantom unit, the holder will receive common units of WGP or, at the discretion of WGP GP’s board of directors, cash in an amount equal to the market value of common units of WGP on the vesting date. Equity-based compensation expense attributable to grants made under the WGP LTIP impact cash flows from operating activities only to the extent cash payments are made to a participant in lieu of issuance of WGP common units to the participant. Stock-based compensation expense attributable to awards granted under the WGP LTIP will be amortized over the vesting periods applicable to the awards. During the nine months ended September 30, 2013 , WGP GP awarded phantom units under the WGP LTIP to its independent directors, which will vest in January 2014, which is one year from the grant date.

Working capital facility. On November 1, 2012, we entered into a $30.0 million working capital facility (“WGP WCF”) with Anadarko as the lender. The facility is available exclusively to fund our working capital borrowings. Borrowings under the facility will mature on November 1, 2017, and will bear interest at London Interbank Offered Rate (“LIBOR”) plus 1.50%. The interest rate was 1.68% and 1.71% at September 30, 2013 , and December 31, 2012 , respectively.

We are required to reduce all borrowings under the WGP WCF to zero for a period of at least 15 consecutive days during the twelve month period commencing on November 1, 2012, and during the twelve month period commencing on each anniversary thereof. As of September 30, 2013 , we had no outstanding borrowings under the WGP WCF. At September 30, 2013 , we were in compliance with all covenants under the WGP WCF.

Reconciliation of net income attributable to Western Gas Partners, LP to net income attributable to Western Gas Equity Partners, LP. The differences between net income attributable to Western Gas Partners, LP and net income attributable to Western Gas Equity Partners, LP are reconciled as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands	2013			2012			2013			2012
Net income attributable to WES	$	78,400		$	46,579		$	189,257		$	143,539
Incremental income tax expense ⁽¹⁾	—			(9,086		)	—			(29,202		)
Limited partner interests in WES not held by WGP ⁽²⁾	(33,403		)	(18,182		)	(75,095		)	(59,302		)
General and administrative expenses ⁽³⁾	(686		)	—			(2,872		)	—
Other income	27			—			74			—
Net income attributable to WGP	$	44,338		$	19,311		$	111,364		$	55,035

⁽¹⁾

The income tax expense recorded in the financial statements of WGR Holdings, LLC, and now reflected in the consolidated financial statements of WGP, reflects our pre-IPO income tax expense and liability on a separate-return basis. Upon the completion of our IPO in December 2012, we became a partnership for U.S. federal and state income tax purposes and therefore are subsequently not subject to U.S. federal and state income taxes, except for Texas margin tax.


⁽²⁾	Represents the portion of net income allocated to the limited partner interests in WES not held by WGP. As of September 30, 2013 and 2012 , publicly held limited partner interests represented a 54.5% and 56.6% interest in WES, respectively. As of September 30, 2013 , AMM held a 0.4% limited partner interest in WES.


⁽³⁾	Represents general and administrative expenses incurred by WGP separate from, and in addition to, those incurred by WES.

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Reconciliation of net cash provided by operating and financing activities. The differences between net cash provided by operating activities for WGP and WES and net cash provided by financing activities for WGP and WES are reconciled as follows:



	Nine Months Ended September 30,
thousands	2013			2012
WES net cash provided by operating activities	$	289,069		$	343,587
Income taxes ⁽¹⁾	—			(62,042		)
General and administrative expenses ⁽²⁾	(2,872		)	—
Non-cash equity-based compensation expense	219			—
Changes in working capital	(419		)	11
Other income	74			—
WGP net cash provided by operating activities	$	286,071		$	281,556

WES net cash provided by financing activities	$	555,718		$	486,644
Proceeds from issuance of WES general partner units ⁽³⁾	(9,278		)	(4,497		)
Offering expenses from the issuance of WGP common units ⁽⁴⁾	(2,367		)	—
Distributions to WGP unitholders ⁽⁵⁾	(90,211		)	—
Distributions to WGP from WES ⁽⁶⁾	120,998			69,615
Net contributions from (distributions to) Anadarko ⁽⁷⁾	—			(3,087		)
WGP net cash provided by financing activities	$	574,860		$	548,675

⁽¹⁾


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


⁽³⁾	Difference is attributable to elimination upon consolidation of proceeds to WES from issuance of WES general partner units in exchange for WES GP’s proportionate capital contribution to maintain its 2.0% general partner interest.


⁽⁴⁾	Represents additional offering costs incurred in conjunction with WGP’s IPO in December 2012.


⁽⁵⁾	Represents distributions to WGP common unitholders for the pro-rated fourth quarter of 2012 and for the first and second quarters of 2013.

⁽⁶⁾

Difference attributable to elimination upon consolidation of WES’s distributions on partnership interests owned by WGP. As of September 30, 2013 , WGP held a 43.1% li mited partner interest in WES and, through its ownership of WES GP, indirectly held a 2.0% general partner interest in WES and 100% of WES ’ s incentive distribution rights. During the nine months ended September 30, 2013 and 2012 , WES paid $215.1 million and $141.5 million , respectively, to its unitholders, of which $94.1 million and $71.9 million , respectively, were paid to noncontrolling interest owners.


⁽⁷⁾	Difference attributable to (i) contribution of current tax expense, (ii) changes in net income, and (iii) elimination upon consolidation of proceeds from WES equity transactions and WES distributions to WGP.

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RESULTS OF OPERATIONS

OPERATING RESULTS

The following tables and discussion present a summary of WES’s results of operations:



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands	2013			2012			2013			2012
Gathering, processing and transportation of natural gas and natural gas liquids	$	130,781		$	93,933		$	343,471		$	278,966
Natural gas, natural gas liquids and condensate sales	141,326			136,106			402,616			386,818
Equity income and other, net	5,894			4,695			16,787			13,936
Total revenues ⁽¹⁾	278,001			234,734			762,874			679,720
Total operating expenses ⁽¹⁾	187,813			173,422			538,523			491,907
Operating income	90,188			61,312			224,351			187,813
Interest income, net – affiliates	4,225			4,225			12,675			12,675
Interest expense	(13,018		)	(10,977		)	(37,483		)	(30,118		)
Other income (expense), net	439			522			1,612			(287		)
Income before income taxes	81,834			55,082			201,155			170,083
Income tax expense	58			5,080			4,431			14,588
Net income	81,776			50,002			196,724			155,495
Net income attributable to noncontrolling interests	3,376			3,423			7,467			11,956
Net income attributable to Western Gas Partners, LP ⁽²⁾	$	78,400		$	46,579		$	189,257		$	143,539
Key performance metrics ⁽³⁾
Gross margin	$	184,485		$	145,627		$	492,815		$	425,001
Adjusted EBITDA attributable to Western Gas Partners, LP	$	125,174		$	97,494		$	328,749		$	279,813
Distributable cash flow	$	105,881		$	74,778		$	274,794		$	229,429

⁽¹⁾

Revenues include amounts earned by WES from services provided to its affiliates, as well as from the sale of residue, condensate and NGLs to its affiliates. Operating expenses include amounts charged by WES affiliates for services as well as reimbursement of amounts paid by affiliates to third parties on WES’s behalf. See Note 5—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.


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


⁽³⁾	Gross margin, Adjusted EBITDA and Distributable cash flow are defined under the caption Key Performance Metrics within this Item 2 . Such caption also includes reconciliations of Adjusted EBITDA and Distributable cash flow to their most directly comparable financial measures calculated and presented in accordance with generally accepted accounting principles in the United States (“GAAP”).

For purposes of the following discussion, any increases or decreases “for the three months ended September 30, 2013 ” refer to the comparison of the three months ended September 30, 2013 , to the three months ended September 30, 2012 ; any increases or decreases “for the nine months ended September 30, 2013 ” refer to the comparison of the nine months ended September 30, 2013 , to the nine months ended September 30, 2012 ; and any increases or decreases “for the three and nine months ended September 30, 2013 ” refer to both the comparisons for the three and nine months ended September 30, 2013 .

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Throughput



	Three Months Ended September 30,				Nine Months Ended September 30,
throughput in MMcf/d	2013	2012	Inc/ (Dec)		2013	2012	Inc/ (Dec)
Gathering, treating and transportation ⁽¹⁾	1,844	1,576	17	%	1,746	1,598	9	%
Processing ⁽²⁾	1,397	1,228	14	%	1,320	1,182	12	%
Equity investment ⁽³⁾	221	236	(6	)%	211	236	(11	)%
Total throughput ⁽⁴⁾	3,462	3,040	14	%	3,277	3,016	9	%
Throughput attributable to noncontrolling interests	177	204	(13	)%	166	254	(35	)%
Total throughput attributable to Western Gas Partners, LP	3,285	2,836	16	%	3,111	2,762	13	%

⁽¹⁾

Excludes average NGL pipeline volum es of 25 MBbls/d and 22 MBbls/d for the three and nine months ended September 30, 2013 , respectively, and 22 MBbls/d and 25 MBbls/d for the three and nine months ended September 30, 2012 , respectively. Includes 100% of Wattenberg system volumes for all periods presented and throughput beginning March 2013 attributable to the Anadarko-Operated Marcellus Interest.


⁽²⁾	Consists of 100% of Chipeta, Hilight and Platte Valley system volumes, 100% of the Granger and Red Desert complex volumes, and 50% of Newcastle volumes.


⁽³⁾	Represents WES’s 14.81% share of Fort Union and 22% share of Rendezvous gross volumes, and excludes WES’s 10% share of average White Cliffs pipeline volumes consisting of 6 MBbls/d and 7 MBbls/d for the three and nine months ended September 30, 2013 , respectively, and 6 MBbls/d for both the three and nine months ended September 30, 2012 .


⁽⁴⁾	Includes affiliate, third-party and equity-investment volumes.

Gathering, treating and transportation thro ughput increase d by 268 MMcf/d and 148 MMcf/d for the three and nine months ended September 30, 2013 , respectively, due to increased volumes at the Non-Operated Marcellus Interest and additional throughput from the Anadarko-Operated Marcellus Interest beginning in March 2013. These increases were partially offset by decreases at the Bison facility resulting from reduced drilling activity in the area and at MIGC due to the expiration of a firm transportation agreement effective September 2012.

Processing throughput increase d by 169 MMcf/d and 138 MMcf/d for the three and nine months ended September 30, 2013 , respectively, primarily due to throughput increases at Chipeta, the start-up of the Brasada plant in June 2013, and an increase in volumes at the Red Desert complex due to additional well connections during the period. In addition, for the nine months ended September 30, 2013 , increased volumes processed at a plant included in the MGR acquisition (“the Granger straddle plant”) contributed to the increase. These increases were partially offset by a decrease in throughput at the Granger complex due to natural production declines in the area.

Equity investment volumes decrease d by 15 MMcf/d and 25 MMcf/d for the three and nine months ended September 30, 2013 , respectively, primarily due to lower throughput at the Fort Union system due to production declines in the area.

Natural Gas Gathering, Processing and Transportation Revenues



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Gathering, processing and transportation of natural gas and natural gas liquids	$	130,781	$	93,933	39	%	$	343,471	$	278,966	23	%

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Revenues from gathering, processing and transportation of natural gas and natural gas liquids increase d by $36.8 million for the three months ended September 30, 2013 , primarily due to increases of $9.1 million, $7.2 million, and $7.2 million at the Non-Operated Marcellus Interest, the Wattenberg system, and Chipeta, respectively, due to higher throughput, an increase of $6.1 million due to the start-up of the Brasada plant in June 2013, and an increase of $4.7 million due to the addition of the Anadarko-Operated Marcellus Interest beginning in March 2013.

Revenues from gathering, processing and transportation of natural gas and natural gas liquids increase d by $64.5 million for the nine months ended September 30, 2013 , primarily due to increases of $21.6 million, $17.4 million, and $12.0 million at the Non-Operated Marcellus Interest, the Wattenberg system, and Chipeta, respectively, all due to higher throughput, an increase of $8.1 million due to the addition of the Anadarko-Operated Marcellus Interest beginning in March 2013, and an increase of $6.9 million due to the start-up of the Brasada plant in June 2013.

Natural Gas, Natural Gas Liquids and Condensate Sales



thousands except percentages and per-unit amounts	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages and per-unit amounts	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Natural gas sales	$	30,034	$	24,223	24	%	$	85,025	$	73,524	16	%
Natural gas liquids sales	104,535		105,124		(1	)%	294,133		291,293		1	%
Drip condensate sales	6,757		6,759		—	%	23,458		22,001		7	%
Total	$	141,326	$	136,106	4	%	$	402,616	$	386,818	4	%
Average price per unit:
Natural gas (per Mcf)	$	5.06	$	4.21	20	%	$	4.53	$	4.19	8	%
Natural gas liquids (per Bbl)	$	48.09	$	48.80	(1	)%	$	47.65	$	47.89	(1	)%
Drip condensate (per Bbl)	$	76.69	$	75.13	2	%	$	76.18	$	75.78	1	%

Including the effects of commodity price swap agreements, total natural gas, natural gas liquids and condensate sales increase d by $5.2 million for the three months ended September 30, 2013 , which consisted of a $5.8 million increase in natural gas sales and a $0.6 million decrease in NGLs sales.

For the three months ended September 30, 2013 , natural gas sales increase d primarily due to a 20% increase in the overall sales price of natural gas and increased sales volumes resulting from higher throughput at the Wattenberg system, the Red Desert complex, and the Hilight system, partially offset by a decrease at the Granger complex due to lower volumes sold as a result of a decline in throughput and by a decrease at the Platte Valley system due to a gas flow change that became effective in July 2013, whereby volumes previously processed under percentage-of-proceeds contracts are now processed under fee-based agreements.

The decline in NGLs sales for the three months ended September 30, 2013 , was primarily due to a decrease of $6.8 million at Chipeta due to a decrease in average price, partially offset by an increase in volume, a decrease of $5.3 million at the Platte Valley system due to the gas flow change described above, and a decrease of $1.9 million at the Granger complex due to lower volumes sold as a result of declines in throughput. These decreases were partially offset by increases of $6.2 million, $4.9 million and $2.1 million at the Hilight system, the Wattenberg system and the Red Desert complex, respectively, due to higher volumes sold as a result of increased throughput.

Including the effects of commodity price swap agreements, total natural gas, natural gas liquids and condensate sales increase d by $15.8 million for the nine months ended September 30, 2013 , which consisted of an $11.5 million increase in sales of natural gas, a $2.8 million increase in NGLs sales and a $1.5 million increase in drip condensate sales.

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For the nine months ended September 30, 2013 , natural gas sales increased primarily due to an 8% increase in the overall sales price of natural gas and higher sales volumes at the Red Desert complex and the Wattenberg system. These increases were partially offset by a decrease at the Granger complex due to a decrease in volumes sold as a result of decreased throughput.

The growth in NGLs sales for the nine months ended September 30, 2013 , was primarily due to increases of $15.4 million, $8.5 million, $4.9 million and $4.0 million resulting from higher volumes processed and sold at the Red Desert complex, the Hilight system, the Wattenberg system and the Granger straddle plant, respectively. These increases were partially offset by a decrease of $16.5 million at Chipeta (with a corresponding decrease in cost of product), a decrease of $8.8 million at the Granger complex due to a decrease in volumes sold as a result of decreased throughput, and a decrease of $5.8 million at the Platte Valley system due to the aforementioned gas flow changes.

The growth in drip condensate sales for the nine months ended September 30, 2013 was primarily due to a $1.6 million increase at the Wattenberg system due to an increase in condensate volumes sold as a result of increased throughput.

For the three and nine months ended September 30, 2013 and 2012 , average natural gas, NGL and drip condensate prices include the effects of commodity price swap agreements attributable to sales for the Granger, Hilight, Newcastle, Hugoton and Wattenberg systems, and the MGR assets. See Note 5—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Equity Income and Other Revenues



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Equity income	$	4,501	$	3,804	18	%	$	12,205	$	10,752	14	%
Other revenues, net	1,393		891		56	%	4,582		3,184		44	%
Total	$	5,894	$	4,695	26	%	$	16,787	$	13,936	20	%

For the three and nine months ended September 30, 2013 , equity income increase d by $0.7 million and $1.5 million , respectively, primarily due to volume increases at White Cliffs, partially offset by a decrease in income due to lower volumes at Fort Union.

Other revenues, net increase d by $0.5 million and $1.4 million for the three and nine months ended September 30, 2013 , respectively, primarily due to the collection of deficiency fees associated with volume commitments at Chipeta.

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Cost of Product and Operation and Maintenance Expenses



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Cost of product	$	93,516	$	89,107	5	%	$	270,059	$	254,719	6	%
Operation and maintenance	42,757		35,493		20	%	121,165		103,304		17	%
Total cost of product and operation and maintenance expenses	$	136,273	$	124,600	9	%	$	391,224	$	358,023	9	%

Including the effects of commodity price swap agreements on purchases, cost of product expense for the three months ended September 30, 2013 , increase d by $4.4 million primarily due to the volume fluctuations noted in Throughput and Natural Gas, Natural Gas Liquids and Condensate Sales within this Item 2, resulting in the following:


•	a $3.7 million net increase in residue purchases primarily at the Wattenberg system, the Red Desert complex, and the Hilight system, partially offset by decreases at the Platte Valley system and the Granger complex;


•	a $0.7 million increase due to changes in imbalance positions; and


•	a $1.5 million net decrease in NGL purchases primarily at Chipeta, the Platte Valley system, and the Granger complex, partially offset by increases at the Hilight system, the Red Desert complex, and the Wattenberg system.

Including the effects of commodity price swap agreements on purchases, cost of product expense for the nine months ended September 30, 2013 , increase d by $15.3 million primarily due to the volume fluctuations noted in Throughput and Natural Gas, Natural Gas Liquids and Condensate Sales within this Item 2, resulting in the following:


•	a $9.7 million net increase in residue purchases primarily at the Red Desert complex, the Wattenberg system, and the Granger straddle plant, partially offset by decreases at the Granger complex and the Hilight system; and


•	a $3.6 million net increase in NGL purchases primarily at the Red Desert complex, the Hilight system, and the Wattenberg system, partially offset by decreases at Chipeta, the Granger complex, and the Platte Valley system.

Cost of product expense for the three and nine months ended September 30, 2013 and 2012 , includes the effects of commodity price swap agreements attributable to purchases for the Granger, Hilight, Hugoton, Newcastle and Wattenberg systems, and the MGR assets. See Note 5—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Operation and maintenance expense increase d by $7.3 million for the three months ended September 30, 2013 , primarily due to a $4.0 million increase in plant repairs and maintenance and a $2.5 million increase in salaries, wages and payroll taxes, primarily at the Wattenberg system, Chipeta and the Brasada plant.

Operation and maintenance expense increase d by $17.9 million for the nine months ended September 30, 2013 , primarily due to an increase of $6.9 million in property, overhead and facility expense attributable to the Non-Operated Marcellus Interest. In addition, plant repairs and maintenance increased by $6.3 million, and salaries, wages, and payroll tax expense increased by $4.9 million, primarily at the Wattenberg system, Chipeta, the Hilight system and the Brasada plant.

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General and Administrative, Depreciation and Other Expenses



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
General and administrative	$	7,276	$	15,039	(52	)%	$	22,228	$	35,623	(38	)%
Property and other taxes	6,649		5,328		25	%	18,520		14,998		23	%
Depreciation, amortization and impairments	37,615		28,455		32	%	106,551		83,263		28	%
Total general and administrative, depreciation and other expenses	$	51,540	$	48,822	6	%	$	147,299	$	133,884	10	%

General and administrative expenses decrease d by $7.8 million and $13.4 million for the three and nine months ended September 30, 2013 , respectively, primarily due to a decrease of $8.6 million and $13.9 million, respectively, in non-cash compensation expenses attributable to the awards outstanding under the Western Gas Holdings, LLC Equity Incentive Plan, as amended and restated (the “Incentive Plan”), which were settled in December 2012 when the Incentive Plan terminated in conjunction with our IPO. These declines were partially offset by increases of $0.5 million and $1.3 million, respectively, in corporate and management personnel costs for which WES reimbursed Anadarko pursuant to the WES omnibus agreement.

For the three months ended September 30, 2013 , property and other taxes increase d by $1.3 million , primarily due to ad valorem tax increases of $0.8 million associated with capital additions at the Wattenberg system and Chipeta and $0.3 million due to the completion of the Brasada plant in June 2013. For the nine months ended September 30, 2013 , property and other taxes increase d by $3.5 million , primarily due to ad valorem tax increases of $2.6 million associated with capital additions at the Platte Valley and Wattenberg systems and $0.8 million due to the completion of the Brasada plant in June 2013.

For the three months ended September 30, 2013 , depreciation, amortization and impairments increase d by $9.2 million , primarily attributable to a $3.2 million increase in depreciation expense associated with capital projects completed at the Wattenberg system, Chipeta, and the Hilight system, a $2.4 million increase in depreciation expense related to the completion of the Brasada plant in June 2013, a $1.7 million increase in depreciation expense associated with the Non-Operated Marcellus Interest, and a $1.2 million increase in depreciation expense associated with the March 2013 acquisition of the Anadarko-Operated Marcellus Interest.

For the nine months ended September 30, 2013 , depreciation, amortization and impairments increase d by $23.3 million , primarily attributable to a $10.1 million increase in depreciation expense associated with capital projects completed at the Wattenberg system, Chipeta, and the Platte Valley and Hilight systems, a $5.5 million increase in depreciation and impairment expense associated with the Non-Operated Marcellus Interest, a $3.7 million increase in depreciation expense related to the completion of the Brasada plant in June 2013, and a $2.7 million increase in depreciation expense associated with the March 2013 acquisition of the Anadarko-Operated Marcellus Interest.

Interest Income, Net – Affiliates and Interest Expense

Amortization of debt issuance costs and commitment fees in the table below includes amortization of (i) the original issue discount for the June 2012 offering of $520.0 million aggregate principal amount of 4.000% Senior Notes due 2022, (ii) the original issue premium for the October 2012 offering of an additional $150.0 million in aggregate principal amount of 4.000% Senior Notes due 2022, (iii) the original issue discount for the $500.0 million aggregate principal amount of 5.375% Senior Notes due 2021 (the “2021 Notes”), (iv) the original issue discount for the August 2013 offering of $250.0 million aggregate principal amount of 2.600% Senior Notes due 2018 (the “2018 Notes”), and (v) underwriters’ fees. The October 2012 notes and the June 2012 notes were issued under the same indenture and are considered a single class of securities, collectively referred to as the “2022 Notes.”



	Three Months Ended September 30,								Nine Months Ended September 30,
thousands except percentages	2013			2012			Inc/ (Dec)		2013			2012			Inc/ (Dec)
Interest income on note receivable	$	4,225		$	4,225		—	%	$	12,675		$	12,675		—	%
Interest income, net – affiliates	$	4,225		$	4,225		—	%	$	12,675		$	12,675		—	%
Third parties
Interest expense on long-term debt	$	(14,994	)	$	(11,919	)	26	%	$	(43,783	)	$	(28,036	)	56	%
Amortization of debt issuance costs and commitment fees ⁽¹⁾	(1,135		)	(1,201		)	(5	)%	(3,252		)	(3,225		)	1	%
Capitalized interest	3,111			2,224			40	%	9,552			3,827			150	%
Affiliates
Interest expense on WES note payable to Anadarko ⁽²⁾	—			—			—	%	—			(2,440		)	(100	)%
Interest expense on affiliate balances ⁽³⁾	—			(81		)	(100	)%	—			(244		)	(100	)%
Interest expense	$	(13,018	)	$	(10,977	)	19	%	$	(37,483	)	$	(30,118	)	24	%

⁽¹⁾

For the three and nine months ended September 30, 2013 , includes $0.3 million and $0.8 million , respectively, of amortization of debt issuance costs and underwriters’ fees for the 2022 Notes, the 2021 Notes, and the 2018 Notes. For the three and nine months ended September 30, 2012 , includes $0.4 million and $0.8 million , respectively, of amortization of debt issuance costs and underwriters’ fees for the 2022 Notes issued in June 2012 and the 2021 Notes.


⁽²⁾	In June 2012, the WES note payable to Anadarko was repaid in full. See Note 8—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

⁽³⁾

Imputed interest expense on the reimbursement payable to Anadarko for certain expenditures incurred in 2011 related to the construction of the Brasada and Lancaster plants. In the fourth quarter of 2012, WES repaid the reimbursement payable to Anadarko associated with the construction of the Brasada and Lancaster plants. See Note 5—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Interest expense increase d by $2.0 million and $7.4 million for the three and nine months ended September 30, 2013 , respectively, primarily due to interest expense incurred on the 2022 Notes of $1.5 million and $14.7 million, respectively, as well as interest incurred on the 2018 Notes of $0.8 million for both the three and nine months ended September 30, 2013 . In addition, interest expense increased on the WES RCF by $0.7 million and $0.2 million, respectively, for the three and nine months ended September 30, 2013 , primarily due to greater average outstanding borrowings in the current period. However, for the nine months ended September 30, 2013 , the increase in interest expense was partially offset by a decrease of $2.4 million attributable to the repayment of the note payable to Anadarko in June 2012. See Note 8—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Also partially offsetting the increases in interest expense for the three and nine months ended September 30, 2013 , were increases of capitalized interest of $0.9 million and $5.7 million, respectively, associated with the expansion of the Lancaster plant and construction of the two Mont Belvieu fractionators. The increase in capitalized interest for the nine months ended September 30, 2013 , also included interest associated with the construction of the Brasada plant which was completed in June 2013.

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Other Income (Expense), Net



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012			Inc/ (Dec)
Other income (expense), net	$	439	$	522	(16	)%	$	1,612	$	(287	)	n/m ⁽¹⁾


⁽¹⁾	Percent change is considered not meaningful (“nm”).

For the three and nine months ended September 30, 2013 and 2012 , other income (expense), net included $0.4 million and $1.2 million , respectively, of interest income related to the capital lease component of a processing agreement assumed in connection with the MGR acquisition. In addition, for the three and nine months ended September 30, 2013 , other income (expense), net included $0.1 million and $ 0.4 million, respectively, of interest earned on overnight investments. For the nine months ended September 30, 2012 , other income (expense), net also included a realized loss of $1.7 million resulting from U.S. Treasury Rate lock agreements settled simultaneously with WES’s June 2012 offering of the 2022 Notes. See Note 8—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Income Tax Expense



	Three Months Ended September 30,								Nine Months Ended September 30,
thousands except percentages	2013			2012			Inc/ (Dec)		2013			2012			Inc/ (Dec)
Income before income taxes	$	81,834		$	55,082		49	%	$	201,155		$	170,083		18	%
Income tax expense	58			5,080			(99	)%	4,431			14,588			(70	)%
Effective tax rate	—		%	9		%			2		%	9		%

WES is not a taxable entity for U.S. federal income tax purposes; however, WES’s 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 WES assets acquired from Anadarko, and WES’s share of Texas margin tax.

Income attributable to (a) the Non-Operated Marcellus Interest prior to and including March 2013 and (b) the MGR assets prior to and including January 2012 was subject to federal and state income tax. Income earned by the Non-Operated Marcellus Interest and MGR assets for periods subsequent to March 2013 and January 2012, respectively, was only subject to Texas margin tax on income apportionable to Texas.

Noncontrolling Interests



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Net income attributable to noncontrolling interests	$	3,376	$	3,423	(1	)%	$	7,467	$	11,956	(38	)%

For the nine months ended September 30, 2013 , net income attributable to noncontrolling interests decreased by $4.5 million , primarily due to WES’s acquisition of Anadarko’s then remaining 24% membership interest in Chipeta in August 2012. See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

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KEY PERFORMANCE METRICS



thousands except percentages and gross margin per Mcf	Three Months Ended September 30,						Nine Months Ended September 30,
thousands except percentages and gross margin per Mcf	2013		2012		Inc/ (Dec)		2013		2012		Inc/ (Dec)
Gross margin	$	184,485	$	145,627	27	%	$	492,815	$	425,001	16	%
Gross margin per Mcf ⁽¹⁾	0.58		0.52		12	%	0.55		0.51		8	%
Gross margin per Mcf attributable to Western Gas Partners, LP ⁽²⁾	0.59		0.54		9	%	0.57		0.54		6	%
Adjusted EBITDA attributable to Western Gas Partners, LP ⁽³⁾	125,174		97,494		28	%	328,749		279,813		17	%
Distributable cash flow ⁽³⁾	$	105,881	$	74,778	42	%	$	274,794	$	229,429	20	%

⁽¹⁾

Average for period. Calculated as gross margin (total revenues less cost of product) divided by total throughput (excluding throughput measured in barrels), including 100% of gross margin and volumes attributable to Chipeta, WES’s 14.81% interest in income and volumes attributable to Fort Union and WES’s 22% interest in income and volumes attributable to Rendezvous. Gross margin also includes 100% of gross margin attributable to WES’s NGL pipelines and WES’s 10% interest in income attributable to White Cliffs.


⁽²⁾	Calculated as described in footnote one above, except also excludes the noncontrolling interest owners’ proportionate share of revenues, cost of product and throughput.


⁽³⁾	For reconciliations of Adjusted EBITDA and Distributable cash flow to their most directly comparable financial measures calculated and presented in accordance with GAAP, please read the descriptions below under the captions Adjusted EBITDA , Distributable cash flow and Reconciliation to GAAP measures .

Gross margin and Gross margin per Mcf. Gross margin increase d by $38.9 million and $67.8 million for the three and nine months ended September 30, 2013 , respectively, primarily due to higher margins at the Non-Operated Marcellus Interest, the Wattenberg system, the Anadarko-Operated Marcellus Interest, Chipeta, and the start-up of the Brasada plant in June 2013.

Gross margin per Mcf increase d by $0.06 and $0.04 for the three and nine months ended September 30, 2013 , respectively, primarily due to higher margins and increases in throughput at Chipeta, the Wattenberg system, and the Non-Operated Marcellus Interest, as well as overall changes in the throughput mix of WES’s portfolio.

Adjusted EBITDA. WES defines “Adjusted EBITDA” as net income attributable to Western Gas Partners, LP, plus distributions from equity investees, non-cash equity-based compensation expense, interest expense, income tax expense, depreciation, amortization and impairments, and other expense, less income from equity investments, interest income, income tax benefit, and other income. WES believes that the presentation of Adjusted EBITDA provides information useful to investors in assessing its 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 WES’s management and external users of WES’s consolidated financial statements, such as industry analysts, investors, commercial banks and rating agencies, use to assess the following, among other measures:


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


•	the ability of WES’s 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.

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Adjusted EBITDA increase d by $27.7 million for the three months ended September 30, 2013 , primarily due to a $42.6 million increase in total revenues excluding equity income. This amount was offset by a $7.3 million increase in operation and maintenance expenses, a $4.4 million increase in cost of product, a $1.3 million increase in property and other tax expense, and a $1.1 million decrease in distributions from equity investees.

Adjusted EBITDA increase d by $48.9 million for the nine months ended September 30, 2013 , primarily due to an $81.7 million increase in total revenues excluding equity income and a $4.5 million decrease in net income attributable to noncontrolling interest. These amounts were offset by a $17.9 million increase in operation and maintenance expenses, a $15.3 million increase in cost of product, and a $3.5 million increase in property and other tax expense.

Distributable cash flow. WES defines “Distributable cash flow” as Adjusted EBITDA, plus interest income, less net cash 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. WES compares Distributable cash flow to the cash distributions WES expects to pay its unitholders. Using this measure, WES’s management can quickly compute the Coverage ratio of distributable cash flow to planned cash distributions. WES believes 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 WES’s operating and financial performance and compare it with the performance of other publicly traded partnerships.

While Distributable cash flow is a measure WES uses to assess its ability to make distributions to its unitholders, it should not be viewed as indicative of the actual amount of cash that WES has available for distributions or that it plans to distribute for a given period.

Distributable cash flow increase d by $31.1 million for the three months ended September 30, 2013 , primarily due to a $27.7 million increase in Adjusted EBITDA and a $6.0 million decrease in maintenance capital expenditures, offset by a $3.0 million increase in net cash paid for interest expense.

Distributable cash flow increase d by $45.4 million for the nine months ended September 30, 2013 , primarily due to a $48.9 million increase in Adjusted EBITDA and a $9.3 million decrease in maintenance capital expenditures, offset by a $13.3 million increase in net cash paid for interest expense.

Reconciliation to GAAP measures. Adjusted EBITDA and Distributable cash flow are not defined in GAAP. The GAAP measures most directly comparable to Adjusted EBITDA are net income attributable to Western Gas Partners, LP and net cash provided by operating activities, and the GAAP measure most directly comparable to Distributable cash flow is net income attributable to Western Gas Partners, LP. WES’s non-GAAP financial measures of Adjusted EBITDA and Distributable cash flow should not be considered as alternatives to the GAAP measures of net income attributable to Western Gas Partners, LP, net cash provided by operating activities or any other measure of financial performance presented in accordance with GAAP. Adjusted EBITDA and Distributable cash flow have important limitations as analytical tools because they exclude some, but not all, items that affect net income and net cash provided by operating activities. Adjusted EBITDA and Distributable cash flow should not be considered in isolation or as a substitute for analysis of WES’s results as reported under GAAP. WES’s definitions of Adjusted EBITDA and Distributable cash flow may not be comparable to similarly titled measures of other companies in WES’s industry, thereby diminishing their utility.

WES’s management compensates for the limitations of Adjusted EBITDA and Distributable cash flow as analytical tools by reviewing the comparable GAAP measures, understanding the differences between Adjusted EBITDA and Distributable cash flow compared to (as applicable) net income and net cash provided by operating activities, and incorporating this knowledge into its decision-making processes. WES believes that investors benefit from having access to the same financial measures that its management uses in evaluating its operating results.

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The following tables present (a) a reconciliation of the non-GAAP financial measure of Adjusted EBITDA to the GAAP financial measures of net income attributable to Western Gas Partners, LP and net cash provided by operating activities, and (b) a reconciliation of the non-GAAP financial measure of Distributable cash flow to the GAAP financial measure of net income attributable to Western Gas Partners, LP:



	Three Months Ended September 30,						Nine Months Ended September 30,
thousands	2013			2012			2013			2012
Reconciliation of Adjusted EBITDA to Net income attributable to Western Gas Partners, LP
Adjusted EBITDA attributable to Western Gas Partners, LP	$	125,174		$	97,494		$	328,749		$	279,813
Less:
Distributions from equity investees	4,531			5,584			15,563			15,603
Non-cash equity-based compensation expense	962			9,417			2,663			16,407
Interest expense	13,018			10,977			37,483			30,118
Income tax expense	58			5,080			4,431			14,588
Depreciation, amortization and impairments ⁽¹⁾	36,970			28,011			104,651			81,507
Other expense ⁽¹⁾	—			—			—			1,665
Add:
Equity income, net	4,501			3,804			12,205			10,752
Interest income, net – affiliates	4,225			4,225			12,675			12,675
Other income ^{(1) (2)}	39			125			419			187
Net income attributable to Western Gas Partners, LP	$	78,400		$	46,579		$	189,257		$	143,539

Reconciliation of Adjusted EBITDA to Net cash provided by operating activities
Adjusted EBITDA attributable to Western Gas Partners, LP	$	125,174		$	97,494		$	328,749		$	279,813
Adjusted EBITDA attributable to noncontrolling interests	4,017			3,866			9,362			13,709
Interest income (expense), net	(8,793		)	(6,752		)	(24,808		)	(17,443		)
Non-cash equity based compensation expense	(80		)	(8,482		)	(99		)	(13,638		)
Debt-related amortization and other items, net	630			698			1,756			1,728
Current income tax expense	(80		)	646			(3,224		)	6,977
Other income (expense), net ⁽²⁾	43			126			424			(1,475		)
Distributions from equity investees less than (in excess of) equity income, net	(30		)	(1,780		)	(3,358		)	(4,851		)
Changes in operating working capital:
Accounts receivable and natural gas imbalance receivable	(1,304		)	34,817			(28,425		)	47,403
Accounts payable, accrued liabilities and natural gas imbalance payable	6,482			39,209			6,818			29,261
Other	(2,003		)	(2,441		)	1,874			2,103
Net cash provided by operating activities	$	124,056		$	157,401		$	289,069		$	343,587

Cash flow information of Western Gas Partners, LP
Net cash provided by operating activities							$	289,069		$	343,587
Net cash used in investing activities							$	(1,226,404	)	$	(1,009,296	)
Net cash provided by financing activities							$	555,718		$	486,644


⁽¹⁾	Includes WES’s 51% share prior to August 1, 2012, and its 75% share after August 1, 2012, of depreciation, amortization and impairments; other expense; and other income attributable to Chipeta. See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.


⁽²⁾	Excludes income of $0.4 million and $1.2 million for each of the three and nine months ended September 30, 2013 and 2012 , respectively, related to a component of a gas processing agreement accounted for as a capital lease. See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

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	Three Months Ended September 30,					Nine Months Ended September 30,
thousands except Coverage ratio	2013			2012		2013			2012
Reconciliation of Distributable cash flow to Net income attributable to Western Gas Partners, LP and calculation of the Coverage ratio
Distributable cash flow	$	105,881		$	74,778	$	274,794		$	229,429
Less:
Distributions from equity investees	4,531			5,584		15,563			15,603
Non-cash equity-based compensation expense	962			9,417		2,663			16,407
Interest expense, net (non-cash settled)	—			81		—			244
Income tax expense	58			5,080		4,431			14,588
Depreciation, amortization and impairments ⁽¹⁾	36,970			28,011		104,651			81,507
Other expense ⁽¹⁾	—			—		—			1,665
Add:
Equity income, net	4,501			3,804		12,205			10,752
Cash paid for maintenance capital expenditures ^{(1) (3)}	7,389			13,398		19,595			28,863
Capitalized interest	3,111			2,224		9,552			3,827
Cash paid for income taxes	—			423		—			495
Other income ^{(1) (2)}	39			125		419			187
Net income attributable to Western Gas Partners, LP	$	78,400		$	46,579	$	189,257		$	143,539

Distributions declared ⁽⁴⁾
Limited partners	$	65,181				$	184,734
General partner	18,805					48,710
Total	$	83,986				$	233,444
Coverage ratio	1.26		x			1.18		x


⁽¹⁾	Includes WES’s 51% share prior to August 1, 2012, and its 75% share after August 1, 2012, of depreciation, amortization and impairments; other expense; cash paid for maintenance capital expenditures; and other income attributable to Chipeta. See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.


⁽²⁾	Excludes income of $0.4 million and $1.2 million for each of the three and nine months ended September 30, 2013 and 2012 , respectively, related to a component of a gas processing agreement accounted for as a capital lease. See Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.


⁽³⁾	Net of a prior period adjustment reclassifying $0.7 million from capital expenditures to operating expenses for the nine months ended September 30, 2012 .


⁽⁴⁾	Reflects WES distributions of $0.58 and $1.68 per unit declared for the three and nine months ended September 30, 2013 , respectively.

LIQUIDITY AND CAPITAL RESOURCES

WES’s primary cash requirements are for acquisitions and other capital expenditures, debt service, customary operating expenses, quarterly distributions to its limited partners and general partner, and distributions to its noncontrolling interest owner. WES’s sources of liquidity as of September 30, 2013 , included cash and cash equivalents, cash flows generated from operations, including interest income on WES’s $260.0 million note receivable from Anadarko, available borrowing capacity under the WES RCF, and issuances of additional equity or debt securities. WES believes that cash flows generated from these sources will be sufficient to satisfy its short-term working capital requirements and long-term maintenance and expansion capital expenditure requirements. The amount of future distributions to unitholders will depend on its results of operations, financial condition, capital requirements and other factors, and will be determined by the board of directors of its general partner on a quarterly basis. Due to WES’s cash distribution policy, WES expects to rely on external financing sources, including equity and debt issuances, to fund expansion capital expenditures and future acquisitions. However, to limit interest expense, WES may use operating cash flows to fund expansion capital expenditures or acquisitions, which could result in subsequent borrowings under the WES RCF to pay distributions or fund other short-term working capital requirements.

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WES has made cash distributions to its unitholders each quarter since its IPO and has increased its quarterly distribution each quarter since the second quarter of 2009. On October 16, 2013 , the board of directors of WES GP declared a cash distribution to WES unitholders of $0.58 per unit, which equates to $84.0 million in aggregate including incentive distributions. The cash distribution is payable on November 12, 2013 , to WES unitholders of record at the close of business on October 31, 2013.

WES’s management continuously monitors its leverage position and coordinates its capital expenditure program, quarterly distributions and acquisition strategy with its expected cash flows and projected debt-repayment schedule. WES 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. To facilitate a potential debt or equity securities issuance, WES has the ability to sell securities under its shelf registration statements. WES’s ability to generate cash flows is subject to a number of factors, some of which are beyond its control. Please read Part II, Item 1A— Risk Factors of this Form 10-Q.

Working capital . As of September 30, 2013 , WES had a $55.0 million working capital deficit, which it defines 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, WES’s customers, and the level and timing of its spending for maintenance and expansion activity. WES’s working capital deficit as of September 30, 2013 , was primarily due to its use of $215.5 million of cash on hand to fund the Non-Operated Marcellus Interest acquisition on March 1, 2013 and $78.1 million of cash on hand to fund the Mont Belvieu JV acquisition on June 5, 2013. As of September 30, 2013 , WES had $687.2 million available for borrowing under its $800.0 million RCF. In addition, we have availability under our $30.0 million WGP WCF. See Note 8—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Capital expenditures . WES’s business is capital intensive, requiring significant investment to maintain and improve existing facilities or develop new midstream infrastructure. WES categorizes 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 WES’s 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 in order to extend the useful lives of WES’s assets, reduce costs, increase revenues or increase system throughput or capacity from current levels, including well connections that increase existing system throughput.

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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. WES’s capital expenditures as presented in the consolidated statements of cash flows and capital incurred were as follows:



	Nine Months Ended September 30,
thousands	2013		2012
Acquisitions	$	710,158	$	605,960

Expansion capital expenditures	$	450,107	$	374,338
Maintenance capital expenditures	19,571		29,611
Total capital expenditures ⁽¹⁾	$	469,678	$	403,949

Capital incurred ⁽²⁾	$	458,236	$	450,989

⁽¹⁾

Capital expenditures for the nine months ended September 30, 2013 , included $8.0 million of capitalized interest. Capital expenditures included the noncontrolling interest owners’ share of Chipeta’s capital expenditures, funded by contributions from the noncontrolling interest owners for all periods presented. Capital expenditures for the nine months ended September 30, 2012 , included $105.8 million of pre-acquisition capital expenditures for the Non-Operated Marcellus Interest acquisition.

⁽²⁾

Capital incurred for the nine months ended September 30, 2013 , included $8.0 million of capitalized interest. Capital incurred for the nine months ended September 30, 2013 and 2012 , included $8.8 million and $109.6 million, respectively, of pre-acquisition capital incurred for the Non-Operated Marcellus Interest acquisition and included the noncontrolling interest owners’ share of Chipeta’s capital incurred, funded by contributions from the noncontrolling interest owners.

Acquisitions included the OTTCO acquisition in the third quarter of 2013, the Mont Belvieu JV acquisition in the second quarter of 2013, the Anadarko-Operated Marcellus Interest acquisition and the Non-Operated Marcellus Interest acquisition in the first quarter of 2013, the acquisition of Anadarko’s then remaining 24% membership interest in Chipeta in the third quarter of 2012, and the MGR acquisition in the first quarter of 2012, as discussed in

Note 2—Acquisitions in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Capital expenditures, excluding acquisitions, increased by $65.7 million for the nine months ended September 30, 2013 . Expansion capital expenditures increased by $75.8 million (including a $4.2 million increase in capitalized interest) for the nine months ended September 30, 2013 , primarily due to an increase of $110.1 million related to the construction of the Brasada and Lancaster plants and a $54.8 million increase in expenditures at the Wattenberg and Hilight systems. These increases were partially offset by a $93.8 million decrease at Chipeta and the Non-Operated Marcellus Interest. Maintenance capital expenditures decreased by $10.0 million, primarily as a result of decreased expenditures of $9.4 million at the Wattenberg, Hilight, Haley, and Platte Valley systems and the Red Desert complex, partially offset by a $1.2 million increase at the Anadarko-Operated Marcellus Interest.

WES updated its estimated total capital expenditures for the year ended December 31, 2013, including its 75% share of Chipeta’s capital expenditures and excluding acquisitions, from an originally reported range of $550 million to $600 million, to a current range of $670 million to $740 million, to include the 2013 portion of expansion capital at Lancaster, as well as the additional expansion capital needed at both the Wattenberg and Hilight systems.

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



	Nine Months Ended September 30,
thousands	2013			2012
Net cash provided by (used in):
Operating activities	$	289,069		$	343,587
Investing activities	(1,226,404		)	(1,009,296		)
Financing activities	555,718			486,644
Net increase (decrease) in cash and cash equivalents	$	(381,617	)	$	(179,065	)

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Operating Activities . Net cash provided by operating activities during the nine months ended September 30, 2013 , was $289.1 million , compared to $343.6 million for the nine months ended September 30, 2012 . Operating cash flows decreased primarily due to the impact of changes in working capital items, partially offset by higher sales volumes and higher average natural gas prices. The impact of changes in working capital items was largely attributable to a decrease in the change in accrued interest expense due to interest paid on the 2022 Notes issued in the second half of 2012. Refer to Operating Results within this Item 2 for a discussion of WES’s results of operations as compared to the prior period.

Investing Activities . Net cash used in investing activities for the nine months ended September 30, 2013 , included the following:


•	$465.5 million of cash paid for the Non-Operated Marcellus Interest acquisition;


•	$469.7 million of capital expenditures;


•	$134.6 million of cash paid for the Anadarko-Operated Marcellus Interest acquisition;


•	$78.1 million of cash paid for the Mont Belvieu JV acquisition;


•	$27.5 million of cash paid for the OTTCO acquisition;


•	$19.1 million of cash paid related to a White Cliffs expansion project anticipated to be completed in the first half of 2014;


•	$26.0 million of capital contributions to the Mont Belvieu JV to fund WES’s current share of construction costs for the fractionation facilities anticipated to be completed by the first quarter of 2014; and


•	$4.4 million of cash paid for equipment purchases from Anadarko.

Net cash used in investing activities for the nine months ended September 30, 2012 , included the following:


•	$458.6 million of cash paid for the MGR acquisition;


•	$403.9 million of capital expenditures;


•	$128.3 million of cash paid for Anadarko’s then remaining 24% membership interest in Chipeta; and


•	$18.9 million of cash paid for equipment purchases from Anadarko.

Financing Activities . Net cash provided by financing activities for the nine months ended September 30, 2013 , included the following:


•	$424.7 million of net proceeds from the WES May 2013 equity offering, including net proceeds from the issuance of general partner units to WES GP to maintain its 2.0% general partner interest, $245.0 million of which was used to repay a portion of the outstanding borrowings under the WES RCF;


•	$250.0 million of borrowings to fund the Non-Operated Marcellus Interest acquisition;


•	$247.6 million of net proceeds from the WES 2018 Notes offering in August 2013, after underwriting and original issue discounts and offering costs, all of which was used to repay a portion of the outstanding borrowings under the WES RCF;


•	$133.5 million of borrowings to fund the Anadarko-Operated Marcellus Interest acquisition;


•	$184.0 million of borrowings to fund capital expenditures;


•	$27.5 million of borrowings to fund the OTTCO acquisition;


•	$2.6 million of net proceeds from activity under WES’s Continuous Offering Program (as defined and discussed in Registered Securities within this Item 2), including net proceeds from the issuance of general partner units to WES GP to maintain its 2.0% general partner interest; and


•	$0.5 million of net proceeds from the issuance of general partner units to WES GP to maintain its 2.0% general partner interest after WES common units were issued in conjunction with the Non-Operated Marcellus Interest acquisition.

Net contributions from Anadarko attributable to intercompany balances were $4.5 million during the nine months ended September 30, 2013 , representing intercompany transactions attributable to the Non-Operated Marcellus Interest acquisition.

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Net cash provided by financing activities for the nine months ended September 30, 2012 , included the following:


•	$511.3 million of net proceeds from the WES 2022 Notes offering in June 2012, after underwriting and original issue discounts and offering costs;


•	$299.0 million of borrowings to fund the MGR acquisition; and


•	$216.4 million of net proceeds from the WES June 2012 equity offering.

Proceeds from the WES 2022 Notes offering were used to repay amounts outstanding under the WES RCF and WES’s note payable to Anadarko. Net contributions from Anadarko attributable to intercompany balances were $60.3 million during the nine months ended September 30, 2012 , representing intercompany transactions attributable to the Non-Operated Marcellus Interest acquisition.

For the nine months ended September 30, 2013 and 2012 , WES paid $215.1 million and $141.5 million , respectively, of cash distributions to its unitholders. Contributions from noncontrolling interest owners of Chipeta totaled $2.2 million and $26.9 million during the nine months ended September 30, 2013 and 2012 , respectively, primarily for expansion of the cryogenic units and plant construction. Distributions to noncontrolling interest owners of Chipeta totaled $8.0 million and $14.3 million for the nine months ended September 30, 2013 and 2012 , respectively, representing the distributions paid as of September 30 of the respective year. Decreases in contributions by and distributions to noncontrolling interest owners of Chipeta were also impacted by WES’s August 2012 acquisition of Anadarko’s then remaining 24% membership interest in Chipeta.

Debt and credit facilities. As of September 30, 2013 , the carrying value of WES’s outstanding debt consisted of $249.7 million of the 2018 Notes, $673.4 million of the 2022 Notes, $495.0 million of the 2021 Notes and $100.0 million of the WES RCF. See Note 8—Debt and Interest Expense in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

WES Senior Notes . In August 2013, WES completed the offering of $250.0 million aggregate principal amount of the 2018 Notes at a price to the public of 99.879% of the face amount. Including the effects of the issuance and underwriting discounts, the effective interest rate is 2.806% . Interest will be paid semi-annually on February 15 and August 15 of each year, commencing on February 15, 2014. The 2018 Notes will mature on August 15, 2018, unless redeemed, in whole or in part, prior to maturity. Proceeds (net of underwriting discount of $1.5 million, original issue discount and debt issuance costs) were used to repay amounts then outstanding under the WES RCF.

In June 2012, WES completed the offering of $520.0 million aggregate principal amount of the 2022 Notes at a price to the public of 99.194% of the face amount. In October 2012, WES issued an additional $150.0 million in aggregate principal amount of the 2022 Notes at a price to the public of 105.178% of the face amount.

In May 2011, WES completed the offering of $500.0 million aggregate principal amount of the 2021 Notes at a price to the public of 98.778% of the face amount.

At September 30, 2013 , WES was in compliance with all covenants under the indentures governing the 2021 Notes, 2022 Notes and 2018 Notes.

WES note payable to Anadarko . In 2008, WES entered into a five-year $175.0 million term loan agreement with Anadarko. The interest rate was fixed at 2.82% prior to June 2012 when the note payable to Anadarko was repaid in full with proceeds from the June 2012 offering of the 2022 Notes.

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WES RCF. As of September 30, 2013 , WES had $100.0 million of outstanding borrowings and $12.8 million in outstanding letters of credit issued under the $800.0 million WES RCF. The interest rate was 1.68% and 1.71% at September 30, 2013 , and December 31, 2012 , respectively. WES is required to pay a quarterly facility fee currently ranging from 0.20% to 0.35% of the commitment amount (whether used or unused), based upon WES’s senior unsecured debt rating. The facility fee rate was 0.25% at September 30, 2013 , and December 31, 2012 . At September 30, 2013 , WES was in compliance with all covenants under the WES RCF.

WGP working capital facility. On November 1, 2012, we entered into the $30.0 million WGP WCF with Anadarko as the lender. The facility is available exclusively to fund our working capital borrowings. Borrowings under the facility will mature on November 1, 2017, and will bear interest at LIBOR plus 1.50%. The interest rate was 1.68% and 1.71% at September 30, 2013 , and December 31, 2012 , respectively.

We are required to reduce all borrowings under the WGP WCF to zero for a period of at least 15 consecutive days during the twelve month period commencing on November 1, 2012, and during the twelve month period commencing on each anniversary thereof. As of September 30, 2013 , we had no outstanding borrowings under the WGP WCF and were in compliance with all covenants under the WGP WCF.

Registered securities . WES may issue an indeterminate amount of common units and various debt securities under its effective shelf registration statements on file with the SEC.

In August 2012, WES filed a registration statement with the SEC authorizing the issuance of up to an aggregate of $125.0 million of WES common units, in amounts, at prices and on terms to be determined by market conditions and other factors at the time of the offerings (the “Continuous Offering Program”). See

Note 4—Equity and Partners’ Capital in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q for a discussion of trades initiated by WES under its Continuous Offering Program.

Credit risk . As stated above, our assets consist solely of ownership interests in WES. Accordingly, we are dependent upon WES’s ability to pay cash distributions to us. WES bears credit risk represented by its exposure to non-payment or non-performance by its 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 WES for services rendered or volumes owed pursuant to gas imbalance agreements. WES examines and monitors the creditworthiness of third-party customers and may establish credit limits for third-party customers. A substantial portion of WES’s throughput, however, comes from producers that have investment-grade ratings.

WES is dependent upon a single producer, Anadarko, for the substantial majority of its natural gas volumes, and WES does not maintain a credit limit with respect to Anadarko. Consequently, WES is subject to the risk of non-payment or late payment by Anadarko for gathering, processing and transportation fees and for proceeds from the sale of residue, NGLs and condensate to Anadarko.

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WES expects its exposure to concentrated risk of non-payment or non-performance to continue for as long as it remains substantially dependent on Anadarko for its revenues. Additionally, WES is exposed to credit risk on the note receivable from Anadarko, which was issued concurrently with the closing of its initial public offering. WES is also party to agreements with Anadarko under which Anadarko is required to indemnify WES 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. Finally, WES has entered into various commodity price swap agreements with Anadarko in order to reduce its exposure to commodity price risk and is subject to performance risk thereunder.

WES’s ability to make distributions to its unitholders may be adversely impacted if Anadarko becomes unable to perform under the terms of its gathering, processing and transportation agreements, natural gas and NGL purchase agreements, Anadarko’s note payable to WES, the WES omnibus agreement, the services and secondment agreement, contribution agreements or the commodity price swap agreements.

CONTRACTUAL OBLIGATIONS

WES’s contractual obligations include, among other things, a revolving credit facility, other third-party long-term debt, capital obligations related to its expansion projects and various operating leases. Refer to

Note 8—Debt and Interest Expense and Note 9—Commitments and Contingencies in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q for an update to WES’s contractual obligations as of September 30, 2013 , including, but not limited to, increases in committed capital.

OFF-BALANCE SHEET ARRANGEMENTS

We do not have any off-balance sheet arrangements. WES does not have any off-balance sheet arrangements other than operating leases. The information pertaining to operating leases required for this item is provided under

Note 9—Commitments and Contingencies included in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity price risk. Certain of WES’s 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 and NGLs. Under percent-of-proceeds agreements, WES receives a specified percentage of the net proceeds from the sale of natural gas and NGLs. Under keep-whole agreements, WES keeps 100% of the NGLs produced, and the processed natural gas, or value of the gas, is returned to the producer. Since some of the gas is used and removed during processing, WES compensates the producer for this amount of gas by supplying additional gas or by paying an agreed-upon value for the gas utilized.

To mitigate WES’s exposure to changes in commodity prices as a result of the purchase and sale of natural gas, condensate or NGLs, WES currently has in place commodity price swap agreements with Anadarko expiring at various times through December 2016 . For additional information on the commodity price swap agreements, see

Note 5—Transactions with Affiliates in the Notes to Consolidated Financial Statements under Item 1 of this Form 10-Q.

In addition, pursuant to certain of WES’s contracts, WES retains and sells drip condensate that is recovered during the gathering of natural gas. As part of this arrangement, WES is required to provide a thermally equivalent volume of natural gas or the cash equivalent thereof to the shipper. Thus, WES’s revenues for this portion of WES’s contractual arrangement are based on the price received for the drip condensate, and WES’s costs for this portion of its contractual arrangement depend on the price of natural gas. Historically, drip condensate sells at a price representing a discount to the price of New York Mercantile Exchange, or NYMEX, West Texas Intermediate crude oil.

We consider WES’s exposure to commodity price risk associated with the above-described arrangements to be minimal given the existence of the commodity price swap agreements with Anadarko and the relatively small amount of WES’s operating income that is impacted by changes in market prices. Accordingly, WES does not expect a 10% increase or decrease in natural gas or NGL prices would have a material impact on WES’s operating income, financial condition or cash flows for the next twelve months, excluding the effect of natural gas imbalances described below.

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We also bear a limited degree of commodity price risk through an investment in WES with respect to settlement of WES’s natural gas imbalances that arise from differences in gas volumes received into WES’s systems and gas volumes delivered by WES to customers, as well as instances where WES’s actual liquids recovery or fuel usage varies from the contractually stipulated amounts. Natural gas volumes owed to or by WES 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 WES are valued at WES’s weighted average cost of natural gas as of the balance sheet dates and are settled in-kind. WES’s exposure to the impact of changes in commodity prices on outstanding imbalances depends on the timing of settlement of the imbalances.

Interest rate risk. Interest rates during the nine months ended September 30, 2013 , were low compared to historic rates. As of September 30, 2013 , there were no borrowings under the WGP WCF and WES had $100.0 million of outstanding borrowings under the WES RCF (both of which bear interest at a rate based on LIBOR). If interest rates rise, future financing costs could increase. A 10% change in LIBOR would have resulted in a nominal change in net income and the fair value of the borrowings under the WES RCF.

Additional variable rate debt may be incurred in the future, either under the WES RCF, WGP WCF 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 our general partner performed an evaluation of our disclosure controls and procedures as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (“Exchange Act”). Our disclosure controls and procedures are designed to ensure that information required to be disclosed by us in the reports that we file or submit 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 by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that our disclosure controls and procedures are effective as of September 30, 2013 .

Transition Period for Assessment of Internal Control Over Financial Reporting . Our most recent annual report filed on March 28, 2013, does not include a report of management’s assessment regarding internal control over financial reporting or an attestation report of our registered public accounting firm due to a transition period established by rules of the SEC for newly public companies.

Changes in Internal Control Over Financial Reporting . There has been no change in our internal control over financial reporting during the quarter ended September 30, 2013 , that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. Legal Proceedings

We are not engaged in any material litigation. WES is not a party to any legal, regulatory or administrative proceedings other than proceedings arising in the ordinary course of its business. WES’s management believes that there are no such proceedings for which final disposition could have a material adverse effect on its results of operations, cash flows or financial condition.

In July 2013, Kerr-McGee Gathering LLC, a WES subsidiary, entered into a consent order with the Colorado Department of Public Health and Environment relating to the failure to comply with certain terms of certain permits at its Frederick compression station and agreed to pay a penalty of approximately $125,000.

Item 1A. Risk Factors

Security holders and potential investors in our securities should carefully consider the risk factors under Part I, Item 1A set forth in our Form 10-K for the year ended December 31, 2012 , 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, 2012 , 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.

WES ’ s construction of new assets may not result in revenue increases and will be subject to regulatory, environmental, political, legal and economic risks, which could adversely affect WES ’ s, and therefore our, results of operations and financial condition.

One of the ways WES intends to grow its business is through the construction of new midstream assets. The construction of additions or modifications to WES’s existing systems and the construction of new midstream assets involve numerous regulatory, environmental, political and legal uncertainties that are beyond WES’s control. These uncertainties could also affect downstream assets which WES does not own or control, but which are critical to certain of its growth projects. Delays in the completion of new downstream assets, or the unavailability of existing downstream assets, due to environmental, regulatory or political considerations could have an adverse impact on the completion or utilization of WES’s growth projects. In addition, construction activities could be subject to state, county and local ordinances that restrict the time, place or manner in which those activities may be conducted. Construction projects may also require the expenditure of significant amounts of capital, and financing may not be available on terms economically acceptable to WES or at all. If WES undertakes these projects, they may not be completed on schedule, at the budgeted cost, or at all. Moreover, WES’s revenues may not increase immediately upon the expenditure of funds on a particular project. For instance, if WES expands a pipeline, the construction may occur over an extended period of time, yet WES will not receive any material increases in revenues until the project is completed. Moreover, WES could construct facilities to capture anticipated future growth in production in a region in which such growth does not materialize. Since WES is not engaged in the exploration for and development of natural gas and oil reserves, WES often does not have access to estimates of potential reserves in an area prior to constructing facilities in that area. To the extent WES relies on estimates of future production in its decision to construct additions to its systems, such estimates may prove to be inaccurate as a result of the numerous uncertainties inherent in estimating quantities of future production. As a result, new facilities may not be able to attract enough throughput to achieve WES’s expected investment return, which could adversely affect WES’s, and therefore our, results of operations and financial condition. In addition, WES may be required to obtain new rights-of-way in connection with the construction of additions to its existing assets. WES may be unable to obtain such rights-of-way and may, therefore, be unable to connect new natural gas volumes to its systems or capitalize on other attractive expansion opportunities. Additionally, it may become more expensive for WES to obtain new rights-of-way or to renew existing rights-of-way. If the cost of renewing existing or obtaining new rights-of-way increases, WES’s, and therefore our, cash flows could be adversely affected.

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Item 6. Exhibits

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



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).
2.3#		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).
2.5#		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).
2.7#		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).
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		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		Certificate of formation of Western Gas Equity Holdings, LLC (incorporated by reference to Exhibit 3.2 to the Western Gas Equity Partners, LP Registration Statement on Form S-1 filed on November 5, 2012, File No. 333-184763).
3.4		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).
3.5		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).
3.6		First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated May 14, 2008 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 14, 2008, File No. 001-34046).

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3.7		Amendment No. 1 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP dated December 19, 2008 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on December 24, 2008, File No. 001-34046).
3.8		Amendment No. 2 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated as of April 15, 2009 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on April 20, 2009, File No. 001-34046).
3.9		Amendment No. 3 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP dated July 22, 2009 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 23, 2009, File No. 001-34046).
3.10		Amendment No. 4 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP dated January 29, 2010 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on February 3, 2010, File No. 001-34046).
3.11		Amendment No. 5 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated August 2, 2010 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 5, 2010, File No. 001-34046).
3.12		Amendment No. 6 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated July 8, 2011 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on July 8, 2011, File No. 001-34046).
3.13		Amendment No. 7 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated January 13, 2012 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on January 17, 2012, File No. 001-34046).
3.14		Amendment No. 8 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated August 1, 2012 (incorporated by reference to Exhibit 3.10 to Western Gas Partners, LP’s Quarterly Report on Form 10-Q filed on August 2, 2012, File No. 001-34046).
3.15		Amendment No. 9 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated December 12, 2012 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on December 12, 2012, File No. 001-34046).
3.16		Amendment No. 10 to First Amended and Restated Agreement of Limited Partnership of Western Gas Partners, LP, dated March 1, 2013 (incorporated by reference to Exhibit 3.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on March 5, 2013, 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		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).
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 4.2 to Western Gas Partners, LP’s Current Report on Form 8-K filed on May 18, 2011, File No. 001-34046).
4.5		Fifth Supplemental Indenture, dated as of August 14, 2013, 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 August 14, 2013, File No. 001-34046).
4.6		Form of 4.000% Senior Notes due 2022 (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).
4.7		Form of 2.600% Senior Notes due 2018 (incorporated by reference to Exhibit 4.1 to Western Gas Partners, LP’s Current Report on Form 8-K filed on August 14, 2013, File No. 001-34046).

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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.
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.
32.1**		Certifications 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.

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

101.INS**		XBRL Instance Document
101.SCH**		XBRL Schema Document
101.CAL**		XBRL Calculation Linkbase Document
101.DEF**		XBRL Definition Linkbase Document
101.LAB**		XBRL Label Linkbase Document
101.PRE**		XBRL Presentation Linkbase Document

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SIGNATURES

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



	WESTERN GAS EQUITY PARTNERS, LP

November 7, 2013

	/s/ Donald R. Sinclair
	Donald R. Sinclair President and Chief Executive Officer Western Gas Equity Holdings, LLC (as general partner of Western Gas Equity Partners, LP)

November 7, 2013

	/s/ Benjamin M. Fink
	Benjamin M. Fink Senior Vice President, Chief Financial Officer and Treasurer Western Gas Equity Holdings, LLC (as general partner of Western Gas Equity Partners, LP)

TABLE OF CONTENTS

Part I. Financial Information Item 1. Financial Statements Item 2. Management S Discussion and Analysis Of Financial Condition and Results Of Operations Note 1 Description Of Business and Basis Of Presentation Note 2 Acquisitions Note 5 Transactions with Affiliates Note 8 Debt and Interest Expense Note 4 Equity and Partners Capital Note 9 Commitments and Contingencies Item 3. Quantitative and Qualitative Disclosures About Market Risk Item 4. Controls and Procedures Part II. Other Information Item 1. Legal Proceedings Item 1A. Risk Factors Item 6. Exhibits

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