10-Q

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 March 31, 2016



o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
		For the transition period from _____ to _____

Commission File Number: 001-32721

WESTERN REFINING, INC.

(Exact name of registrant as specified in its charter)



Delaware		20-3472415
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)

123 W. Mills Ave., Suite 200		79901
El Paso, Texas		(Zip Code)
(Address of principal executive offices)

Registrant’s telephone number, including area code: (915) 534-1400

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 o

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 o

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.



Large accelerated filer þ	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o

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

As of April 29, 2016, there were 91,276,677 shares outstanding, par value $0.01, of the registrant’s common stock.

WESTERN REFINING, INC. AND SUBSIDIARIES

INDEX



Part I. Financial Information	1

Item 1. Financial Statements (Unaudited)	1

Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015	1

Condensed Consolidated Statements of Operations for the Three Months Ended March 31, 2016 and 2015	2

Condensed Consolidated Statements of Comprehensive Income for the Three Months Ended March 31, 2016 and 2015	3

Condensed Consolidated Statements of Cash Flows for the Three Months Ended March 31, 2016 and 2015	4

Notes to Condensed Consolidated Financial Statements	5

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	41

Item 3. Quantitative and Qualitative Disclosure About Market Risk	65

Item 4. Controls and Procedures	66

Part II. Other Information	66

Item 1A. Risk Factors	66

Item 2. Unregistered Sale of Equity Securities and Use of Proceeds	67

Item 3. Defaults Upon Senior Securities	67

Item 4. Mine Safety Disclosures	67

Item 5. Other Information	67

Item 6. Exhibits	68

Signatures	69

EX-31.1
EX-31.2
EX-32.1
EX-32.2
EX-101

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Forward-Looking Statements

As provided by the safe harbor provisions of the Private Securities Litigation Reform Act of 1995, certain statements included throughout this Quarterly Report on Form 10-Q and in particular under the section entitled Part I — Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations relating to matters that are not historical fact should be deemed forward-looking statements that represent management’s beliefs and assumptions based upon currently available information. These forward-looking statements relate to matters such as our industry, including the regulation of our industry, business strategy, our proposal to acquire all of the publicly-held common units of Northern Tier Energy LP ("NTI") not presently held by us, future operations, our expectations for margins and crack spreads, seasonality, the discount between West Texas Intermediate ("WTI") crude oil and Dated Brent crude oil as well as the discount between WTI Cushing and WTI Midland crude oils, volatility of crude oil prices, additions to pipeline capacity in the Permian Basin and at Cushing, Oklahoma, pipeline access to advantaged crude oil, expected share repurchases and dividends, volatility in pricing of Renewable Identification Numbers ("RIN"), taxes, capital expenditures, liquidity and capital resources and other financial and operating information. Forward-looking statements also include those regarding the timing of completion of certain operational and maintenance improvements we are making at our refineries, future operational and refinery efficiencies and cost savings, timing of future maintenance turnarounds, the amount or sufficiency of future cash flows and earnings growth, future expenditures, future contributions related to pension and postretirement obligations, our ability to manage our inventory price exposure through commodity hedging instruments, the impact upon our business of existing and future state and federal regulatory requirements, environmental loss contingency accruals, projected remediation costs or requirements and the expected outcomes of legal proceedings in which we are involved. We have used the words “anticipate,” “assume,” “believe,” “budget,” “continue,” “could,” “estimate,” “expect,” “forecast,” “intend,” “may,” “plan,” “position,” “potential,” “predict,” “project,” “strategy,” “will,” “future” and similar terms and phrases to identify forward-looking statements in this report.

Forward-looking statements reflect our current expectations regarding future events, results or outcomes. These expectations may or may not be realized. Some of these expectations may be based upon assumptions or judgments that prove to be incorrect or that are affected by unknown risks or uncertainties. Consequently, no forward-looking statements can be guaranteed. In addition, our business and operations involve numerous risks and uncertainties, many that are beyond our control, that could result in our expectations not being realized or otherwise materially affect our financial condition, results of operations and cash flows.

When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this quarterly report on Form 10-Q. Actual events, results and outcomes may differ materially from our expectations due to a variety of factors. Although it is not possible to predict or identify all of these factors, they include, among others, the following:


•	the possibility that the proposed merger with NTI is not consummated in a timely manner or at all;


•	the diversion of management in connection with the proposed merger with NTI and our ability to realize the anticipated benefits of the proposed merger with NTI;


•	availability, costs and price volatility of crude oil, other refinery feedstocks and refined products;


•	the successful integration and future performance of acquired assets, businesses or third-party product supply, and the possibility that expected synergies may not be achieved;


•	the impact on us of increased levels and cost of indebtedness used to fund our proposed merger with NTI or the cash portion of the merger consideration and increased cost of existing indebtedness due to the actions taken to consummate the merger with NTI;


•	our ability to obtain debt or equity financing on satisfactory terms to fund additional acquisitions, expansion projects, working capital requirements and the repayment or refinancing of indebtedness;


•	changes in crack spreads;


•	changes in the spread between WTI crude oil and West Texas Sour crude oil, also known as the sweet/sour spread;


•	changes in the spread between WTI crude oil and Dated Brent crude oil;


•	changes in the spread between WTI Cushing crude oil and WTI Midland crude oil;


•	effects of and exposure to risks related to our commodity hedging strategies and transactions;


•	availability and costs of renewable fuels for blending and RINs to meet Renewable Fuel Standards ("RFS") obligations;


•	construction of new or expansion of existing product or crude pipelines by us or our competitors, including in the Permian Basin, the San Juan Basin and at Cushing, Oklahoma;

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•	changes in the underlying demand for our refined products;


•	instability and volatility in the financial markets, including as a result of potential disruptions caused by economic uncertainties, commodity price fluctuations and expectations for changes in interest rates;


•	a potential economic recession in the United States and/or abroad;


•	adverse changes in the credit ratings assigned to our and our subsidiaries' debt instruments;


•	changes in the availability and cost of capital;


•	actions of customers and competitors;


•	actions of third-party operators, processors and transporters;


•	changes in fuel and utility costs incurred by our refineries;


•	the effect of weather-related problems upon our operations;


•	disruptions due to equipment interruption, pipeline disruptions or failure at our or third-party facilities;


•	execution of planned capital projects, cost overruns relating to those projects and failure to realize the expected benefits from those projects;


•	effects of and costs relating to compliance with current and future local, state and federal environmental, economic, climate change, safety, tax and other laws, policies and regulations and enforcement initiatives;


•	rulings, judgments or settlements in litigation, tax or other legal or regulatory matters, including unexpected environmental remediation costs in excess of any reserves or insurance coverage;


•	the price, availability and acceptance of alternative fuels and alternative fuel vehicles;


•	labor relations;


•	operating hazards, natural disasters, casualty losses, acts of terrorism including cyber-attacks and other matters beyond our control; and


•	other factors discussed in more detail under Part I — Item 1A. Risk Factors in our Annual Report on Form 10-K for the year ended December 31, 2015 ("2015 10‑K") that are incorporated herein by this reference.

Any one of these factors or a combination of these factors could materially affect our financial condition, results of operations or cash flows and could influence whether any forward-looking statements ultimately prove to be accurate. You are urged to consider these factors carefully in evaluating any forward-looking statements and are cautioned not to place undue reliance upon these forward-looking statements.

Although we believe the forward-looking statements we make in this report related to our plans, intentions and expectations are reasonable, we can provide no assurance that such plans, intentions or expectations will be achieved. These statements are based upon assumptions made by us based upon our experience and perception of historical trends, current conditions, expected future developments and other factors that we believe are appropriate in the circumstances. Such statements are subject to a number of risks and uncertainties, many of which are beyond our control. The forward-looking statements included herein are made only as of the date of this report and we are not required to (and will not) update any information to reflect events or circumstances that may occur after the date of this report, except as required by applicable law.

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Part I

Financial Information


Item 1.	Financial Statements

WESTERN REFINING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In thousands, except share and per share data)



	March 31, 2016			December 31, 2015
ASSETS
Current assets:
Cash and cash equivalents (WNRL: $28,653 and $44,605, respectively)	$	593,101		$	772,502
Accounts receivable, trade, net of a reserve for doubtful accounts of $195 and $169, respectively (WNRL: $60,946 and $55,053, respectively)	337,077			359,237
Inventories (WNRL: $12,476 and $15,200, respectively)	683,593			547,538
Prepaid expenses (WNRL: $5,380 and $4,133, respectively)	79,971			73,213
Other current assets (WNRL: $5,510 and $5,562, respectively)	159,591			169,728
Total current assets	1,853,333			1,922,218
Restricted cash	36,783			69,106
Equity method investment	102,971			97,513
Property, plant and equipment, net (WNRL: $324,342 and $321,251, respectively)	2,324,591			2,305,171
Goodwill	1,289,443			1,289,443
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	85,275			84,945
Other assets, net (WNRL: $3,348 and $3,376, respectively)	61,366			64,997
Total assets	$	5,753,762		$	5,833,393
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable (WNRL: $14,663 and $9,489, respectively)	$	562,430		$	553,957
Accrued liabilities (WNRL: $25,858 and $30,378, respectively)	218,752			248,395
Current portion of long-term debt	5,500			5,500
Total current liabilities	786,682			807,852
Long-term liabilities:
Long-term debt, less current portion (WNRL: $422,810 and $437,467, respectively)	1,652,592			1,644,894
Lease financing obligations	53,190			53,232
Deferred income tax liability, net	341,475			312,914
Other liabilities (WNRL: $9 in both periods)	69,023			68,595
Total long-term liabilities	2,116,280			2,079,635
Commitments and contingencies
Equity:
Western shareholders' equity:
Common stock, par value $0.01, 240,000,000 shares authorized; 102,828,650 and 102,773,705 shares issued, respectively	1,028			1,028
Preferred stock, par value $0.01, 10,000,000 shares authorized; no shares issued or outstanding	—			—
Additional paid-in capital	492,847			492,848
Retained earnings	1,162,876			1,167,938
Accumulated other comprehensive loss, net of tax	651			651
Treasury stock, 11,551,973 and 9,089,623 shares, respectively at cost	(438,168		)	(363,168		)
Total Western shareholders' equity	1,219,234			1,299,297
Non-controlling interests	1,631,566			1,646,609
Total equity	2,850,800			2,945,906
Total liabilities and equity	$	5,753,762		$	5,833,393

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

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WESTERN REFINING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands, except per share data)



	Three Months Ended
	March 31,
	2016			2015
Net sales	$	1,455,504		$	2,318,730
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	1,047,361			1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	223,585			215,311
Selling, general and administrative expenses	53,285			55,803
Loss (gain) on disposal of assets, net	(130		)	282
Maintenance turnaround expense	125			105
Depreciation and amortization	52,651			49,926
Total operating costs and expenses	1,376,877			2,062,737
Operating income	78,627			255,993
Other income (expense):
Interest income	164			163
Interest and debt expense	(26,681		)	(24,957		)
Other, net	6,104			3,206
Income before income taxes	58,214			234,405
Provision for income taxes	(18,629		)	(59,437		)
Net income	39,585			174,968
Less net income attributable to non-controlling interests	9,047			68,979
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989

Net earnings per share:
Basic	$	0.34		$	1.11
Diluted	0.33			1.11
Weighted-average common shares outstanding:
Basic	92,078			95,567
Diluted	92,144			95,682

Cash dividends declared per common share	$	0.38		$	0.30

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

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WESTERN REFINING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In thousands)



	Three Months Ended
	March 31,
	2016		2015
Net income	$	39,585	$	174,968
Other comprehensive income items:
Benefit plans:
Reclassification of loss to income	—		13
Other comprehensive income before tax	—		13
Income tax	—		(5		)
Other comprehensive income, net of tax	—		8
Comprehensive income	39,585		174,976
Less comprehensive income attributable to non-controlling interests	9,047		68,979
Comprehensive income attributable to Western Refining, Inc.	$	30,538	$	105,997

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

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WESTERN REFINING, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)



	Three Months Ended
	March 31,
	2016			2015
Cash flows from operating activities:
Net income	$	39,585		$	174,968
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	52,651			49,926
Changes in fair value of commodity hedging instruments	12,483			20,057
Reserve for doubtful accounts	26			(46		)
Amortization of loan fees and original issue discount	1,628			1,515
Stock-based compensation expense	6,181			4,010
Deferred income taxes	28,561			4,989
Excess tax benefit from stock-based compensation	—			(337		)
Income from equity method investment, net of dividends	(5,517		)	(3,619		)
Loss (gain) on disposal of assets, net	(130		)	282
Changes in operating assets and liabilities:
Accounts receivable	21,824			19,016
Inventories	(136,055		)	(43,851		)
Prepaid expenses	(6,758		)	11,909
Other assets	(62		)	(33,451		)
Accounts payable and accrued liabilities	(14,362		)	(99,041		)
Other long-term liabilities	1,049			(1,349		)
Net cash provided by operating activities	1,104			104,978
Cash flows from investing activities:
Capital expenditures	(79,029		)	(53,195		)
Use of restricted cash	32,323			43,400
Proceeds from the sale of assets	219			624
Net cash used in investing activities	(46,487		)	(9,171		)
Cash flows from financing activities:
Additions to long-term debt	—			300,000
Payments on long-term debt and capital lease obligations	(1,922		)	(1,375		)
Borrowings on revolving credit facility	70,000			—
Repayments on revolving credit facility	(62,500		)	(269,000		)
Deferred financing costs	—			(6,551		)
Purchase of common stock for treasury	(75,000		)	(25,000		)
Distribution to non-controlling interest holders	(28,995		)	(33,665		)
Dividends paid	(35,601		)	(28,638		)
Excess tax benefit from stock-based compensation	—			337
Net cash used in financing activities	(134,018		)	(63,892		)
Net increase (decrease) in cash and cash equivalents	(179,401		)	31,915
Cash and cash equivalents at beginning of period	772,502			431,159
Cash and cash equivalents at end of period	$	593,101		$	463,074

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

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Organization

"Western," "we," "us," "our" and the "Company" refer to Western Refining, Inc. and, unless the context otherwise requires, our subsidiaries. Western Refining, Inc. was formed on September 16, 2005, as a holding company prior to our initial public offering and is incorporated in Delaware.

We produce refined products at three refineries: one in El Paso, Texas, one near Gallup, New Mexico and one in St. Paul Park, Minnesota. We sell refined products in Arizona, Colorado, Minnesota, New Mexico, Wisconsin, West Texas, the Mid-Atlantic region and Mexico. Our product sales occur through bulk distribution terminals, wholesale marketing networks and two retail networks with a total of 541 company-owned and franchised retail sites in the United States.

At March 31, 2016, we owned a 38.3% limited partner interest in Northern Tier Energy LP ("NTI") and the public held a 61.7% limited partner interest. We control NTI through our 100% ownership of its general partner. NTI owns and operates a refinery in St. Paul Park, Minnesota and has a retail-marketing network of 283 convenience stores; 114 of which operate through franchise agreements. NTI's primary areas of operation include Minnesota and Wisconsin.

We entered into an Agreement and Plan of Merger dated as of December 21, 2015 (the “Merger Agreement”) with Western Acquisition Co, LLC, a wholly-owned subsidiary of Western (“MergerCo”), NTI and Northern Tier Energy GP LLC, to acquire all of NTI’s outstanding common units not already held by us (the “Merger”). Each of the outstanding NTI common units held by unitholders other than us (the “NTI Public Unitholders”) will be converted under the terms of the Merger Agreement, into the right to receive, subject to election by the NTI Public Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western’s common stock, par value $0.01 per share (“Western Common Stock”), (ii) $26.06 in cash without interest or (iii) 0.7036 of a share of Western Common Stock. Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo will merge with and into NTI and the separate limited liability company existence of MergerCo will cease and NTI will continue to exist, as a limited partnership under Delaware law and as our indirect wholly-owned subsidiary, as the surviving entity in the Merger. The Merger is expected to close in the second quarter of 2016, pending the satisfaction of certain customary conditions and the approval of the Merger and other matters at a special meeting of NTI unitholders by the affirmative vote of holders of a majority of the outstanding NTI common units (including the NTI common units held by us). The transaction is expected to result in 17.2 million additional shares of Western Common Stock outstanding.

Consistent with NTI’s distribution policy, cash distributions with respect to the second quarter of 2016, if any, would normally be declared and paid in August 2016. However, pursuant to the terms of the Merger Agreement, with respect to the quarter in which the closing date ("Closing Date") occurs, which is currently expected to be the second quarter of 2016, assuming all closing conditions are satisfied, NTI will, to the extent it generates available cash in such quarter, make a prorated quarterly distribution to unitholders of record as of immediately prior to the effective time of the Merger (the “Effective Time”) of any such available cash if the record date for the Western's quarterly cash dividend to be paid in that quarter occurs before the Closing Date. Accordingly, in the quarter that the Closing Date occurs, NTI common unitholders who receive Western Common Stock in the Merger will receive (i) an NTI cash distribution in respect of the previous quarter, to the extent that NTI generates available cash in such quarter, and (ii) either an NTI prorated cash distribution in respect of available cash generated by NTI in the quarter in which the Closing Date occurs or (assuming such unitholders continue to hold the shares of Western Common Stock received in the Merger through the record date for such Western dividend) the Western quarterly cash dividend payable in the quarter in which the Closing Date occurs. The amount of any distribution will not have any effect on the merger consideration to be received by the NTI’s unitholders. See Note 21, NTI, for further discussion.

At March 31, 2016, we owned a 66.4% limited partner interest in Western Refining Logistics, LP ("WNRL") and the public held a 33.6% limited partner interest. We control WNRL through our 100% ownership of its general partner and we own the majority of WNRL's limited partnership interests. WNRL owns and operates logistics assets consisting of pipeline and gathering, terminalling, storage and transportation assets as well a wholesale business that operates primarily in the Southwest. WNRL operates its logistics assets primarily for the benefit of the Company. See Note 22, WNRL, for further discussion.

On October 30, 2015, we sold a 375 mile segment of the TexNew Mex Pipeline system to WNRL that extends from WNRL's crude oil station in Star Lake, New Mexico, in the Four Corners region to its T station in Eddy County, New Mexico (the "TexNew Mex Pipeline System"). We also sold an 80,000 barrel crude oil storage tank located at WNRL's crude oil pumping station in Star Lake, New Mexico and certain other related assets. WNRL acquired these assets from us in exchange for $170 million in cash, 421,031 common units representing limited partner interests in WNRL and 80,000 units of a newly created class of limited partner interests in WNRL, referred to as the "TexNew Mex Units." We refer to this transaction as the "TexNew Mex Pipeline Transaction."

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

The WNRL financial and operational data presented includes the historical results of all assets acquired from Western in the TexNew Mex Pipeline Transaction. The acquisition from Western was a transfer of assets between entities under common control. Accordingly, the financial information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the TexNew Mex Pipeline System assets acquired, for periods prior to the effective date of the TexNew Mex Pipeline Transaction.

Our operations include four business segments: refining, NTI, WNRL and retail. See Note 3, Segment Information, for further discussion of our business segments.

2. Basis of Presentation and Significant Accounting Policies

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principals ("GAAP") for interim consolidated financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, these unaudited condensed consolidated financial statements do not include all of the information and footnotes required by GAAP for complete financial statements. In management's opinion, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Operating results for the three months ended March 31, 2016 are not necessarily indicative of the results that may be expected for the year ending December 31, 2016, or for any other period.

The Condensed Consolidated Balance Sheet at December 31, 2015 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements. The accompanying condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015.

Principles of Consolidation

The accompanying condensed consolidated financial statements include the accounts of Western and our subsidiaries. We own a 38.3% limited partner interest in NTI and a 66.4% limited partner interest in WNRL. We own 100% of NTI's and WNRL's respective general partners. As the general partner of NTI and WNRL, we have the ability to direct the activities of NTI and WNRL that most significantly impact their respective economic performance. We have reported non-controlling interests for NTI and WNRL of $1,631.6 million and $1,646.6 million in our Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015, respectively. All intercompany accounts and transactions have been eliminated for all periods presented. Investments in significant non-controlled entities are accounted for using the equity method.

Variable Interest Entity

WNRL is a variable interest entity ("VIE") as defined under GAAP. A VIE is a legal entity whose equity owners do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support or, as a group, the equity holders lack the power, through voting rights, to direct the activities that most significantly impact the entity's financial performance, the obligation to absorb the entity's expected losses or rights to expected residual returns. As the general partner of WNRL, we have the sole ability to direct the activities of WNRL that most significantly impact WNRL's financial performance, and therefore we consolidate WNRL. See Note 22, WNRL, for further discussion.

Goodwill and Other Unamortizable Intangible Assets

Goodwill represents the excess of the purchase price (cost) over the fair value of the net assets acquired and is carried at cost. We do not amortize goodwill for financial reporting purposes. We test goodwill for impairment at the reporting unit level. The reporting unit or units used to evaluate and measure goodwill for impairment are determined primarily from the manner in which the business is managed. Our policy is to test goodwill and other unamortizable intangible assets for impairment annually at June 30, or more frequently if indications of impairment exist.

The risk of goodwill and intangible asset impairment losses may increase to the extent that NTI’s market capitalization, results of operations, or cash flows decline. Impairment losses may result in a material, non-cash write-down of goodwill or intangible assets. Furthermore, impairment losses could have a material adverse effect on the Company’s results of operations and shareholders’ equity.

Use of Estimates and Seasonality

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Demand for gasoline is generally higher during the summer months than during the winter months. As a result, our operating results for the first and fourth calendar quarters are generally lower than those for the second and third calendar quarters of each year. During 2014 and continuing into 2015, the volatility in crude oil prices and refining margins contributed to the variability of our results of operations.

Recent Accounting Pronouncements

Effective January 1, 2016, we adopted the revised accounting and reporting requirements included in the Accounting Standards Codification ("ASC") for consolidation of limited partnerships or similar entities. We have applied the new standards retrospectively. The adoption of these revised standards did not result in any change to our consolidation conclusions or impact our financial position, results of operations or cash flows. We have added disclosures for WNRL as required for entities not previously included in the reporting entity as a variable interest entity.

From time to time, new accounting pronouncements are issued by various standard setting bodies that may have an impact on our accounting and reporting. We are currently evaluating the effect that certain of these new accounting requirements may have on our accounting and related reporting and disclosures in our condensed consolidated financial statements.

•

Recognition and reporting of revenues - the requirements were amended to remove inconsistencies in revenue requirements and to provide a more complete framework for addressing revenue issues across a broad range of industries and transaction types. The revised standard’s core principle is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The revised standard also addresses principal versus agent considerations and indicators related to transfer of control over specified goods. These provisions are effective January 1, 2018, and are to be applied retrospectively, with early adoption permitted for periods beginning after December 15, 2016, and interim periods thereafter.

•

Lease accounting - the requirements were amended in regards to recognizing lease assets and lease liabilities on the balance sheet and disclosing information about leasing arrangements. The core principle is that a lessee should recognize the assets and liabilities that arise from leases. These provisions are effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted.

•

Employee share-based payment accounting - the requirements involve several aspects of accounting for share-based payment transactions, including income tax consequences, classification of awards as either equity or liabilities and classification in the statement of cash flows. These provisions are effective for annual periods beginning after December 15, 2016, including interim periods within those annual periods. Early adoption is permitted in any interim or annual period.

•

Recognition of breakage for certain prepaid stored-value products - the requirements align recognition of the financial liabilities related to prepaid stored-value products with the revenue recognition standard discussed above for non-financial liabilities. Certain of these liabilities may be extinguished proportionally in earnings as redemptions occur, or when redemption is remote if issuers are not entitled to the unredeemed stored value. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017 with early adoption permitted subject to certain requirements.

•

Derivatives and hedging: contingent put and call options in debt instruments - the requirements will reduce diversity of practice in identifying embedded derivatives in debt instruments and clarify the nature of an exercise contingency is not subject to the “clearly and closely” criteria for purposes of assessing whether the call or put option must be separated from the debt instrument and accounted for separately as a derivative. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2016 with early adoption permitted subject to certain requirements.

3. Segment Information

Our operations are organized into four operating segments based on manufacturing and marketing criteria and the nature of our products and services, our production processes and our types of customers. These segments are refining, NTI, WNRL and retail.

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We treated the TexNew Mex Pipeline System assets that we sold to WNRL in the TexNew Mex Pipeline Transaction as a transfer of assets between entities under common control. Accordingly, we have retrospectively adjusted the financial information for the affected reporting segments to include or exclude the historical results of the transferred assets for periods prior to the effective date of the transaction. The TexNew Mex Pipeline System was moved from the refining segment to the WNRL segment.

A description of each segment and the principal products follows:

Refining. We report the operations of two refineries in our refining segment: one in El Paso, Texas (the "El Paso refinery") with a 131,000 barrel per day ("bpd") capacity and one near Gallup, New Mexico (the "Gallup refinery") with a 25,000 bpd capacity. Our refineries make various grades of gasoline, diesel fuel and other products from crude oil, other feedstocks and blending components. We purchase crude oil, other feedstocks and blending components from various third-party suppliers. We also acquire refined products through exchange agreements and from various third-party suppliers to supplement supply to our customers. We sell these products to WNRL, to our retail segment, to other independent wholesalers and retailers, commercial accounts and sales and exchanges with major oil companies.

We have an exclusive supply and marketing agreement with a third party covering activities related to our refined product supply, sales and hedging in the Mid-Atlantic region. We recorded $1.4 million and $1.8 million in assets at March 31, 2016 and December 31, 2015, respectively, related to this supply agreement in our Condensed Consolidated Balance Sheets. The revenues and costs recorded under the supply agreement included $26.4 million and $21.5 million in net hedging gains for the three months ended March 31, 2016 and 2015, respectively.

NTI. NTI is an independent crude oil refiner and marketer of refined products with a 98,000 bpd refinery in St. Paul Park, Minnesota and a network of retail convenience stores selling various grades of gasoline, diesel fuel and convenience store merchandise, primarily in Minnesota and Wisconsin. NTI's operations are separate from those of Western. As of March 31, 2016, NTI included the operations of 169 retail convenience stores and supported 114 franchised retail convenience stores. NTI's refinery supplies the majority of the gasoline and diesel fuel sold through its retail convenience stores.

WNRL. WNRL owns and operates pipeline and gathering, terminalling, storage and transportation assets that provide logistics services to our refining segment in the Southwest, including 685 miles of pipelines and 8.2 million barrels of active storage capacity. The majority of WNRL's logistics assets are integral to the operations of the El Paso and Gallup refineries.

WNRL also owns a wholesale business that operates primarily in the Southwest. WNRL's wholesale business includes the operations of several lubricant and bulk petroleum distribution plants and a fleet of crude oil, refined product and lubricant delivery trucks. WNRL distributes commercial wholesale petroleum products primarily in Arizona, California, Colorado, Nevada, New Mexico and Texas. WNRL purchases petroleum fuels and lubricants from our refining segment and from third-party suppliers.

Retail. Our Southwest retail business sells various grades of gasoline, diesel fuel, convenience store merchandise and beverage and food products to the general public through retail convenience stores and various grades of gasoline and diesel fuel to commercial vehicle fleets through unmanned fleet fueling sites ("cardlocks"). WNRL supplies the majority of gasoline and diesel fuel that our retail segment sells. We purchase general merchandise and beverage and food products from various third-party suppliers. At March 31, 2016, the retail segment operated 258 service stations and convenience stores or kiosks located in Arizona, Colorado, New Mexico and Texas compared to 261 service stations and convenience stores or kiosks at March 31, 2015. At March 31, 2016, the retail segment operated 52 cardlocks located in Arizona, California, Colorado, New Mexico and Texas compared to 50 cardlocks at March 31, 2015.

Segment Accounting Principles. Operating income for each segment consists of net revenues less cost of products sold; direct operating expenses; selling, general and administrative expenses; net impact of the disposal of assets and depreciation and amortization. The refining and NTI segments also include costs related to periodic maintenance turnaround activities. Cost of products sold includes net realized and unrealized gains and losses related to our commodity hedging activities and reflects current costs adjusted, where appropriate, for "last-in, first-out" ("LIFO") and lower of cost or market ("LCM") inventory adjustments. Intersegment revenues are reported at prices that approximate market.

Activities of our business that are not included in the four segments mentioned above are included in the Other category. These activities consist primarily of corporate staff operations and other items that are not specific to the normal business of any one of our four operating segments. We do not allocate certain items of other income and expense, including income taxes, to the individual segments. NTI and WNRL are primarily pass-through entities with respect to income taxes.

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total assets of the corporate operations are cash and cash equivalents; various net accounts receivable; prepaid expenses; other current assets; net property, plant and equipment and other long-term assets.

Disclosures regarding our reportable segments with reconciliations to consolidated totals for the three months ended March 31, 2016 and 2015 are presented below:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Operating Results:
Refining (2)
Net sales	$	886,320		$	1,491,441
Intersegment eliminations	467,807			542,542
Net refining sales to external customers	418,513			948,899
NTI
Net sales	497,473			697,776
Intersegment eliminations	8,696			12,990
Net NTI sales to external customers	488,777			684,786
WNRL (2)
Net sales	468,039			607,396
Intersegment eliminations	149,462			178,249
Net WNRL sales to external customers	318,577			429,147
Retail
Net sales	231,186			258,602
Intersegment eliminations	1,549			2,704
Net retail sales to external customers	229,637			255,898

Consolidated net sales to external customers	$	1,455,504		$	2,318,730

Operating income (loss)
Refining (1) (2)	$	62,138		$	148,612
NTI (1)	8,115			107,987
WNRL (2)	21,438			17,561
Retail	2,432			(441		)
Other	(15,496		)	(17,726		)
Operating income from segments	78,627			255,993
Other income (expense), net	(20,413		)	(21,588		)
Consolidated income before income taxes	$	58,214		$	234,405

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	Three Months Ended
	March 31,
	2016		2015
Depreciation and amortization
Refining (2)	$	21,285	$	20,484
NTI	19,969		19,365
WNRL (2)	7,144		5,892
Retail	3,330		3,286
Other	923		899
Consolidated depreciation and amortization	$	52,651	$	49,926

Capital expenditures
Refining (2)	$	43,563	$	17,826
NTI	27,990		6,673
WNRL (2)	6,241		25,996
Retail	637		1,402
Other	598		1,298
Consolidated capital expenditures	$	79,029	$	53,195

Total assets
Refining (2)	$	1,620,113	$	1,606,073
NTI (including $1,289,443 of goodwill)	2,328,446		2,258,695
WNRL (2)	448,218		495,028
Retail	239,359		249,318
Other	1,117,626		1,075,408
Consolidated total assets	$	5,753,762	$	5,684,522

(1)

The effect of our economic hedging activity is included within the operating income of our refining and NTI segments as a component of cost of products sold. The cost of products sold within our refining segment included $6.0 million in net realized and unrealized economic hedging gains and $3.7 million in net realized and unrealized economic hedging losses for the three months ended March 31, 2016 and 2015, respectively. NTI cost of products sold included $0.7 million in net realized and unrealized economic hedging losses and $1.2 million in net realized and unrealized economic hedging gains for the three months ended March 31, 2016 and 2015, respectively. Also included within cost of products sold is the net effect of non-cash LCM recoveries of $40.7 million and $4.9 million for our refining segment and $11.0 million and $10.8 million for NTI for the three months ended March 31, 2016 and 2015, respectively.

(2)

WNRL's financial data includes its historical financial results and an allocated portion of corporate general and administrative expenses, previously reported as Other, for the three months ended March 31, 2015. Refining operating results include activity of the TexNew Mex Pipeline System that was previously recorded within our refining segment. The information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the TexNew Mex Pipeline System.

4. Fair Value Measurement

We utilize the market approach when measuring fair value of our financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities.

The fair value hierarchy consists of the following three levels:


Level 1	Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.

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Level 2	Inputs are quoted prices for similar assets or liabilities in an active market, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable and market-corroborated inputs that are derived principally from or corroborated by observable market data.


Level 3	Inputs are derived from valuation techniques that one or more significant inputs or value drivers are unobservable and cannot be corroborated by market data or other entity-specific inputs.

The carrying amounts of cash and cash equivalents, which we consider Level 1 assets and liabilities, approximated their fair values at March 31, 2016 and December 31, 2015, due to their short-term maturities. Our fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments and an evaluation of counterparty credit risk. Cash equivalents totaling $70.1 million consisting of short-term money market deposits and commercial paper were included in the Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015.

We maintain cash deposits with various counterparties in support of our hedging and trading activities. These deposits are required by counterparties as collateral and cannot be offset against the fair value of open contracts except in the event of default. Certain of our commodity derivative contracts under master netting arrangements include both asset and liability positions. We have elected to offset the fair value amounts recognized for multiple similar derivative instruments executed with the same counterparty under the column "Netting Adjustments" below; however, fair value amounts by hierarchy level are presented on a gross basis in the tables below. See Note 13, Crude Oil and Refined Product Risk Management, for further discussion of master netting arrangements.

The following tables represent our assets and liabilities for our commodity hedging contracts measured at fair value on a recurring basis as of March 31, 2016 and December 31, 2015, and the basis for that measurement:



	Carrying Value at March 31, 2016			Fair Value Measurement Using								Netting Adjustments			Recorded Value at March 31, 2016
	Carrying Value at March 31, 2016			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at March 31, 2016
	(In thousands)
Gross financial assets:
Other current assets	$	86,144		$	—	$	86,144		$	—		$	(19,080	)	$	67,064
Other assets	8,019			—		8,019			—			(867		)	7,152
Gross financial liabilities:
Accrued liabilities	(12,647		)	—		(8,689		)	(3,958		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	—		(14,437		)	—			14,437			—
	$	67,079		$	—	$	71,037		$	(3,958	)	$	—		$	67,079



	Carrying Value at December 31, 2015			Fair Value Measurement Using								Netting Adjustments			Recorded Value at December 31, 2015
	Carrying Value at December 31, 2015			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at December 31, 2015
	(In thousands)
Gross financial assets:
Other current assets	$	95,062		$	—	$	95,062		$	—		$	(16,937	)	$	78,125
Other assets	11,881			—		11,881			—			—			11,881
Gross financial liabilities:
Accrued liabilities	(21,454		)	—		(15,698		)	(5,756		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	—		(5,756		)	—			5,756			—
	$	79,733		$	—	$	85,489		$	(5,756	)	$	—		$	79,733

Commodity hedging contracts designated as Level 3 financial assets consisted of jet fuel crack spread swaps. Ultra-low sulfur diesel ("ULSD") pricing has had a strong historical correlation to jet fuel crack spread swaps. We estimate the fair value of our Level 3 instruments based on the differential between quoted market settlement prices on ULSD futures and quoted market settlement prices on jet fuel futures for settlement dates corresponding to each of our outstanding Level 3 jet fuel crack spread swaps. As quoted prices for similar assets or liabilities in an active market are available, we reclassify the underlying financial asset or liability and designate them as Level 2 prior to final settlement.

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Carrying amounts of commodity hedging contracts reflected as financial assets are included in both current and non-current other assets in the Condensed Consolidated Balance Sheets. Carrying amounts of commodity hedging contracts reflected as financial liabilities are included in both accrued and other long-term liabilities in the Condensed Consolidated Balance Sheets. Fair value adjustments referred to as credit valuation adjustments ("CVA") are included in the carrying amounts of commodity hedging contracts. CVAs are intended to adjust the fair value of counterparty contracts as a function of a counterparty's credit rating and reflect the credit quality of each counterparty to arrive at contract fair values.

The following table presents the changes in fair value of our Level 3 assets and liabilities, excluding goodwill (all related to commodity price swap contracts) for the three months ended March 31, 2016 and 2015.



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Asset (liability) balance at beginning of period	$	(5,756	)	$	330
Change in fair value	186			—
Fair value of trades entered into during the period	—			1,462
Fair value reclassification from Level 3 to Level 2	1,612			(82		)
Asset (liability) balance at end of period	$	(3,958	)	$	1,710

A hypothetical change of 10% to the estimated future cash flows attributable to our Level 3 commodity price swaps would result in a $0.4 million change in the estimated fair value at March 31, 2016.

As of March 31, 2016 and December 31, 2015, the carrying amount and estimated fair value of our debt was as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Western obligations:
Carrying amount	$	887,625	$	889,000
Fair value	838,373		867,178
NTI obligations:
Carrying amount	$	372,500	$	350,000
Fair value	367,250		360,500
WNRL obligations:
Carrying amount	$	430,000	$	445,000
Fair value	400,000		439,000

The carrying amount of our debt is the amount reflected in the Condensed Consolidated Balance Sheets, including the current portion. The fair value of the debt was determined using Level 2 inputs.

There have been no transfers between assets or liabilities whose fair value is determined through the use of quoted prices in active markets (Level 1) and those determined through the use of significant other observable inputs (Level 2).

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5. Inventories

Inventories were as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Refined products (1)	$	267,861	$	201,928
Crude oil and other raw materials	362,415		288,403
Lubricants	12,356		14,996
Retail store merchandise	40,961		42,211
Inventories	$	683,593	$	547,538


(1)	Includes $15.0 million and $14.5 million of inventory valued using the first-in, first-out ("FIFO") valuation method at March 31, 2016 and December 31, 2015, respectively.

We value our refinery inventories of crude oil, other raw materials and asphalt at the lower of cost or market under the LIFO valuation method. Other than refined products inventories held by WNRL and our retail segment, refined products inventories are valued under the LIFO valuation method. WNRL's wholesale refined product, lubricants and related inventories are valued using the FIFO inventory valuation method. Retail refined product inventory is valued using the FIFO inventory valuation method. Retail merchandise inventory is valued using the retail inventory method.

As of March 31, 2016 and December 31, 2015, refined products valued under the LIFO method and crude oil and other raw materials totaled 12.6 million barrels and 10.0 million barrels, respectively. At March 31, 2016 and December 31, 2015, the excess of the LIFO cost over the current cost of these crude oil, refined product and other feedstock and blendstock inventories was $221.4 million and $198.4 million, respectively.

During the three months ended March 31, 2016 and 2015, cost of products sold included net non-cash credits of $23.0 million and $113.6 million, respectively, from changes in our LIFO reserves. In order to state our inventories at market values that were lower than our LIFO costs, we reduced the carrying values of our inventory through non-cash LCM inventory adjustments of $123.4 million and $175.1 million at March 31, 2016 and December 31, 2015, respectively. These non-cash LCM recoveries decreased cost of products sold by $51.7 million and $15.7 million for the three months ended March 31, 2016 and 2015, respectively.

Average LIFO cost per barrel of our refined products and crude oil and other raw materials inventories as of March 31, 2016 and December 31, 2015, were as follows:



	March 31, 2016					December 31, 2015
	Barrels	LIFO Cost		Average LIFO Cost Per Barrel		Barrels	LIFO Cost		Average LIFO Cost Per Barrel
	(In thousands, except cost per barrel)
Refined products	5,130	$	314,934	$	61.39	3,536	$	259,722	$	73.45
Crude oil and other	7,462	423,694		56.78		6,490	391,237		60.28
	12,592	$	738,628	58.66		10,026	$	650,959	64.93

6. Equity Method Investment

NTI owns a 17% common equity interest in Minnesota Pipe Line Company, LLC ("MPL"). The carrying value of this equity method investment was $103.0 million and $97.5 million at March 31, 2016 and December 31, 2015, respectively.

As of March 31, 2016 and December 31, 2015, the carrying amount of the equity method investment was $21.3 million higher than the underlying net assets of the investee. We are amortizing this difference over the remaining life of MPL’s primary asset (the fixed asset life of the pipeline). There is no market for the common units of MPL and, accordingly, no quoted market price is available.

We received no distributions during the three months ended March 31, 2016. During the three months ended March 31, 2015, we recognized $3.7 million in declared but unpaid distributions from MPL. Equity income from MPL for the three

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months ended March 31, 2016 and 2015, was $5.5 million and $3.6 million, respectively. Equity income has been included in other, net in the accompanying Condensed Consolidated Statements of Operations.

7. Property, Plant and Equipment, Net

Property, plant and equipment, net was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Refinery facilities and related equipment	$	2,390,745		$	2,348,663
Pipelines, terminals and transportation equipment	559,040			533,040
Retail facilities and related equipment	329,808			328,419
Wholesale facilities and related equipment	61,369			61,133
Corporate	51,451			50,812
	3,392,413			3,322,067
Accumulated depreciation	(1,067,822		)	(1,016,896		)
Property, plant and equipment, net	$	2,324,591		$	2,305,171

Depreciation expense was $51.6 million and $48.9 million for the three months ended March 31, 2016 and 2015, respectively.

8. Intangible Assets, Net

Intangible assets, net was as follows:



	March 31, 2016							December 31, 2015							Weighted- Average Amortization Period (Years)
	Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Weighted- Average Amortization Period (Years)
	(In thousands)
Amortizable assets:
Licenses and permits	$	20,427	$	(14,124	)	$	6,303	$	20,427	$	(13,729	)	$	6,698	4.0
Customer relationships	7,551		(4,060		)	3,491		7,551		(3,921		)	3,630		6.3
Rights-of-way and other	7,905		(1,999		)	5,906		6,839		(1,797		)	5,042		8.6
	35,883		(20,183		)	15,700		34,817		(19,447		)	15,370
Unamortizable assets:
Franchise rights and trademarks	50,500		—			50,500		50,500		—			50,500
Liquor licenses	19,075		—			19,075		19,075		—			19,075
Intangible assets, net	$	105,458	$	(20,183	)	$	85,275	$	104,392	$	(19,447	)	$	84,945

Intangible asset amortization expense for the three months ended March 31, 2016 was $0.7 million based on estimated useful lives ranging from 1 to 35 years. Intangible asset amortization expense for the three months ended March 31, 2015 was $0.7 million based on estimated useful lives ranging from 1 to 23 years.

Estimated amortization expense for the indicated periods is as follows (in thousands):



Remainder of 2016	$	2,204
2017	2,906
2018	2,905
2019	2,237
2020	1,292
2021	1,006

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9. Long-Term Debt

Long-term debt was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Western obligations:
Revolving Credit Facility due 2019	$	—		$	—
Term Loan Credit Facility due 2020	537,625			539,000
6.25% Senior Unsecured Notes due 2021	350,000			350,000
Total Western obligations	887,625			889,000
NTI obligations:
Revolving Credit Facility due 2019	22,500			—
7.125% Senior Secured Notes due 2020	350,000			350,000
Total NTI obligations	372,500			350,000
WNRL obligations:
Revolving Credit Facility due 2018	130,000			145,000
7.5% Senior Notes due 2023	300,000			300,000
Total WNRL obligations	430,000			445,000
Less unamortized premium and debt issuance costs	32,033			33,606
Long-term debt	1,658,092			1,650,394
Current portion of long-term debt	(5,500		)	(5,500		)
Long-term debt, net of current portion	$	1,652,592		$	1,644,894

As of March 31, 2016, annual maturities of long-term debt for the remainder of 2016 are $4.1 million. For 2017, 2018, 2019 and 2020, long-term debt maturities are $5.5 million, $135.5 million, $28.0 million and $867.0 million, respectively. Thereafter, total long-term debt maturities are $650.0 million.

Interest and debt expense were as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Contractual interest:
Western obligations	$	12,052		$	12,007
NTI obligations	6,914			6,591
WNRL obligations	6,705			3,726
	25,671			22,324
Amortization of loan fees	1,911			1,786
Other interest expense	(176		)	1,075
Capitalized interest	(725		)	(228		)
Interest and debt expense	$	26,681		$	24,957

We amortize original issue discounts and financing fees using the effective interest method over the respective term of the debt. Our creditors have no recourse to the assets owned by either of NTI or WNRL, and the creditors of NTI and WNRL have no recourse to our assets or those of our other subsidiaries.

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Western Obligations

Revolving Credit Facility

On October 2, 2014, we entered into the Third Amended and Restated Revolving Credit Agreement (the "Western 2019 Revolving Credit Facility"). Lenders committed $900.0 million, all of which will mature on October 2, 2019. The commitments under the Western 2019 Revolving Credit Facility may be increased in the future to $1.4 billion, subject to certain conditions (including the agreement of financial institutions, in their sole discretion, to provide such additional commitments). The amended terms of the agreement include revised borrowing rates. Borrowings can be either base rate loans plus a margin ranging from 0.50% to 1.00% or LIBOR loans plus a margin ranging from 1.50% to 2.00%, subject to adjustment based upon the average excess availability. The Western 2019 Revolving Credit Facility also provides for a quarterly commitment fee ranging from 0.25% to 0.375% per annum, subject to adjustment based upon the average utilization ratio, and letter of credit fees ranging from 1.50% to 2.00% per annum payable quarterly, subject to adjustment based upon the average excess availability. Borrowing availability under the Western 2019 Revolving Credit Facility is tied to the amount of our and our restricted subsidiaries' eligible accounts receivable and inventory. The Western 2019 Revolving Credit Facility is guaranteed, on a joint and several basis, by certain of our subsidiaries and will be guaranteed by certain newly acquired or formed subsidiaries, subject to certain limited exceptions. The Western 2019 Revolving Credit Facility is secured by our cash and cash equivalents, accounts receivable and inventory. The Western 2019 Revolving Credit Facility contains certain covenants, including, but not limited to, limitations on debt, investments and dividends and the maintenance of a minimum fixed charge coverage ratio in certain circumstances.

As of and during the three month period ended March 31, 2016, we had no direct borrowings under the Western 2019 Revolving Credit Facility, with availability of $201.0 million at March 31, 2016. This availability is net of $64.4 million in outstanding letters of credit.

Term Loan Credit Agreement

On November 12, 2013, we entered into a term loan credit agreement (the "Western 2020 Term Loan Credit Facility"). The Western 2020 Term Loan Credit Facility provides for loans of $550.0 million, matures on November 12, 2020, and provides for quarterly principal payments of $1.4 million until September 30, 2020, with the remaining balance then outstanding due on the maturity date. The Western 2020 Term Loan Credit Facility bears interest at a rate based either on the base rate (as defined in the Western 2020 Term Loan Credit Facility) plus 2.25% or the Eurodollar Rate (as defined in the Western 2020 Term Loan Credit Facility) plus 3.25% (with a Eurodollar Rate floor of 1.00%). The current interest rate based on these criteria is 4.25%. The effective rate of interest for the Western 2020 Term Loan Credit Facility was 4.65% as of March 31, 2016.

The Western 2020 Term Loan Credit Facility is secured by both the El Paso and Gallup refineries and is fully and unconditionally guaranteed on a joint and several basis by substantially all of Western's material wholly-owned subsidiaries. The Western 2020 Term Loan Credit Facility contains customary restrictive covenants including limitations on debt, investments and dividends and does not contain any financial maintenance covenants.

6.25% Senior Unsecured Notes

On March 25, 2013, we entered into an indenture (the "Western 2021 Indenture") for the issuance of $350.0 million in aggregate principal amount of 6.25% Senior Unsecured Notes due 2021 (the "Western 2021 Senior Unsecured Notes"). The Western 2021 Senior Unsecured Notes are guaranteed on a senior unsecured basis by each of our wholly-owned domestic restricted subsidiaries. We pay interest on the Western 2021 Senior Unsecured Notes semi-annually in arrears on April 1 and October 1 of each year. The Western 2021 Senior Unsecured Notes mature on April 1, 2021. The effective rate of interest for the Western 2021 Senior Unsecured Notes was 6.52% as of March 31, 2016.

NTI Obligations

Revolving Credit Facility

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recourse to Northern Tier Energy GP LLC ("NTI LLC") and certain of its subsidiaries that are borrowers thereunder, its general partner, and is guaranteed by NTI and certain of its subsidiaries. Borrowings under the NTI Revolving Credit Facility bear interest at either (a) a base rate plus an applicable margin (ranging between 0.50% and 1.00%) or (b) a LIBOR rate plus an applicable margin (ranging between 1.50% and 2.00%), in each case subject to adjustment based upon the average historical excess availability. In addition to paying interest on outstanding borrowings, NTI is also required to pay a quarterly commitment fee ranging from 0.250% to 0.375% subject to adjustment based upon the average utilization ratio and letter of credit fees ranging from 1.50% to 2.00% subject to adjustment based upon the average historical excess availability. The NTI Revolving Credit Facility contains certain covenants, including but not limited to, limitations on debt, investments and dividends and the maintenance of a minimum fixed charge coverage ratio in certain circumstances. NTI incurred financing costs of $3.0 million associated with the amended and restated NTI Revolving Credit Facility.

At March 31, 2016, the availability under the NTI Revolving Credit Facility was $134.7 million. This availability is net of $22.5 million in direct borrowings and $29.4 million in outstanding letters of credit. The effective rate of interest for the Western 2020 Term Loan Credit Facility was 5.77% as of March 31, 2016.

7.125% Secured Notes

On November 8, 2012, NTI LLC and Northern Tier Finance Corporation (together with NTI LLC, the "NTI 2020 Notes Issuers"), issued $275.0 million in aggregate principal amount of 7.125% senior secured notes due 2020 (the "NTI 2020 Secured Notes").

NTI increased the principal amount of the NTI 2020 Secured Notes in September 2014 by an additional $75.0 million in principal value at a premium of $4.2 million. This additional offering was issued under the same indenture as the existing NTI 2020 Secured Notes and the new notes issued have the same terms as the existing notes. The offering generated cash proceeds of $79.2 million including an issuance premium of $4.2 million. NTI incurred financing costs of $2.5 million associated with this offering. The issuance premium will be amortized to interest expense over the remaining life of the notes. The effective rate of interest for the NTI 2020 Secured Notes was 6.91% as of March 31, 2016.

The obligations under the NTI 2020 Secured Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by Northern Tier Energy LP and on a senior secured basis by (i) all of NTI LLC’s restricted subsidiaries that borrow, or guarantee obligations, under the NTI Revolving Credit Facility or any other indebtedness of NTI LLC or another subsidiary of NTI LLC that guarantees the NTI 2020 Secured Notes and (ii) all other material wholly-owned domestic subsidiaries of NTI LLC. The indenture governing the NTI 2020 Secured Notes contains covenants that limit or restrict dividends or other payments from restricted subsidiaries. Indebtedness under the NTI 2020 Secured Notes is guaranteed by NTI and certain of its subsidiaries.

WNRL Obligations

Revolving Credit Facility

On October 16, 2013, WNRL entered into a $300.0 million senior secured revolving credit facility (the "WNRL Revolving Credit Facility"). WNRL has the ability to increase the total commitment of the WNRL Revolving Credit Facility by up to $200.0 million for a total facility size of up to $500.0 million, subject to receiving increased commitments from lenders and to the satisfaction of certain conditions. The WNRL Revolving Credit Facility includes a $25.0 million sub-limit for standby letters of credit and a $10.0 million sub-limit for swing line loans. Obligations under the WNRL Revolving Credit Facility and certain cash management and hedging obligations are guaranteed by all of WNRL's subsidiaries and, with certain exceptions, will be guaranteed by any formed or acquired subsidiaries. Obligations under the WNRL Revolving Credit Facility are secured by a first priority lien on substantially all of WNRL's and its subsidiaries' significant assets. The WNRL Revolving Credit Facility will mature on October 16, 2018. Borrowings under the WNRL Revolving Credit Facility bear interest at either a base rate plus an applicable margin ranging from 0.75% to 1.75%, or at LIBOR plus an applicable margin ranging from 1.75% to 2.75%. The applicable margin will vary based upon WNRL's Consolidated Total Leverage Ratio, as defined in the WNRL Revolving Credit Facility.

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On October 15, 2014, to partially fund the purchase of certain assets from Western, WNRL borrowed $269.0 million under the WNRL Revolving Credit Facility. On February 11, 2015, WNRL repaid its outstanding direct borrowings under the WNRL Revolving Credit Facility with a portion of the proceeds from the issuance of its 7.5% Senior Notes due 2023 (the "7.5% Senior Notes"), discussed below. On October 30, 2015, WNRL borrowed $145.0 million under the WNRL Revolving Credit Facility to partially fund the purchase of the TexNew Mex Pipeline System from Western. On February 17, 2016, WNRL repaid $15.0 million of its outstanding direct borrowings under the WNRL Revolving Credit Facility.

The WNRL Revolving Credit Facility contains covenants that limit or restrict WNRL's ability to make cash distributions. WNRL is required to maintain certain financial ratios that are tested on a quarterly basis for the immediately preceding four quarter period. At March 31, 2016, the availability under the WNRL Revolving Credit Facility was $169.3 million, net of $130.0 million in direct borrowings and $0.7 million in outstanding letters of credit. WNRL had no swing line borrowings outstanding under the WNRL Revolving Credit Facility as of March 31, 2016. The interest rate for the borrowings under the WNRL Revolving Credit Facility was 2.69% as of March 31, 2016. The effective rate of interest for the WNRL Revolving Credit Facility was 2.76% as of March 31, 2016.

7.5% Senior Notes

On February 11, 2015, WNRL entered into an indenture (the “WNRL Indenture”) among WNRL, WNRL Finance Corp., a Delaware corporation and wholly-owned subsidiary of the Partnership (“Finance Corp.” and together with the Partnership, the “Issuers”), the Guarantors named therein and U.S. Bank National Association, as trustee (the “Trustee”) under which the Issuers issued $300.0 million in aggregate principal amount of 7.5% Senior Notes due 2023. The Partnership will pay interest on the 7.5% Senior Notes semi-annually in cash in arrears on February 15 and August 15 of each year, beginning on August 15, 2015. The 7.5% Senior Notes will mature on February 15, 2023. WNRL used the proceeds from the notes to repay the full balance due under the WNRL Revolving Credit Facility on February 11, 2015. The effective rate of interest for the 7.5% Senior Notes was 7.78% as of March 31, 2016.

The WNRL Indenture contains covenants that limit WNRL’s and its restricted subsidiaries’ ability to, among other things, (i) incur, assume or guarantee additional indebtedness or issue preferred units, (ii) create liens to secure indebtedness, (iii) pay distributions on equity securities, repurchase equity securities or redeem subordinated indebtedness, (iv) make investments, (v) restrict distributions, loans or other asset transfers from the Partnership’s restricted subsidiaries, (vi) consolidate with or merge with or into, or sell substantially all of the Partnership’s properties to, another person, (vii) sell or otherwise dispose of assets, including equity interests in subsidiaries and (viii) enter into transactions with affiliates. These covenants are subject to a number of important limitations and exceptions. The WNRL Indenture also provides for events of default, which, if any of them occurs, would permit or require the principal, premium, if any, and interest on all the then outstanding Notes to be due and payable immediately.

10. Equity

Changes to equity during the three months ended March 31, 2016, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2015	$	1,299,297		$	1,646,609		$	2,945,906
Net income	30,538			9,047			39,585
Dividends	(35,601		)	—			(35,601		)
Stock-based compensation	328			4,657			4,985
Tax deficiency from stock-based compensation	(328		)	—			(328		)
Distributions to non-controlling interests	—			(28,747		)	(28,747		)
Treasury stock purchases	(75,000		)	—			(75,000		)
Balance at March 31, 2016	$	1,219,234		$	1,631,566		$	2,850,800

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Changes to equity during the three months ended March 31, 2015, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2014	$	1,119,708		$	1,667,936		$	2,787,644
Net income	105,989			68,979			174,968
Other comprehensive income, net of tax	8			—			8
Dividends	(28,638		)	—			(28,638		)
Stock-based compensation	1,001			2,503			3,504
Excess tax benefit from stock-based compensation	337			—			337
Distributions to non-controlling interests	—			(33,665		)	(33,665		)
Treasury stock purchases	(25,000		)	—			(25,000		)
Balance at March 31, 2015	$	1,173,405		$	1,705,753		$	2,879,158

Share Repurchase Programs

Our board of directors has periodically approved various share repurchase programs authorizing us to repurchase up to $200 million of our outstanding common stock, per program. Our board of directors approved our current share repurchase program in September of 2015 ("September 2015 Program"). The September 2015 program is scheduled to expire on December 31, 2016. Our common stock repurchase programs are subject to discontinuance by our board of directors at any time.

The following table summarizes our share repurchase activity for the September 2015 Program:



	Number of shares purchased	Cost of share purchases (In thousands)
Shares purchased at December 31, 2015	—	$	—
Shares purchased during Q1, 2016	2,462,350	75,000
Shares purchased at March 31, 2016	2,462,350	$	75,000

As of March 31, 2016, we had $125.0 million remaining in authorized expenditures under the September 2015 Program.

Dividends

The table below summarizes our 2016 cash dividend declarations, payments and scheduled payments:

Declaration Date

Record Date

Payment Date

Dividend per Common Share

Total Payment

(In thousands)

First quarter

January 6

January 20

February 4

0.38

35,601

Second quarter (1)

April 8

April 18

May 2

0.38

—

Total

35,601

(1) The second quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $34.7 million.

NTI Distributions

The table below summarizes NTI's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Unit
February 3, 2016	February 12, 2016	February 19, 2016	$	0.38
Total			$	0.38

On April 29, 2016, the board of directors of NTI's general partner chose not to approve a quarterly distribution.

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WNRL Distributions

The table below summarizes WNRL's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Common and Subordinated Unit
February 1, 2016	February 11, 2016	February 26, 2016	$	0.3925
April 25, 2016	May 13, 2016	May 27, 2016	0.4025
Total			$	0.7950

In addition to its quarterly distributions, WNRL paid incentive distributions of $0.8 million and $0.02 million for the three months ended March 31, 2016 and 2015, respectively, to Western as its general partner and holder of its incentive distribution rights.

11. Income Taxes

Compared to the federal statutory rate of 35%, our effective tax rates for the three months ended March 31, 2016 and 2015, were 32.0% and 25.4%, respectively. The effective tax rates for the three months ended March 31, 2016 and 2015, were lower than the statutory rate primarily due to the reduction of taxable income associated with the non-controlling interests in NTI and WNRL.

We are subject to examination by the Internal Revenue Service for tax years ending December 31, 2012, or after and by various state and local taxing jurisdictions for tax years ending December 31, 2011, or after.

We believe that it is more likely than not that the benefit from certain state net operating loss ("NOL") carryforwards related to the Yorktown refinery will not be realized. Accordingly, a valuation allowance of $20.8 million was previously provided against the deferred tax assets relating to these NOL carryforwards at March 31, 2016. There was no change in the valuation allowance for the Yorktown NOL carryforwards from December 31, 2015.

As of March 31, 2016, we have recorded a liability of $40.2 million for unrecognized tax benefits, of which $20.9 million would affect our effective tax rate if recognized. There was no material change for unrecognized tax benefits for the three months ended March 31, 2016. We also recognized $0.2 million and $0.1 million in interest and penalties for the three months ended March 31, 2016 and 2015, respectively.

12. Retirement Plans

We fully recognize the obligations associated with our retiree healthcare and other postretirement plans and NTI's single-employer defined benefit cash balance plan in our financial statements.

Pensions

The net periodic benefit cost associated with NTI's cash balance plan for both the three months ended March 31, 2016 and 2015, was $0.6 million.

Postretirement Obligations

The net periodic benefit cost associated with our postretirement medical benefit plans for the three months ended March 31, 2016 and 2015, was $0.03 million and $0.2 million, respectively.

Our benefit obligation at December 31, 2015, for our postretirement medical benefit plans was $6.2 million. We fund our medical benefit plans on an as-needed basis.

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The following table presents cumulative changes in other comprehensive income (loss) related to our benefit plans included as a component of equity for the periods presented, net of income tax. The related expenses are included in direct operating expenses in the Condensed Consolidated Statements of Operations.



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Beginning of period balance	$	651	$	(1,291	)
Reclassification of loss to income	—		13
Income tax	—		(5		)
End of period balance	$	651	$	(1,283	)

Defined Contribution Plan

Western sponsors a 401(k) defined contribution plan under which Western and WNRL participants may contribute a percentage of their eligible compensation to various investment choices offered by the plan. For the three months ended March 31, 2016 and 2015, we expensed $2.0 million, respectively in both periods, in connection with this plan.

NTI sponsors qualified defined contribution plans for eligible employees. For the three months ended March 31, 2016 and 2015, NTI expensed $2.6 million and $2.2 million, respectively, in connection with its qualified defined contribution plans.

13. Crude Oil and Refined Product Risk Management

We enter into crude oil forward contracts primarily to facilitate the supply of crude oil to our refineries. During the three months ended March 31, 2016, we entered into net forward, fixed-price contracts to physically receive and deliver crude oil that qualify as normal purchases and normal sales and are exempt from derivative reporting requirements.

We use crude oil and refined products futures, swap contracts or options to mitigate the change in value for a portion of our LIFO inventory volumes subject to market price fluctuations. We enter into swap contracts to fix differentials on a portion of our future crude oil purchases and to fix margins on a portion of our future gasoline and distillate production. The physical volumes are not exchanged; these contracts are net settled with cash. These hedging activities do not qualify for hedge accounting treatment.

The fair value of these contracts is reflected in the Condensed Consolidated Balance Sheets and the related net gain or loss is recorded within cost of products sold in the Condensed Consolidated Statements of Operations. Quoted prices for similar assets or liabilities in active markets (Level 2) are considered to determine the fair values of the majority of the contracts for the purpose of marking the hedging instruments to market at each period end.

The following tables summarize our economic hedging activity recognized within cost of products sold for the three months ended March 31, 2016 and 2015, and open commodity hedging positions as of March 31, 2016 and December 31, 2015:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Economic hedging results
Realized hedging gain, net	$	17,803		$	17,553
Unrealized hedging loss, net	(12,483		)	(20,057		)
Total hedging gain (loss), net	$	5,320		$	(2,504	)

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	March 31, 2016			December 31, 2015
	(In thousands)
Open commodity hedging instruments (barrels)
Crude oil differential swaps, net long positions	7,201			5,155
Crude oil futures, net short positions	(1,823		)	(562		)
Refined product price and crack spread swaps, net short positions	(2,900		)	(5,645		)
Total open commodity hedging instruments, net long (short) positions	2,478			(1,052		)

Fair value of outstanding contracts, net
Other current assets	$	67,064		$	78,125
Other assets	7,152			11,881
Accrued liabilities	(7,137		)	(10,273		)
Other long-term liabilities	—			—
Fair value of outstanding contracts - unrealized gain, net	$	67,079		$	79,733

Offsetting Assets and Liabilities

Western's derivative financial instruments are subject to master netting arrangements to manage counterparty credit risk associated with derivatives; however, Western does not offset the fair value amounts recorded for derivative instruments under these agreements in the Condensed Consolidated Balance Sheets. We have posted or received margin collateral with various counterparties in support of our hedging and trading activities. The margin collateral posted or received is required by counterparties as collateral deposits and cannot be offset against the fair value of open contracts except in the event of default.

The following table presents offsetting information regarding Western's commodity hedging contracts as of March 31, 2016 and December 31, 2015:



	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of March 31, 2016	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	86,144		$	(19,080	)	$	67,064
Other assets	8,019			(867		)	7,152
Financial liabilities:
Accrued liabilities	(12,647		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	14,437			—
	$	67,079		$	—		$	67,079

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	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of December 31, 2015	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	95,062		$	(16,937	)	$	78,125
Other assets	11,881			—			11,881
Financial liabilities:
Accrued liabilities	(21,454		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	5,756			—
	$	79,733		$	—		$	79,733

Our commodity hedging activities are initiated within guidelines established by management and approved by our board of directors. Due to mark-to-market accounting during the term of the various commodity hedging contracts, significant unrealized, non-cash net gains and losses could be recorded in our results of operations. Additionally, we may be required to collateralize any mark-to-market losses on outstanding commodity hedging contracts.

As of March 31, 2016, we had the following outstanding crude oil and refined product hedging instruments that were entered into as economic hedges. Settlement prices for our unleaded gasoline crack spread swaps range from $14.61 to $17.13 per contract. Settlement prices for our distillate crack spread swaps range from $7.08 to $12.19 per contract. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels):



	Notional Contract Volumes by Year of Maturity
	2016		2017		2018
Inventory positions (futures and swaps):
Crude oil differential swaps, net long positions	5,283		1,918		—
Crude oil futures, net short positions	(1,823	)	—		—
Refined products — net short positions	(999	)	—		—
Natural gas futures — net long positions	720		329		—
Refined product positions (crack spread swaps):
Distillate — net short positions	(744	)	(1,305	)	—
Unleaded gasoline — net short positions	(900	)	—		—

14. Stock-Based Compensation

Western Incentive Plans

The Western Refining 2006 Long-Term Incentive Plan (the "2006 LTIP") and the Amended and Restated 2010 Incentive Plan of Western Refining (the "2010 Incentive Plan") allow for restricted share unit awards ("RSUs") among other forms of awards. As of March 31, 2016, there were 19,856 and 2,418,248 shares of common stock reserved for future grants under the 2006 LTIP and the 2010 Incentive Plan, respectively. Awards granted under both plans vest over a scheduled vesting period of either one, three or five years and their market value at the date of the grant is amortized over the vesting period on a straight-line basis. Effective March 25, 2015, our board of directors approved administrative amendments to the 2010 Incentive Plan.

As of March 31, 2016, there were 656,290 unvested RSUs outstanding. We recorded stock compensation of $1.0 million and $1.0 million for the three months ended March 31, 2016 and 2015, respectively, which is included in selling, general and administrative expenses.

As of March 31, 2016, the aggregate grant date fair value of outstanding RSUs was $21.6 million. The aggregate intrinsic value of outstanding RSUs was $19.1 million. The unrecognized compensation cost of unvested RSUs was $19.6 million. Unrecognized compensation costs for RSUs will be recognized over a weighted-average period of 3.13 years.

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The tax deficiency related to the RSUs that vested during the three months ended March 31, 2016, was $0.3 million using a statutory blended rate of 38.1%. The aggregate grant date fair value of the RSUs that vested during the three months ended March 31, 2016, was $3.2 million. The related aggregate intrinsic value of these RSUs was $2.4 million at the vesting date.

The excess tax benefit related to the RSUs that vested during the three months ended March 31, 2015, was $0.3 million using a statutory blended rate of 38.1%. The aggregate grant date fair value of the RSUs that vested during the three months ended March 31, 2015, was $1.9 million. The related aggregate intrinsic value of these RSUs was $2.8 million at the vesting date.

The following table summarizes our RSU activity for the three months ended March 31, 2016:



	Number of Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	399,214		$	37.43
Awards granted	339,618		29.60
Awards vested	(79,118	)	40.71
Awards forfeited	(3,424	)	43.81
Not vested at March 31, 2016	656,290		32.95

NTI 2012 Long-Term Incentive Plan

There are 6,659,555 NTI common units reserved for issuance under the NTI 2012 Long-Term Incentive Plan ("NTI LTIP"). NTI has awarded both restricted units and phantom units under the NTI LTIP. The NTI LTIP permits the award of unit options, restricted units, phantom units, distribution equivalent rights, unit appreciation rights and other awards that derive their value from the market price of NTI's common units.

As of March 31, 2016, 1,536,998 units were outstanding under the NTI LTIP. NTI recognizes the expense on all NTI LTIP awards ratably from the grant date until all units become unrestricted or vest. Service-based awards generally vest ratably over a three-year period beginning on the award's first anniversary date and performance-based awards generally vest following the end of the measurement period which, for the performance-based phantom awards, has traditionally been three years after the commencement of the measurement period. Compensation expense related to these restricted units is based on the grant date fair value as determined by the closing market price on the grant date, reduced by the fair value of estimated forfeitures. For awards to employees, NTI estimates a forfeiture rate that is subject to revision depending on the actual forfeiture experience.

As of March 31, 2016 and December 31, 2015, the total unrecognized compensation cost for NTI LTIP units was $26.3 million and $16.1 million, respectively.

NTI incurred $4.6 million and $2.6 million of unit-based compensation expense for the three months ended March 31, 2016 and 2015, respectively.

Restricted Common Units

As of March 31, 2016, NTI had 157,370 restricted common units outstanding. Upon vesting, these common units will no longer be restricted. All restricted common units participate in distributions on an equal basis with NTI common units and must be paid no later than 30 days after the distribution date to common unitholders. For restricted common unit awards outstanding at March 31, 2016, the forfeiture rates on NTI LTIP awards ranged from zero to 30%, depending on the employee classification and the length of the award's vesting period. NTI has one restricted common unit award with a clause stating distributions are to be accrued until the underlying units vest, at which time the accrued distributions applicable to those units will be paid to the award holder. The accrued distributions on that award at March 31, 2016 and December 31, 2015, were $0.8 million and $0.7 million, respectively.

Phantom Common Units

Service-based Awards

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common units are accrued until the underlying units vest at which time the distributions are paid in cash. In the event that unvested phantom common units are forfeited or canceled, any accrued distributions on the underlying units are forfeited by the grantee. As of March 31, 2016 and December 31, 2015, NTI had $1.7 million and $2.5 million, respectively, in accrued service-based phantom common unit distributions included in accrued liabilities and other liabilities in the Condensed Consolidated Balance Sheets. For phantom common unit awards outstanding at March 31, 2016, the forfeiture rates on NTI LTIP awards ranged from zero to 20%, depending on the employee classification.

Performance-based Phantom Units

As of March 31, 2016, NTI had 652,786 outstanding Performance-based Phantom Common Units ("NTI Performance LTIPs"), under the NTI LTIP. Assuming a threshold EBITDA is achieved, participants are entitled to an award under the NTI Performance LTIPs based on NTI’s achievement of two criteria compared to the performance peer group selected by the Compensation Committee over the performance period: (a) return on capital employed, referred to as a performance condition and (b) total unitholder return, referred to as a market condition. NTI accounts for the performance conditions and market conditions in each NTI Performance LTIPs as separate awards. Each of the performance condition awards and market condition awards represent the right to receive NTI common units or cash, or a combination of both, at the discretion of NTI's board of directors or its Compensation Committee, at the end of a three-year performance period, in an amount ranging from 0% to 200% of the original number of units granted depending on NTI’s achievement of the performance conditions and market conditions, respectively.

Performance Condition Awards. The 652,786 NTI Performance LTIPs include 342,695 performance condition awards. The fair value of performance condition awards is estimated using the market price of NTI's common units on the grant date and NTI management's assessment of the probability of the number of performance condition awards that will ultimately be awarded. The estimated fair value of these performance condition awards is amortized over a three-year vesting period using the straight-line method. On a quarterly basis, NTI estimates the ultimate payout percentage, relative to target, and adjusts compensation expense accordingly. At March 31, 2016, NTI estimates that a weighted average of 200% of the target unit count will be achieved at the end of the vesting term.

Market Condition Awards. The 652,786 NTI Performance LTIPs include 310,091 market condition awards. The estimated fair value for market condition awards is estimated using a Monte Carlo simulation model as of the grant date and the related expense is amortized over a three-year vesting period using the straight-line method. The compensation expense relating to the market condition awards is determined at the award's date and expensed ratably at a fixed rate over the vesting term. However, for purposes of the phantom common unit activity table below, NTI estimates that at March 31, 2016, a weighted average of 181% of the target unit count will be achieved at the end of the vesting term.

Expected volatilities are based on the historical volatility over the most recent three-year period. The risk-free rate is based on the U.S. Treasury yield curve in effect at the date of valuation. The assumptions used in the Monte Carlo simulation used to value NTI's market condition awards as of March 31, 2016, are presented below:



	2016 Awards		2015 Awards
Expected volatility	29.80	%	34.10	%
Risk-free interest rate	1.08	%	0.84	%

As of March 31, 2016 and December 31, 2015, NTI had $1.5 million and $1.0 million, respectively, in accrued performance-based phantom common unit distributions included in accrued liabilities in the Condensed Consolidated Balance Sheets.

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A summary of the NTI LTIP common unit activity for the three months ended March 31, 2016, is set forth below:



	Restricted Units				Phantom Units
	Restricted Units				Service-Based Units		Performance-Based Units		Total		Weighted Average Grant Date Fair Value
	Number of Units		Weighted Average Grant Date Fair Value		Number of Units		Number of Units		Total		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	191,424		$	24.75	581,882		260,690		842,572		$	24.00
Awards granted	—		—		381,029		163,571		544,600		30.27
Incremental performance units	—		—		—		231,777		231,777		38.17
Awards vested	(34,054	)	26.84		(235,546	)	(1,789	)	(237,335	)	24.05
Awards forfeited	—		—		(523	)	(1,463	)	(1,986	)	24.01
Not vested at March 31, 2016	157,370		24.30		726,842		652,786		1,379,628		28.90

Western Refining Logistics, LP 2013 Long-Term Incentive Plan

The Western Refining Logistics, LP 2013 Long-Term Incentive Plan (the "WNRL LTIP") provides, among other awards, for grants of phantom units and distribution equivalent rights. As of March 31, 2016, there were 4,111,322 phantom units reserved for future grants under the WNRL LTIP.

The fair value of the phantom units is determined based on the closing price of WNRL common units on the grant date. The estimated fair value of the phantom units is amortized on a straight-line basis over the scheduled vesting periods of individual awards. WNRL incurred unit-based compensation expense of $0.5 million and $0.4 million for the three months ended March 31, 2016 and 2015, respectively.

The aggregate grant date fair value of non-vested phantom units outstanding as of March 31, 2016, was $7.9 million. The aggregate intrinsic value of such phantom units was $6.9 million. Total unrecognized compensation cost related to unvested phantom units totaled $7.4 million as of March 31, 2016, that is expected to be recognized over a weighted-average period of 3.12 years.

A summary of WNRL's common and phantom unit award activity for the three months ended March 31, 2016, is set forth below:



	Number of Phantom Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	279,787		$	28.06
Awards granted	75,919		22.53
Awards vested	(60,705	)	26.80
Awards forfeited	—		—
Not vested at March 31, 2016	295,001		26.64

15. Earnings per Share

We follow the provisions related to the accounting treatment of certain participating securities for the purpose of determining earnings per share. These provisions address share-based payment awards that have not vested and that contain nonforfeitable rights to dividend equivalents and state that they are participating securities and should be included in the computation of earnings per share pursuant to the two-class method.

Diluted earnings per common share includes the effects of potentially dilutive shares that consist of unvested RSUs. These awards are non-participating securities due to the forfeitable nature of their associated dividend equivalent rights, prior to vesting and we do not consider the RSUs in the two-class method when calculating earnings per share.

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(Unaudited)

The computation of basic and diluted earnings per share under the two-class method is presented as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands, except per share data)
Basic earnings per common share:
Allocation of earnings:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Distributed earnings	(35,601		)	(28,638		)
Undistributed income (loss) available to Western Refining, Inc.	$	(5,063	)	$	77,351
Weighted-average number of common shares outstanding	92,078			95,567
Basic earnings per common share:
Distributed earnings per share	$	0.39		$	0.30
Undistributed earnings (loss) per share	(0.05		)	0.81
Basic earnings per common share	$	0.34		$	1.11

Diluted earnings per common share:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Weighted-average diluted common shares outstanding	92,144			95,682
Diluted earnings per common share	$	0.33		$	1.11

The computation of the weighted average number of diluted shares outstanding is presented below:



	Three Months Ended
	March 31,
	2016	2015
	(In thousands)
Weighted-average number of common shares outstanding	92,078	95,567
Restricted share units	66	115
Weighted-average number of diluted shares outstanding	92,144	95,682

A shareholder's interest in our common stock could become diluted as a result of vestings of RSUs. In calculating our fully diluted earnings per common share, we consider the impact of RSUs that have not vested. We include unvested RSUs in our diluted earnings calculation when the trading price of our common stock equals or exceeds the per share or per share unit grant price. In connection with the Merger Agreement, we may grant additional RSUs to NTI employees. The Merger Agreement is expected to result in 17.2 million additional shares of Western Common Stock outstanding. The issuance of these additional shares may have a dilutive impact on our earnings per share.

16. Cash Flows

Restricted Cash

Restricted cash reported in our Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015, relates to net proceeds from the sale of Western's TexNew Mex Pipeline System to WNRL. This cash is restricted through October 30, 2016, and must be used to reinvest in assets used in our business or as an offer of prepayment to lenders under the Western 2020 Term Loan Credit Facility.

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Supplemental Cash Flow Information

Supplemental disclosures of cash flow information were as follows:



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Income taxes paid	$	11,215	$	40,009
Interest paid, excluding amounts capitalized	20,676		8,959

Non-cash investing and financing activities were as follows:
Assets acquired through capital lease obligations	$	328	$	19,511
Accrued capital expenditures	46,045		12,741
Distributions receivable from equity method investee	—		3,740
Distributions accrued on unvested NTI equity awards	3,964		—
Transfer of capital spares from fixed assets to other assets	699		—

17. Leases and Other Commitments

We have commitments under various operating leases with initial terms greater than one year for retail convenience stores, office space, warehouses, cardlocks, railcars and other facilities, some of which have renewal options and rent escalation clauses. These leases have terms that will expire on various dates through 2040. We expect that in the normal course of business, these leases will be renewed or replaced by other leases. Certain of our lease agreements provide for the fair value purchase of the leased asset at the end of the lease. Rent expense for operating leases that provide for periodic rent escalations or rent holidays over the term of the lease and for renewal periods that are reasonably assured at the inception of the lease are recognized on a straight-line basis over the term of the lease.

In the normal course of business, we also have long-term commitments to purchase products and services, such as natural gas, electricity, water and transportation services for use by our refineries and logistic assets at market-based rates. We are also party to various refined product and crude oil supply and exchange agreements.

Under a sulfuric acid regeneration and sulfur gas processing agreement with The Chemours Company FC, LLC (“Chemours”), Chemours constructed and operates two sulfuric acid regeneration units on property we leased to Chemours within our El Paso refinery. Our annual estimated cost for processing sulfuric acid and sulfur gas under this agreement is $15.7 million through March of 2028.

In November 2007, we entered into a ten-year lease agreement for office space in downtown El Paso, Texas. The building serves as our headquarters. In December 2007, we entered into an eleven-year lease agreement for an office building in Tempe, Arizona. The building centralized our operational and administrative offices in the Phoenix area.

We are party to 38 capital leases, with initial terms of 20 years, expiring in 2017 through 2036. The current portion of our capital lease obligation of $1.1 million and $1.0 million is included in accrued liabilities and the non-current portion of $53.2 million and $53.2 million is included in lease financing obligations in the accompanying Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015, respectively. The capital lease obligations include a deferred gain of $2.2 million.

These capital leases were discounted using annual rates of 3.24% and 10.51%. Total remaining interest related to these leases was $43.5 million and $44.1 million at March 31, 2016 and December 31, 2015, respectively. Average annual payments, including interest, for the next five years are $5.2 million with the remaining $70.9 million due through 2036. Of the 38 capital leases, 19 are NTI obligations with annual lease payments, including interest, that average $1.3 million annually through the end of 2020 with the remaining $14.2 million due through 2036. There is no recourse to Western on the NTI capital leases. The remaining 19 capital leases are held by our retail segment and make up the balance of the annual payments for the periods noted above.

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The following table presents our future minimum lease commitments under capital leases and non-cancelable operating leases that have lease terms of one year or more (in thousands) as of March 31, 2016:



	Operating		Capital
Remaining 2016	$	43,908	$	3,859
2017	52,828		5,060
2018	49,495		5,084
2019	44,407		5,195
2020	40,218		5,386
2021 and thereafter	340,046		70,941
Total minimum lease payments	$	570,902	95,525
Less amount that represents interest			43,476
Present value of net minimum capital lease payments			$	52,049

Total rental expense was $17.7 million and $15.9 million for the three months ended March 31, 2016 and March 31, 2015, respectively. Contingent rentals and subleases were not significant in any period.

18. Contingencies

Environmental Matters

Similar to other petroleum refiners, our operations are subject to extensive and periodically changing federal and state environmental regulations governing air emissions, wastewater discharges and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent and the cost of compliance can be expected to increase over time. Our policy is to accrue environmental and clean-up related costs of a non-capital nature when it is probable that a liability has been incurred and the amount can be reasonably estimated. Such estimates may be subject to revision in the future as regulations and other conditions change.

Periodically, we receive communications from various federal, state and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective action for these asserted violations. We intend to respond in a timely manner to all such communications and to take appropriate corrective action. We do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations or cash flows. As of March 31, 2016 and December 31, 2015, we had consolidated environmental accruals of $19.4 million and $18.3 million, respectively.

El Paso Refinery

Prior spills, releases and discharges of petroleum or hazardous substances have impacted the groundwater and soils in certain areas at and adjacent to our El Paso refinery. We are currently remediating, in conjunction with Chevron U.S.A., Inc. ("Chevron"), these areas in accordance with certain agreed administrative orders with the Texas Commission on Environmental Quality (the "TCEQ"). Pursuant to our purchase of the north side of the El Paso refinery from Chevron, Chevron retained responsibility to remediate its solid waste management units in accordance with its Resource Conservation Recovery Act ("RCRA") permit that Chevron has fulfilled. Chevron also retained control of and liability for certain groundwater remediation responsibilities that are ongoing.

In May 2000, we entered into an Agreed Order with the TCEQ for remediation of the south side of our El Paso refinery property. We purchased a non-cancelable Pollution and Legal Liability and Clean-Up Cost Cap Insurance policy that covers environmental clean-up costs related to contamination that occurred prior to December 31, 1999, including the costs of the Agreed Order activities. The insurance provider assumed responsibility for all environmental clean-up costs related to the Agreed Order up to $20.0 million, of which $6.6 million remained as of March 31, 2016. In addition, a subsidiary of Chevron is obligated under a settlement agreement to pay 60% of any Agreed Order environmental clean-up costs that exceed the $20.0 million policy coverage.

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Four Corners Refineries

Four Corners 2005 Consent Agreements. In July 2005, as part of the EPA Initiative, Giant Industries, Inc., our wholly-owned subsidiary, reached an administrative settlement with the New Mexico Environment Department (the "NMED") and the EPA in the form of consent agreements that resolved certain alleged violations of air quality regulations at the Gallup and Bloomfield refineries in the Four Corners area of New Mexico. In January 2009 and June 2012, we and the NMED agreed to amendments of the 2005 administrative settlement (the "2005 NMED Amended Agreement") that altered certain deadlines and allowed for alternative air pollution controls.

We incurred $50.8 million in total capital expenditures between 2009 and 2013 to address the requirements of the 2005 NMED Amended Agreement. These capital expenditures were primarily for installation of emission controls on the heaters, boilers and Fluid Catalytic Cracking Unit ("FCCU") and for reducing sulfur in fuel gas to reduce emissions of sulfur dioxide, NOx and particulate matter from our Gallup refinery. As of March 31, 2016, we have completed the capital expenditures required by the 2005 NMED Amended Agreement to implement one or more FCCU emission offset projects prior to the end of 2017. We incurred $0.1 million and $1.9 million, respectively, for the years ended December 31, 2015 and 2014, and $0.1 million in the three months ended March 31, 2016 to implement an FCC emission offset project. We paid penalties between 2009 and 2012 totaling $2.7 million.

Bloomfield 2007 NMED Remediation Order. In July 2007, we received a final administrative compliance order from the NMED alleging that releases of contaminants and hazardous substances that have occurred at the Bloomfield refinery over the course of its operation prior to June 1, 2007, have resulted in soil and groundwater contamination. Among other things, the order requires that we investigate the extent of such releases, perform interim remediation measures and implement corrective measures. Prior to July 2007, with the approval of the NMED and the New Mexico Oil Conservation Division, we placed into operation certain remediation measures that remain operational.

Gallup 2014 Environment Protection Division of NMED Settlement. In March 2014, we received a revised notice of violation and offer of settlement from the NMED Air Quality Bureau for alleged violations of the Clean Air Act. We agreed to settle and paid a penalty of $0.1 million in May 2014. No capital expenditures are required under the settlement.

NTI

At March 31, 2016 and December 31, 2015, liabilities for remediation and closure obligations by NTI totaled $8.5 million and $8.6 million, respectively, of which $2.5 million and $2.6 million, respectively, are recorded on a discounted basis. These discounted liabilities are expected to be settled over at least the next 22 years. At March 31, 2016, the estimated future cash flows to settle these discounted liabilities totaled $3.0 million and are discounted at a rate of 2.27%. Receivables for recoverable costs from the state, under programs to assist companies in clean-up efforts related to underground storage tanks at retail marketing outlets, and others were $0.1 million and $0.2 million at March 31, 2016 and December 31, 2015, respectively.

On June 3, 2014, the St. Paul Park refinery was issued a National Pollutant Discharge Elimination Permit/State Disposal System Permit by the Minnesota Pollution Control Agency ("MPCA") relating to its upgraded wastewater treatment plant at its St. Paul Park refinery. This permit required the refinery to conduct additional testing of its remaining lagoon. The testing was completed in the fourth quarter of 2014, following NTI's review of the test results and additional discussions with MPCA, NTI plans to close the remaining lagoon. At March 31, 2016 and December 31, 2015, NTI estimated the remediation and closure costs to be $6.0 million, subject to receipt of final bids from contractors. In connection with NTI's December 2010 acquisition of the St. Paul Park refinery, among other assets, from the Marathon Petroleum Company LP ("Marathon"), NTI entered into an agreement with Marathon that required Marathon to share in the future remediation costs of this lagoon, should they be required. During the third quarter of 2015, NTI entered into a settlement and release agreement with Marathon and received $3.5 million pursuant to this settlement that NTI recorded as a reduction of direct operating expenses.

Other Matters

The EPA has issued Renewable Fuels Standards ("RFS"), that require us and other refiners to blend renewable fuels into the refined products produced at our refineries. Annually, the EPA is required to establish a volume of renewable fuels that refineries must blend into their refined petroleum fuels. To the extent we are unable to blend at the rate necessary to satisfy the EPA mandated volume, we purchase Renewable Identification Numbers ("RINs"). The purchase price for RINs is volatile and may vary significantly from period to period. The net cost of meeting our estimated renewable volume obligations, including sales and purchases of RINs, was $13.6 million and $6.2 million for the three months ended March 31, 2016 and 2015, respectively. The supply and demand environment for RINs is uncertain and we cannot predict the impact of RINs purchases on our results of operations in any given period.

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In addition, the EPA has investigated and brought enforcement actions against companies it believes produced invalid RINs. We may have purchased RINs that the EPA will determine are invalid. Previously, we have entered into settlements and entered into another settlement in May 2015, with the EPA regarding RINs we purchased that the EPA ultimately determined were invalid. While we do not know if the EPA will determine that other RINs we have purchased are invalid, at this time we do not expect any settlements we would enter into with the EPA would have a material effect on our financial condition, results of operations or cash flows.

We are party to various other claims and legal actions arising in the normal course of business. We believe that the resolution of these matters will not have a material effect on our financial condition, results of operations or cash flows.

19. Related Party Transactions

We lease office space in a building located in El Paso, Texas that is owned by an entity controlled by one of our officers. The lease agreement expires in May 2017. Under the terms of the lease, we make annual payments of $0.2 million. For the three months ended March 31, 2016 and 2015, we made rental payments under this lease to the related party of $0.06 million. We have no amounts due as of March 31, 2016, related to this lease agreement.

Beginning on September 30, 2014, NTI began paying MPL for transportation services at published tariff rates. During the three months ended March 31, 2016 and 2015, NTI paid $14.0 million and $12.7 million, respectively, in crude transportation costs with MPL. Prior to September 30, 2014, NTI had a crude oil supply and logistics agreement with a third-party and had no direct supply transactions with MPL prior to this date. NTI's Chief Executive Officer is a member of MPL's board of managers.

20. Condensed Consolidating Financial Information

Separate condensed consolidating financial information of Western Refining, Inc. (the "Parent"), subsidiary guarantors and non-guarantors is presented below. At March 31, 2016, the Parent and certain subsidiary guarantors have fully and unconditionally guaranteed our Western 2021 Senior Unsecured Notes on a joint and several basis. NTI and WNRL are subsidiaries that have not guaranteed the Western 2021 Senior Unsecured Notes. As a result of the Parent and certain subsidiaries' guarantee arrangements, we are required to present the following condensed consolidating financial information that should be read in conjunction with the accompanying condensed consolidated financial statements and notes thereto.

Due to the retrospective adjustments of financial position, results of operations and cash flows from the guarantor to the non-guarantor entities resulting from the TexNew Mex Pipeline Transaction, we have revised the condensed consolidating financial information for all periods presented. See Note 1, Organization, for additional information on this transaction.

NTI and WNRL are publicly held master limited partnerships. As of March 31, 2016, we owned a 38.3% limited partnership interest in NTI and a 66.4% limited partnership interest in WNRL, and the non-financial general partner interests of both entities. We are the primary beneficiary of WNRL's earnings and cash flows. We exercise control of both NTI and WNRL through our 100% ownership of the respective general partners. Accordingly, NTI and WNRL are consolidated with the other accounts of Western.

Our transactions with WNRL, including fees paid under our pipeline, terminalling and services agreements, are eliminated and have no impact on our condensed consolidated financial statements. All intercompany accounts and transactions with NTI and WNRL are eliminated in our condensed consolidated financial statements.

NTI's long-term debt is comprised of its NTI 2020 Secured Notes and the NTI Revolving Credit Facility. NTI creditors under the NTI 2020 Secured Notes and the NTI Revolving Credit Facility have no recourse to the Parent's assets except to the extent of the assets of Northern Tier Energy GP LLC, the general partner of NTI that we wholly own. Any recourse to NTI’s general partner would be limited to the extent of the general partner’s assets that other than its investment in NTI are not significant. Furthermore, the Parent's creditors have no recourse to the assets of NTI's general partner, NTI and its consolidated subsidiaries. See Note 9, Long-Term Debt, for a description of NTI’s debt obligations.

WNRL generates revenues by charging fees and tariffs for transporting crude oil through its pipelines and truck fleet, for transporting refined and other products through its terminals and pipelines, for providing storage in its storage tanks and at its terminals and selling refined products through its wholesale distribution network. We do not provide financial or equity support through any liquidity arrangements and/or debt guarantees to WNRL.

WNRL's long-term debt is comprised of the WNRL 2023 Senior Notes and the WNRL Revolving Credit Facility. With the exception of the assets of Western Refining Logistic GP, LLC, the general partner of WNRL, creditors have no recourse to our assets. Any recourse to WNRL’s general partner would be limited to the extent of Western Refining Logistic GP, LLC’s assets which, other than its investment and incentive distribution rights in WNRL, are not significant. Furthermore, our creditors have

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no recourse to the assets of WNRL and its consolidated subsidiaries. See Note 9, Long-Term Debt, for a description of WNRL’s debt obligations.

NTI and WNRL have risks associated with their respective operations. NTI’s risks, while similar to ours because it experiences similar industry dynamics, are not associated with our operations. WNRL’s risks are directly associated with our operations. If we suffer significant decreases in our throughput or fail to meet desired shipping or throughput levels for an extended period of time, WNRL revenues would be reduced and WNRL could suffer substantial losses.

In the event that NTI or WNRL incur a loss, our operating results will reflect NTI's or WNRL’s loss, net of intercompany eliminations, to the extent of our ownership interests in NTI and WNRL at that point in time.

The following condensed consolidating financial information is provided as an alternative to providing separate financial statements for guarantor subsidiaries. Separate financial statements of Western’s subsidiary guarantors are not included because the guarantees are full and unconditional and these subsidiary guarantors are 100% owned and jointly and severally liable for the Parent’s outstanding debt. The information is presented using the equity method of accounting for investments in subsidiaries.

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(Unaudited)

CONDENSED CONSOLIDATING BALANCE SHEETS

As of March 31, 2016

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	529,460	$	63,620	$	—		$	593,101
Accounts receivable, trade, net of a reserve for doubtful accounts	—		104,551		232,526		—			337,077
Accounts receivable, affiliate	3,007		66,012		2,544		(71,563		)	—
Inventories	—		419,692		263,901		—			683,593
Prepaid expenses	—		61,472		18,499		—			79,971
Other current assets	—		118,778		40,813		—			159,591
Total current assets	3,028		1,299,965		621,903		(71,563		)	1,853,333
Restricted cash	—		36,783		—		—			36,783
Equity method investment	—		—		102,971		—			102,971
Property, plant and equipment, net	—		1,106,879		1,217,712		—			2,324,591
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,923		53,352		—			85,275
Investment in subsidiaries	3,994,766		—		—		(3,994,766		)	—
Due from affiliate	—		1,894,627		—		(1,894,627		)	—
Other assets, net	—		37,975		23,391		—			61,366
Total assets	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	10,938	$	251,898	$	299,594	$	—		$	562,430
Accounts payable, affiliate	—		—		71,563		(71,563		)	—
Accrued liabilities	10,975		110,587		97,190		—			218,752
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	27,413		362,485		468,347		(71,563		)	786,682
Long-term liabilities:
Long-term debt, less current portion	856,520		—		796,072		—			1,652,592
Due to affiliate	1,894,627		—		—		(1,894,627		)	—
Lease financing obligation	—		41,943		11,247		—			53,190
Deferred income tax liability, net	—		304,195		37,280		—			341,475
Deficit in subsidiaries	—		399,553		—		(399,553		)	—
Other liabilities	—		64,489		4,534		—			69,023
Total long-term liabilities	2,751,147		810,180		849,133		(2,294,180		)	2,116,280
Equity:
Equity - Western	1,219,234		3,235,487		359,726		(3,595,213		)	1,219,234
Equity - Non-controlling interest	—		—		1,631,566		—			1,631,566
Total equity	1,219,234		3,235,487		1,991,292		(3,595,213		)	2,850,800
Total liabilities and equity	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762

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CONDENSED CONSOLIDATING BALANCE SHEETS

As of December 31, 2015

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	656,966	$	115,515	$	—		$	772,502
Accounts receivable, trade, net of a reserve for doubtful accounts	—		122,593		236,644		—			359,237
Accounts receivable, affiliate	—		55,550		3,505		(59,055		)	—
Inventories	—		311,589		235,949		—			547,538
Prepaid expenses	—		55,699		17,514		—			73,213
Other current assets	—		135,139		34,589		—			169,728
Total current assets	21		1,337,536		643,716		(59,055		)	1,922,218
Restricted cash	—		69,106		—		—			69,106
Equity method investment	—		—		97,513		—			97,513
Property, plant and equipment, net	—		1,099,787		1,205,384		—			2,305,171
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,401		53,544		—			84,945
Investment in subsidiaries	3,964,578		—		—		(3,964,578		)	—
Due from affiliate	—		1,797,047		—		(1,797,047		)	—
Other assets, net	—		42,166		22,831		—			64,997
Total assets	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	—	$	262,550	$	291,407	$	—		$	553,957
Accounts payable, affiliate	920		—		58,135		(59,055		)	—
Accrued liabilities	5,508		142,257		100,630		—			248,395
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	11,928		404,807		450,172		(59,055		)	807,852
Long-term liabilities:
Long-term debt, less current portion	856,327		—		788,567		—			1,644,894
Due to affiliate	1,797,047		—		—		(1,797,047		)	—
Lease financing obligation	—		42,168		11,064		—			53,232
Deferred income tax liability, net	—		275,634		37,280		—			312,914
Deficit in subsidiaries	—		395,774		—		(395,774		)	—
Other liabilities	—		63,674		4,921		—			68,595
Total long-term liabilities	2,653,374		777,250		841,832		(2,192,821		)	2,079,635
Equity:
Equity - Western	1,299,297		3,194,986		373,818		(3,568,804		)	1,299,297
Equity - Non-controlling interest	—		—		1,646,609		—			1,646,609
Total equity	1,299,297		3,194,986		2,020,427		(3,568,804		)	2,945,906
Total liabilities and equity	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,004,540		$	965,512		$	(514,548	)	$	1,455,504
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			798,548			763,361			(514,548		)	1,047,361
Direct operating expenses (exclusive of depreciation and amortization)	—			106,540			117,045			—			223,585
Selling, general and administrative expenses	46			24,695			28,544			—			53,285
Gain on disposal of assets, net	—			(26		)	(104		)	—			(130		)
Maintenance turnaround expense	—			125			—			—			125
Depreciation and amortization	—			25,538			27,113			—			52,651
Total operating costs and expenses	46			955,420			935,959			(514,548		)	1,376,877
Operating income (loss)	(46		)	49,120			29,553			—			78,627
Other income (expense):
Equity in earnings of subsidiaries	43,725			9,304			—			(53,029		)	—
Interest income	—			114			50			—			164
Interest and debt expense	(13,141		)	(738		)	(12,802		)	—			(26,681		)
Other, net	—			1,069			5,035			—			6,104
Income before income taxes	30,538			58,869			21,836			(53,029		)	58,214
Provision for income taxes	—			(18,368		)	(261		)	—			(18,629		)
Net income	30,538			40,501			21,575			(53,029		)	39,585
Less net income attributable to non-controlling interests	—			—			9,047			—			9,047
Net income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538
Comprehensive income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,783,100		$	1,305,172		$	(769,542	)	$	2,318,730
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			1,488,688			1,022,164			(769,542		)	1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	—			109,235			106,076			—			215,311
Selling, general and administrative expenses	47			29,530			26,226			—			55,803
Loss (gain) on disposal of assets, net	—			381			(99		)	—			282
Maintenance turnaround expense	—			105			—			—			105
Depreciation and amortization	—			24,669			25,257			—			49,926
Total operating costs and expenses	47			1,652,608			1,179,624			(769,542		)	2,062,737
Operating income (loss)	(47		)	130,492			125,548			—			255,993
Other income (expense):
Equity in earnings of subsidiaries	119,759			8,228			—			(127,987		)	—
Interest income	—			97			66			—			163
Interest and debt expense	(13,723		)	(507		)	(10,727		)	—			(24,957		)
Other, net	—			45			3,161			—			3,206
Income before income taxes	105,989			138,355			118,048			(127,987		)	234,405
Provision for income taxes	—			(59,234		)	(203		)	—			(59,437		)
Net income	105,989			79,121			117,845			(127,987		)	174,968
Less net income attributable to non-controlling interests	—			—			68,979			—			68,979
Net income attributable to Western Refining, Inc.	$	105,989		$	79,121		$	48,866		$	(127,987	)	$	105,989
Comprehensive income attributable to Western Refining, Inc.	$	105,989		$	79,129		$	48,866		$	(127,987	)	$	105,997

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	4,786		$	(21,284	)	$	30,994		$	(13,392	)	$	1,104
Cash flows from investing activities:
Capital expenditures	—			(44,798		)	(34,231		)	—			(79,029		)
Return of capital from equity method investment	13,537			—			—			(13,537		)	—
Use of restricted cash	—			32,323			—			—			32,323
Contributions to affiliate	—			(93,653		)	—			93,653			—
Proceeds from the sale of assets	—			100			119			—			219
Net cash provided by (used in) investing activities	13,537			(106,028		)	(34,112		)	80,116			(46,487		)
Cash flows from financing activities:
Payments on long-term debt and capital lease obligations	(1,375		)	(194		)	(353		)	—			(1,922		)
Borrowings on revolving credit facility	—			—			70,000			—			70,000
Repayments on revolving credit facility	—			—			(62,500		)	—			(62,500		)
Distribution to affiliate	—			—			(26,929		)	26,929			—
Purchases of common stock for treasury	(75,000		)	—			—			—			(75,000		)
Distribution to non-controlling interest holders	—			—			(28,995		)	—			(28,995		)
Dividends paid	(35,601		)	—			—			—			(35,601		)
Contributions from affiliates	93,653			—			—			(93,653		)	—
Net cash used in financing activities	(18,323		)	(194		)	(48,777		)	(66,724		)	(134,018		)
Net decrease in cash and cash equivalents	—			(127,506		)	(51,895		)	—			(179,401		)
Cash and cash equivalents at beginning of year	21			656,966			115,515			—			772,502
Cash and cash equivalents at end of year	$	21		$	529,460		$	63,620		$	—		$	593,101

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	12,172		$	4,907		$	115,668		$	(27,769	)	$	104,978
Cash flows from investing activities:
Capital expenditures	—			(20,526		)	(33,317		)	648			(53,195		)
Use of restricted cash	—			43,400			—			—			43,400
Contributions to affiliate	—			(61,636		)	—			61,636			—
Proceeds from the sale of assets	—			1,093			179			(648		)	624
Net cash provided by (used in) investing activities	—			(37,669		)	(33,138		)	61,636			(9,171		)
Cash flows from financing activities:
Additions to long-term debt	—			—			300,000			—			300,000
Payments on long-term debt and capital lease obligations	(1,375		)	—			—			—			(1,375		)
Repayments on revolving credit facility	—			—			(269,000		)	—			(269,000		)
Distribution to affiliate	—			—			(27,769		)	27,769			—
Deferred financing costs	—			—			(6,551		)	—			(6,551		)
Purchases of common stock for treasury	(25,000		)	—			—			—			(25,000		)
Distribution to non-controlling interest holders	—			—			(33,665		)	—			(33,665		)
Dividends paid	(28,638		)	—			—			—			(28,638		)
Contributions from affiliates	42,841			—			18,795			(61,636		)	—
Excess tax benefit from stock-based compensation	—			337			—			—			337
Net cash provided by (used in) financing activities	(12,172		)	337			(18,190		)	(33,867		)	(63,892		)
Net increase (decrease) in cash and cash equivalents	—			(32,425		)	64,340			—			31,915
Cash and cash equivalents at beginning of year	21			288,986			142,152			—			431,159
Cash and cash equivalents at end of year	$	21		$	256,561		$	206,492		$	—		$	463,074

21. NTI

On December 21, 2015, Western entered into the Merger Agreement, by and among Western, MergerCo, NTI and Northern Tier Energy GP LLC, the general partner of NTI and a wholly-owned subsidiary of Western (“NTI GP”). Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo will merge with and into NTI, the separate limited liability company existence of MergerCo will cease and NTI will continue to exist, as a limited partnership under Delaware law and as an indirect wholly-owned subsidiary of Western, as the surviving entity in the Merger.

NT InterHoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("NT InterHoldCo"), owns 100% of the membership interests in NTI GP and 38.3% of NTI’s outstanding common units representing limited partner interests in NTI (“NTI Common Units”). NT InterHoldCo also owns 100% of the membership interests in Western Acquisition Holdings, LLC, a Delaware limited liability company and holder of 100% of the membership interests in MergerCo (“MergerCo HoldCo”). Following the Merger, NTI GP will remain the sole general partner of NTI, the NTI Common Units held by Western and its subsidiaries will be unchanged and remain issued and outstanding, and, by virtue of the Merger, all of the membership interests in MergerCo will automatically be converted into the number of NTI Common Units (excluding any NTI Common Units owned by Western and its subsidiaries) issued and outstanding immediately prior to the effective time of the Merger (the “Effective Time”). Consequently, NT InterHoldCo and its wholly-owned subsidiary, MergerCo HoldCo, will become the sole limited partners of NTI. At the Effective Time, each of the outstanding NTI Common Units held by the NTI Public Unitholders will be converted into the right to receive, subject to election by the NTI Public

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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western Common Stock (the “Standard Mix of Consideration”), (ii) $26.06 in cash without interest (the “Cash Election”), or (iii) 0.7036 of a share of Western Common Stock (the “Stock Election”). The Cash and Stock Elections will be subject to proration to ensure that the total amount of cash paid and the total number of shares of Western Common Stock issued and delivered (which may include shares of Western Common Stock held in treasury by Western and reissued) in the Merger to NTI Public Unitholders as a whole are equal to the total amount of cash and number of shares of Western Common Stock that would have been paid and issued if all NTI Public Unitholders received the Standard Mix of Consideration. The transaction is expected to result in the payment and delivery of $862.3 million in cash and 17.2 million shares of Western Common Stock to the NTI Public Unitholders.

The parties anticipate that the Merger will close in the second quarter of 2016, pending the satisfaction of certain customary conditions thereto. Pursuant to the terms of the Merger Agreement, with respect to the Closing Date, NTI will, to the extent it generates available cash in such quarter, make a prorated quarterly cash distribution to all NTI common unitholders, including NT InterHoldCo, for the portion of the quarter that NTI Public Unitholders own NTI Common Units prior to the Closing Date, in the event that NTI Public Unitholders who receive Western Common Stock in the Merger would not receive a dividend with respect to the Western Common Stock received in the Merger, due to the record date for such dividend occurring before the Closing Date. Any prorated quarterly distribution for the quarter in which the Closing Date occurs would be paid to NTI Public Unitholders as of the Effective Time for the Merger, together with the merger consideration payable with respect to the Merger.

The Merger Agreement contains customary representations, warranties, covenants and agreements by each of the parties. Completion of the Merger is conditioned upon, among other things: (1) approval of the Merger Agreement and the transactions contemplated by the Merger Agreement, including the Merger (the “Merger Transactions”), by the affirmative vote of NTI common unitholders, as of the record date for the NTI special meeting, holding a majority of the outstanding NTI Common Units; (2) any waiting period applicable to the Merger Transactions under the Hart-Scott-Rodino Antitrust Act of 1976, as amended (the “HSR Act”) having been terminated or expired; (3) all filings, consents, approvals, permits and authorizations required to be made or obtained prior to the Effective Time in connection with the Merger Transactions having been made or obtained; (4) the absence of legal injunctions or impediments prohibiting the Merger Transactions; (5) the effectiveness of a registration statement on Form S-4 (the “Registration Statement”) with respect to the issuance of new shares of Western Common Stock in the Merger; and (6) approval of the listing on the New York Stock Exchange, subject to official notice of issuance, of the new shares of Western Common Stock to be issued and delivered (or, to the extent held in treasury by Western, delivered but not issued) in the Merger. On January 29, 2016, the United States Federal Trade Commission granted early termination of the waiting periods applicable to the Merger Transactions under the HSR Act. Pursuant to the Merger Agreement, Western has agreed to vote the NTI common units owned beneficially or of record by it or any of its subsidiaries in favor of the adoption and approval of the Merger Agreement and the Merger Transactions.

The Board of Directors of Western has approved the Merger Agreement and the Merger Transactions. The NTI GP Conflicts Committee, acting for NTI GP in its capacity as the general partner of NTI, approved the Merger Agreement and the Merger Transactions, and determined that the Merger Agreement and the Merger Transactions are fair and reasonable to NTI and the holders of NTI Common Units other than NTI GP and its affiliates (the “NTI Unaffiliated Unitholders”) and are not adverse to the interests of NTI or the interests of the NTI Unaffiliated Unitholders.

On January 19, 2016, Western filed a preliminary registration statement on Form S-4 (the “Preliminary S-4”) to register the shares of Western Common Stock to be issued and delivered (or, to the extent held in treasury by Western, delivered but not issued) in the Merger. Western filed two subsequent amendments to the Preliminary S-4 on March 18 and April 19, 2016, in response to review and comments by the Securities and Exchange Commission (the “SEC”). On each respective filing date, the parties to the Merger Agreement jointly filed a transaction statement on Schedule 13E-3 ("Schedule 13-E") that discloses the material terms of the Merger Transactions. Both the preliminary S-4 and the Schedule 13-E are currently under review by the SEC and are subject to future amendments.

22. WNRL

WNRL is a publicly held master limited partnership that owns and operates logistic assets that consist of pipeline and gathering, terminalling, storage and transportation assets, providing related services to our refining segment in the Southwest, including 685 miles of pipelines and 8.2 million barrels of active storage capacity. The majority of WNRL's logistics assets are integral to the operations of the El Paso and Gallup refineries.

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WESTERN REFINING, INC. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Nevada, New Mexico and Texas. WNRL purchases petroleum fuels and lubricants from our refining segment and from third-party suppliers.

As of March 31, 2016, we owned a 66.4% interest in WNRL and a 100% general partner interest. As the general partner of WNRL, we have the sole ability to direct the activities that most significantly impact WNRL's financial performance, and therefore we consolidate WNRL.

We are WNRL’s primary logistics customer and a significant wholesale customer through our retail business. WNRL generates revenues by charging tariffs for transporting petroleum products and crude oil though its pipelines, by charging fees for terminalling refined products and other hydrocarbons, and storing and providing other services at its storage tanks and terminals. Additionally, WNRL sells various finished petroleum products to us and other third party customers. Under our long-term agreements with WNRL (discussed below), we accounted for 31.9% and 29.3% of WNRL’s total revenues for the three month periods ended March 31, 2016 and 2015, respectively. We do not provide financial or equity support through any liquidity arrangements and/or debt guarantees to WNRL.

WNRL has outstanding debt under a senior secured revolving credit facility and its senior notes. Excluding assets held by WNRL, WNRL’s creditors have no recourse to our assets. Any recourse to WNRL’s general partner would be limited to the extent of Western Refining Logistics GP LLC.’s assets that other than its investment in WNRL, are not significant. Our creditors have no recourse to the assets of WNRL and its consolidated subsidiaries.

WNRL provides us with various pipeline transportation, terminal distribution and storage services under long-term, fee-based commercial agreements expiring in 2023. These agreements contain minimum volume commitments. Each agreement has fees that are indexed for inflation and provides us with options to renew for two additional five-year terms.

In addition to commercial agreements, we are also party to an omnibus agreement with WNRL that among other things provides for reimbursement to us for various general and administrative services provided to WNRL. We are also party to an operational services agreement with WNRL, under which we are reimbursed for personnel services provided by Western in support of WNRL's operations of its pipelines, terminals and storage facilities.

WNRL has risk associated with its operations. If a major customer of WNRL were to terminate its contracts or fail to meet desired shipping or throughput levels for an extended period of time, revenue would be reduced and WNRL could suffer substantial losses to the extent that a new customer is not found. In the event that WNRL incurs a loss, our operating results will reflect WNRL’s loss, net of intercompany eliminations, to the extent of our ownership interest in WNRL at that point in time.

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

You should read the following discussion together with the financial statements and the notes thereto included elsewhere in this report. This discussion contains forward-looking statements that are based on current expectations, estimates and projections about our business and operations. The cautionary statements made in this report should be read as applying to all related forward-looking statements wherever they appear in this report. Our actual results may differ materially from those currently anticipated and expressed in such forward-looking statements as a result of a number of factors, including those we discuss under Part I, Item 1A. "Risk Factors" included in our Annual Report on Form 10-K for the year ended December 31, 2015 ("2015 Form 10-K") and elsewhere in this report. You should read "Risk Factors" and "Forward-Looking Statements" in this report. In this Item 2, all references to "Western Refining," "the Company," "Western," "we," "us," and "our" refer to Western Refining, Inc. and its consolidated subsidiaries including Northern Tier Energy LP ("NTI") and Western Refining Logistics, LP ("WNRL"), unless the context otherwise requires or where otherwise indicated.

Company Overview

We are an independent crude oil refiner and marketer of refined products incorporated in September 2005 under Delaware law with principal offices located in El Paso, Texas. Our common stock trades on the New York Stock Exchange ("NYSE") under the symbol “WNR.” We own certain operating assets directly; the controlling general partner interest and a 38.3% limited partner interest in NTI and the controlling general partner interest, incentive distribution rights and a 66.4% limited partner interest in Western Refining Logistics, LP ("WNRL"). NTI and WNRL common partnership units trade on the NYSE under the symbols "NTI" and "WNRL," respectively.

We produce refined products at our refineries in El Paso, Texas (131,000 barrels per day, or bpd), near Gallup, New Mexico (25,000 bpd) and NTI's refinery in St. Paul Park, Minnesota (98,000 bpd). We sell refined products primarily in Arizona, Colorado, Minnesota, New Mexico, Wisconsin, West Texas, the Mid-Atlantic region and Mexico through bulk distribution terminals and wholesale marketing networks. We also sell refined products through two retail networks with a total of 541 company-operated and franchised retail sites in the United States.

Our 100% ownership of the general partners of both NTI and WNRL gives us effective control of both entities. NTI operates a refinery in St. Paul Park, Minnesota and a retail-marketing network of 283 convenience stores, of which 114 are franchisees. NTI's primary area of operations includes Minnesota and Wisconsin. WNRL provides logistical services to our refineries in the Southwest and operates several lubricant and bulk petroleum distribution plants and a fleet of crude oil and refined product delivery trucks. WNRL distributes wholesale petroleum products primarily in Arizona, California, Colorado, Nevada, New Mexico and Texas.

We entered into an Agreement and Plan of Merger dated as of December 21, 2015 (the “Merger Agreement”) with Western Acquisition Co, LLC, a wholly-owned subsidiary of Western (“MergerCo”), NTI and Northern Tier Energy GP LLC, to acquire all of NTI’s outstanding common units not already held by us (the “Merger”). Each of the outstanding NTI common units held by unitholders other than us (the “NTI Public Unitholders”) will be converted under the terms of the Merger Agreement, into the right to receive, subject to election by the NTI Public Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western's common stock, par value $0.01 per share ("Western Common Stock"), (ii) $26.06 in cash without interest or (iii) 0.7036 of a share of Western Common Stock. Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo will merge with and into NTI and the separate limited liability company existence of MergerCo will cease and NTI will continue to exist, as a limited partnership under Delaware law and as our indirect wholly-owned subsidiary, as the surviving entity in the Merger. The Merger is expected to close in the second quarter of 2016, pending the satisfaction of certain customary conditions and the approval of the Merger and other matters at a special meeting of NTI unitholders by the affirmative vote of holders of a majority of the outstanding NTI common units (including the NTI common units held by us). The transaction is expected to result in 17.2 million additional shares of Western Common Stock outstanding.

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consideration to be received by the NTI’s unitholders. See Note 21, NTI, in the Notes to Condensed Consolidated Financial Statements for further discussion.

Our operations are reported under four business segments based on manufacturing and marketing criteria and the nature of our products and services, our production processes and our types of customers. These four segments are: refining, NTI, WNRL and retail. See Note 3, Segment Information, in the Notes to Condensed Consolidated Financial Statements for further discussion of our business segments.


•	Refining. Our refining segment owns and operates two refineries in the Southwest that process crude oil and other feedstocks primarily into gasoline, diesel fuel, jet fuel and asphalt. We market refined products to a diverse customer base including wholesale distributors and retail chains. The refining segment also sells refined products in the Mid-Atlantic region and Mexico.


•	NTI. NTI owns and operates refining and transportation assets and operates and supports retail convenience stores primarily in the Upper Great Plains region of the United States.


•	WNRL. WNRL owns and operates terminal, storage, transportation and wholesale assets consisting of a fleet of crude oil and refined product truck transports and wholesale petroleum product operations in the Southwest region. WNRL's primary customer is our refineries in the Southwest. WNRL purchases its wholesale product supply from the refining segment and third-party suppliers.


•	Retail. Our retail segment operates retail convenience stores and unmanned commercial fleet fueling ("cardlock") locations located in the Southwest. The retail convenience stores sell gasoline, diesel fuel and convenience store merchandise.

Major Influences on Results of Operations

Summary of First Quarter 2016 Operating and Financial Results


•	We averaged total throughput of 143,056 bpd at the El Paso refinery for the three months ended March 31, 2016, a 2.7% increase from the three months ended March 31, 2015.


•	We averaged throughput of 22,312 bpd at the Gallup refinery for the three months ended March 31, 2016, a 20.3% decrease from the three months ended March 31, 2015, primarily due to maintenance activity during the quarter.


•	NTI averaged throughput of 100,609 bpd at the St. Paul Park refinery for the three months ended March 31, 2016, a 6.9% increase from the three months ended March 31, 2015.


•	We purchased 2,462,350 shares under our share repurchase program at an average price of $30.46 per share.


•	NTI borrowed and repaid $70.0 million and $47.5 million, respectively, under the NTI Revolving Credit Facility.


•	WNRL repaid $15.0 million of its outstanding direct borrowings under the WNRL Revolving Credit Facility.


•	Dividends and distributions declared and paid:


◦	$0.38 per Western common share;


◦	$0.38 per NTI common unit; and


◦	$0.3925 per WNRL common unit.

Net income attributable to Western was $30.5 million, or $0.33 per diluted share for the three months ended March 31, 2016, compared to $106.0 million, or $1.11 per diluted share for the three months ended March 31, 2015.

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Our operating income decreased $177.4 million from March 31, 2015, to March 31, 2016, as shown by segment in the following table:



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Refining	$	62,138		$	148,612		$	(86,474	)
NTI	8,115			107,987			(99,872		)
WNRL	21,438			17,561			3,877
Retail	2,432			(441		)	2,873
Other	(15,496		)	(17,726		)	2,230
Total operating income	$	78,627		$	255,993		$	(177,366	)

The WNRL financial and operational data presented includes the historical results of all assets acquired from Western in the TexNew Mex Pipeline Transaction. This transaction was a transfer of assets between entities under common control. The financial information for the affected reporting segments has been retrospectively adjusted to include or exclude the historical results of the transferred assets for periods prior to the effective date of the transaction. See Note 3, Segment Information, in the Notes to Condensed Consolidated Financial Statements for further discussion of these retrospective adjustments.

Overview of Segments

Refining. The following items have a significant impact on our overall refinery gross margin, results of operations and cash flows:


•	fluctuations in petroleum based commodity values such as refined product prices and the cost of crude oil and other feedstocks;


•	product yield volumes that are less than total refinery throughput volume, resulting in yield loss and lower refinery gross margin;


•	the impact of our economic hedging activity;


•	fluctuations in our direct operating expenses, especially the cost of natural gas and electricity;


•	planned maintenance turnarounds, generally significant in both downtime and cost, are expensed as incurred;


•	seasonal fluctuations in demand for refined products; and


•	unplanned downtime of our refineries generally leads to increased maintenance costs and a temporary increase in working capital investment.

The following key factors affect petroleum based commodity values:


•	supply and demand for crude oil, gasoline and other refined products;


•	changes in domestic and foreign economies;


•	weather conditions;


•	domestic and foreign political affairs;


•	crude oil and refined petroleum product production levels;


•	logistics constraints;


•	availability of imports;


•	marketing of competitive fuels;


•	price differentials between heavy and sour crude oils and light sweet crude oils; and


•	government regulation.

We engage in hedging activity primarily to fix the margin on a portion of our future gasoline and distillate production and to protect the value of certain crude oil, refined product and blendstock inventories. We record the results of our hedging activity within cost of products sold which directly impacts our results of operations.

Excise and other taxes collected from customers and remitted to governmental authorities are not included in revenues or cost of products sold. In addition to the crude oil that we purchase to process at our refineries, we also purchase crude oil

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quantities that are transported to different locations and sold to third parties. We record these sales on a gross basis with the sales price recorded as revenues and the related costs within cost of products sold. Consolidated cost of products sold for the three months ended March 31, 2016, includes $5.3 million of realized and unrealized net gains from our economic hedging activities, including refining segment gains of $6.0 million and NTI losses of $0.7 million. The non-cash unrealized net losses included in the consolidated total were $12.5 million, including unrealized losses of $16.3 million related to Western's refining segment and unrealized gains of $3.8 million related to NTI for the three months ended March 31, 2016.

Demand for gasoline is generally higher during the summer months than during the winter months. As a result, our operating results for the first and fourth calendar quarters are generally lower than those for the second and third calendar quarters of each year. During 2015 and 2016, the volatility in crude oil prices and refining margins contributed to the variability of our results of operations.

Safety, reliability and the environmental performance of our refineries’ operations are critical components of our financial performance. Unplanned downtime of our refineries generally results in lost refinery gross margin, increased maintenance costs and a temporary increase in our working capital investment. We attempt to mitigate the financial impact of planned downtime, such as a turnaround or a major maintenance project, through our planning process that considers product availability, the margin environment and the availability of resources to perform the required maintenance. We occasionally experience unplanned downtime due to circumstances outside of our control. Certain of these outages may lead to losses that qualify for reimbursement under our business interruption insurance and we record such reimbursements as revenues when received.

Under an exclusive supply agreement with a third party, we receive monthly distribution amounts from the supplier equal to one-half of the amount by which our refined product sales in the Mid-Atlantic exceeds the supplier's costs of acquiring, transporting and hedging the refined product related to such sales. To the extent our refined product sales do not exceed the refined product costs during any month, we pay one-half of that amount to the supplier. Our payments to the supplier are limited to an aggregate annual amount of $2.0 million. This supply agreement is due to expire at the end of 2016.

NTI. NTI's gross margins, results of operations and cash flows are primarily affected by the following:


•	fluctuations in petroleum based commodity values such as refined product prices and the cost of crude oil and other feedstocks resulting from changes in supply and demand;


•	product yield volumes that are less than total refinery throughput volume, resulting in yield loss and lower refinery gross margin;


•	adjustments to reflect the lower of cost or market value of crude oil, finished product and retail LIFO inventory values;


•	fluctuations in its direct operating expenses, especially related to the cost of natural gas and the cost of electricity;


•	planned maintenance turnarounds, generally significant in both downtime and cost, are expensed as incurred;


•	seasonal fluctuations in demand for refined products; and


•	unplanned downtime of its refineries generally leads to increased maintenance costs and a temporary increase in working capital investment.

Demand for gasoline in summer is generally higher than demand in winter. These seasonal trends can impact gasoline prices and margins, causing a general trend in NTI's operating results toward lower first and fourth calendar quarters compared to the second and third calendar quarters of each year.

WNRL. WNRL's terminal throughput volumes depend primarily on the volume of refined and other products produced at Western’s southwestern refineries that, in turn, is ultimately dependent on supply and demand for refined product, crude oil and other feedstocks and Western’s response to changes in demand and supply.

Earnings and cash flows from WNRL's wholesale business are primarily affected by the sales volumes and margins of gasoline, diesel fuel and lubricants sold and transportation revenues from crude oil trucking and delivery. These margins are equal to the sales price, net of discounts, less total cost of sales and are measured on a cents per gallon ("cpg") basis. Factors that influence margins include local supply, demand and competition.

Retail. Earnings and cash flows from our retail business are primarily affected by the sales volumes and margins of gasoline and diesel fuel and by the sales and margins of merchandise sold at our retail stores. Margins for gasoline and diesel fuel sales are equal to the sales price less the delivered cost of the fuel and motor fuel taxes and are measured on a cpg basis. Fuel margins are impacted by competition and local and regional supply and demand. Margins for retail merchandise sold are equal to retail merchandise sales less the delivered cost of the merchandise, net of supplier discounts and inventory shrinkage and are measured as a percentage of merchandise sales. Merchandise sales are impacted by convenience or location, branding and competition. Our retail sales reflect seasonal trends such that operating results for the first and fourth calendar quarters are

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generally lower than those for the second and third calendar quarters of each year primarily due to lower demand for retail fuel. Earnings and cash flows from our cardlock business are primarily affected by the sales volumes and margins of gasoline and diesel fuel sold. These margins are equal to the sales price, net of discounts less the delivered cost of the fuel and motor fuel taxes and are measured on a cpg basis. Factors that influence margins include local supply, demand and competition.

Critical Accounting Policies and Estimates

We prepare our financial statements in conformity with U.S. generally accepted accounting principles ("GAAP"). In order to apply these principles, we must make judgments, assumptions and estimates based on the best available information at the time. Actual results may differ based on the continuing development of the information utilized and subsequent events, some of which we may have little or no control over. Our critical accounting policies could materially affect the amounts recorded in our financial statements. Our critical accounting policies, estimates and recent accounting pronouncements that potentially impact us are discussed in detail under Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations in our 2015 Form 10-K.

Recent Accounting Pronouncements. From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board or other standard setting bodies that may have an impact on our accounting and reporting. We are currently evaluating the effect that certain of these new accounting requirements may have on our accounting and related reporting and disclosures in our consolidated financial statements. For further discussion of the impact of recent accounting pronouncements, see Note 2, Basis of Presentation and Significant Accounting Policies, in the Notes to Condensed Consolidated Financial Statements.

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Results of Operations

The following tables summarize our consolidated and operating segment financial data and key operating statistics for the three months ended March 31, 2016 and 2015. The following data should be read in conjunction with our Condensed Consolidated Financial Statements and the notes thereto included elsewhere in this quarterly report.

Consolidated

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands, except per share data)
Statements of Operations Data
Net sales (1)	$	1,455,504		$	2,318,730		$	(863,226	)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization) (1)	1,047,361			1,741,310			(693,949		)
Direct operating expenses (exclusive of depreciation and amortization)	223,585			215,311			8,274
Selling, general and administrative expenses	53,285			55,803			(2,518		)
Loss (gain) on disposal of assets, net	(130		)	282			(412		)
Maintenance turnaround expense	125			105			20
Depreciation and amortization	52,651			49,926			2,725
Total operating costs and expenses	1,376,877			2,062,737			(685,860		)
Operating income	78,627			255,993			(177,366		)
Other income (expense):
Interest income	164			163			1
Interest and debt expense	(26,681		)	(24,957		)	(1,724		)
Other, net	6,104			3,206			2,898
Income before income taxes	58,214			234,405			(176,191		)
Provision for income taxes	(18,629		)	(59,437		)	40,808
Net income	39,585			174,968			(135,383		)
Less net income attributable to non-controlling interests (2)	9,047			68,979			(59,932		)
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989		$	(75,451	)

Basic earnings per share	$	0.34		$	1.11		$	(0.77	)
Diluted earnings per share	$	0.33		$	1.11		$	(0.78	)
Dividends declared per common share	$	0.38		$	0.30		$	0.08
Weighted average basic shares outstanding	92,078			95,567			(3,489		)
Weighted average dilutive shares outstanding	92,144			95,682			(3,538		)


(1)	Excludes $627.5 million and $736.5 million of intercompany sales and $627.5 million and $736.5 million of intercompany cost of products sold for the three months ended March 31, 2016 and March 31, 2015, respectively.


(2)	Net income attributable to non-controlling interests for the three months ended March 31, 2016, consisted of income from NTI and WNRL in the amount of $4.3 million and $4.7 million, respectively. Net income attributable to non-controlling interests for the three months ended March 31, 2015, consisted of income from NTI and WNRL in the amount of $63.8 million and $5.2 million, respectively.

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	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Economic Hedging Activities Recognized within Cost of Products Sold
Realized hedging gain, net	$	17,803		$	17,553		$	250
Unrealized hedging loss, net	(12,483		)	(20,057		)	7,574
Total hedging gain (loss), net	$	5,320		$	(2,504	)	$	7,824

Cash Flow Data
Net cash provided by (used in):
Operating activities	$	1,104		$	104,978		$	(103,874	)
Investing activities	(46,487		)	(9,171		)	(37,316		)
Financing activities	(134,018		)	(63,892		)	(70,126		)
Capital expenditures	$	79,029		$	53,195		$	25,834

Gross Margin. Gross margin is calculated as net sales less cost of products sold (exclusive of depreciation and amortization). Compared to the three months ended March 31, 2015, our consolidated gross margin decreased by 29.3% for the current period. This decrease was primarily due to lower refining margins offset in part by net economic hedging gains. We discuss refining margins and economic hedging activities under our refining and NTI segments.

Direct Operating Expenses (exclusive of depreciation and amortization). The increase in direct operating expenses was primarily due to increases of $8.4 million, $2.5 million, $0.7 million in our NTI, WNRL and retail segments, respectively, partially offset by a decrease of $3.3 million in our refining segment.

Selling, General and Administrative Expenses. The decrease in selling, general and administrative expenses resulted from decreases of $2.2 million, $2.3 million, $0.9 million and $0.4 million in corporate overhead and in our refining, WNRL and retail segments, respectively, partially offset by an increase of $3.2 million in our NTI segment. The decrease in corporate overhead was due to lower employee expenses based primarily on lower incentive compensation expenses in the current period.

Depreciation and Amortization. The increase between periods was primarily due to additional depreciation associated with our logistics assets related to the TexNew Mex Pipeline System and the ongoing expansion of our Delaware Basin logistics system.

Interest and Debt Expense. The increase in interest expense from prior periods was attributable to interest incurred through WNRL's issuance of $300.0 million of the WNRL 2023 Senior Notes during the first quarter of 2015, borrowings under the WNRL Revolving Credit Facility of $130.0 million and borrowings under the NTI Revolving Credit Facility.

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Results by Segment

The following tables set forth our historical financial data by segment for the periods presented. Our operations are organized into four operating segments based on manufacturing and marketing criteria and the nature of our products and services, our production processes and our types of customers. These segments are refining, NTI, WNRL and retail. See Note 3, Segment Information, in the Notes to Condensed Consolidated Financial Statements for more information.



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands)
Gross Margin by Segment
Refining	$	164,306	$	255,985	$	(91,679	)
NTI	129,702		217,313		(87,611		)
WNRL	72,449		65,695		6,754
Retail	41,686		38,427		3,259
Consolidated gross margin	$	408,143	$	577,420	$	(169,277	)
Direct Operating Expenses by Segment
Refining	$	73,488	$	76,798	$	(3,310	)
NTI	78,144		69,705		8,439
WNRL	38,901		36,371		2,530
Retail	33,052		32,354		698
Other	—		83		(83		)
Consolidated direct operating expenses	$	223,585	$	215,311	$	8,274
Depreciation and Amortization by Segment
Refining	$	21,285	$	20,484	$	801
NTI	19,969		19,365		604
WNRL	7,144		5,892		1,252
Retail	3,330		3,286		44
Other	923		899		24
Consolidated depreciation and amortization	$	52,651	$	49,926	$	2,725

See additional analysis under discussions of our refining, NTI, WNRL and retail segments.

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Adjusted EBITDA

Adjusted EBITDA represents earnings before interest and debt expense, provision for income taxes, depreciation, amortization, maintenance turnaround expense and certain other non-cash income and expense items. However, Adjusted EBITDA is not a recognized measurement under U.S. generally accepted accounting principles ("GAAP"). Our management believes that the presentation of Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors and other interested parties in the evaluation of companies in our industry. In addition, our management believes that Adjusted EBITDA is useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of Adjusted EBITDA generally eliminates the effects of financings, income taxes, the accounting effects of significant turnaround activities (that many of our competitors capitalize and thereby exclude from their measures of EBITDA) and certain non-cash charges that are items that may vary for different companies for reasons unrelated to overall operating performance.

Adjusted EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations are:


•	Adjusted EBITDA does not reflect our cash expenditures or future requirements for significant turnaround activities, capital expenditures or contractual commitments;


•	Adjusted EBITDA does not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt;


•	Adjusted EBITDA does not reflect changes in, or cash requirements for, our working capital needs; and


•	Adjusted EBITDA, as we calculate it, may differ from the Adjusted EBITDA calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure.

Because of these limitations, Adjusted EBITDA should not be considered a measure of discretionary cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and using Adjusted EBITDA only supplementally.

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989		$	(75,451	)
Net income attributable to non-controlling interests	9,047			68,979			(59,932		)
Interest and debt expense	26,681			24,957			1,724
Provision for income taxes	18,629			59,437			(40,808		)
Loss (gain) on disposal of assets, net	(130		)	282			(412		)
Depreciation and amortization	52,651			49,926			2,725
Maintenance turnaround expense	125			105			20
Net change in lower of cost or market inventory reserve	(51,734		)	(15,722		)	(36,012		)
Unrealized loss on commodity hedging transactions	12,483			20,057			(7,574		)
Adjusted EBITDA	$	98,290		$	314,010		$	(215,720	)

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Refining Segment

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands, except bpd and per barrel data)
Statement of Operations Data:
Net sales (including intersegment sales) (1)	$	886,320	$	1,491,441	$	(605,121	)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization) (2)	722,014		1,235,456		(513,442		)
Direct operating expenses (exclusive of depreciation and amortization)	73,488		76,798		(3,310		)
Selling, general and administrative expenses	7,270		9,569		(2,299		)
Loss on disposal of assets, net	—		417		(417		)
Maintenance turnaround expense	125		105		20
Depreciation and amortization	21,285		20,484		801
Total operating costs and expenses	824,182		1,342,829		(518,647		)
Operating income	$	62,138	$	148,612	$	(86,474	)
Key Operating Statistics
Total sales volume (bpd) (1) (3)	190,941		233,474		(42,533		)
Total refinery production (bpd)	163,167		164,837		(1,670		)
Total refinery throughput (bpd) (4)	165,368		167,299		(1,931		)
Per barrel of refinery throughput:
Refinery gross margin (2) (5) (6)	$	10.79	$	16.83	$	(6.04	)
Direct operating expenses (7)	4.88		5.10		(0.22		)
Mid-Atlantic sales volume (bbls)	1,731		1,940		(209		)
Mid-Atlantic margin per barrel	$	1.14	$	1.32	$	(0.18	)

The following tables set forth our summary refining throughput and production data for the periods and refineries presented:

El Paso and Gallup Refineries



	Three Months Ended
	March 31,
	2016	2015	Change
Key Operating Statistics
Refinery product yields (bpd):
Gasoline	90,011	89,197	814
Diesel and jet fuel	64,140	65,109	(969	)
Residuum	3,218	4,938	(1,720	)
Other	5,798	5,593	205
Total refinery production (bpd)	163,167	164,837	(1,670	)
Refinery throughput (bpd):
Sweet crude oil	123,953	131,182	(7,229	)
Sour crude oil	28,499	23,237	5,262
Other feedstocks and blendstocks	12,916	12,880	36
Total refinery throughput (bpd) (4)	165,368	167,299	(1,931	)

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El Paso Refinery



	Three Months Ended
	March 31,
	2016		2015		Change
Key Operating Statistics
Refinery product yields (bpd):
Gasoline	75,239		71,692		3,547
Diesel and jet fuel	58,284		56,726		1,558
Residuum	3,218		4,938		(1,720		)
Other	4,619		3,980		639
Total refinery production (bpd)	141,360		137,336		4,024
Refinery throughput (bpd):
Sweet crude oil	104,887		106,359		(1,472		)
Sour crude oil	28,499		23,237		5,262
Other feedstocks and blendstocks	9,670		9,706		(36		)
Total refinery throughput (bpd) (4)	143,056		139,302		3,754
Total sales volume (bpd) (3)	141,762		151,812		(10,050		)
Per barrel of refinery throughput:
Refinery gross margin (2) (5)	$	7.42	$	17.47	$	(10.05	)
Direct operating expenses (7)	3.49		4.08		(0.59		)

Gallup Refinery



	Three Months Ended
	March 31,
	2016		2015		Change
Key Operating Statistics
Refinery product yields (bpd):
Gasoline	14,772		17,505		(2,733		)
Diesel and jet fuel	5,856		8,383		(2,527		)
Other	1,179		1,613		(434		)
Total refinery production (bpd)	21,807		27,501		(5,694		)
Refinery throughput (bpd):
Sweet crude oil	19,066		24,823		(5,757		)
Other feedstocks and blendstocks	3,246		3,174		72
Total refinery throughput (bpd) (4)	22,312		27,997		(5,685		)
Total sales volume (bpd) (3)	30,614		32,884		(2,270		)
Per barrel of refinery throughput:
Refinery gross margin (2) (5)	$	9.30	$	14.04	$	(4.74	)
Direct operating expenses (7)	10.06		8.06		2.00


(1)	Refining net sales for the three months ended March 31, 2016 and 2015, includes $56.2 million and $215.5 million, respectively, representing a period average of 18,565 bpd and 48,778 bpd, respectively, in crude oil sales to third parties.

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(2)	Cost of products sold for the combined refining segment includes the net realized and net non-cash unrealized hedging activity shown in the table below. The hedging gains and losses are also included in the combined gross profit and refinery gross margin but are not included in those measures for our individual refineries.



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Realized hedging gain, net	$	22,269		$	17,455		$	4,814
Unrealized hedging loss, net	(16,271		)	(21,182		)	4,911
Total hedging gain (loss), net	$	5,998		$	(3,727	)	$	9,725

(3)

Sales volume includes sales of refined products sourced primarily from our refinery production as well as refined products purchased from third parties. We purchase additional refined products from third parties to supplement supply to our customers. These products are similar to the products that we currently manufacture and represented 8.4% and 9.1% of our total consolidated sales volumes for the three months ended March 31, 2016 and 2015, respectively. The majority of the purchased refined products are distributed through our refined product sales activities in the Mid-Atlantic region where we satisfy our refined product customer sales requirements through a third-party supply agreement.


(4)	Total refinery throughput includes crude oil, other feedstocks and blendstocks.

(5)

Refinery gross margin is a per barrel measurement calculated by dividing the difference between net sales and cost of products sold by our refineries’ total throughput volumes for the respective periods presented. Net realized and net non-cash unrealized economic hedging gains and losses included in the combined refining segment gross margin are not allocated to the individual refineries. Cost of products sold does not include any depreciation or amortization. Refinery gross margin is a non-GAAP performance measure that we believe is important to investors in evaluating our refinery performance as a general indication of the amount above our cost of products that we are able to sell refined products. Each of the components used in this calculation (net sales and cost of products sold) can be reconciled directly to our statement of operations. Our calculation of refinery gross margin may differ from similar calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure.

Our calculation of refinery gross margin excludes the sales and costs related to our Mid-Atlantic business that we report within the refining segment. The following table reconciles the sales and cost of sales used to calculate refinery gross margin with the total sales and cost of sales reported in the refining statement of operations data above:



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands)
Refinery net sales (including intersegment sales)	$	800,918	$	1,355,519	$	(554,601	)
Mid-Atlantic sales	85,402		135,922		(50,520		)
Net sales (including intersegment sales)	$	886,320	$	1,491,441	$	(605,121	)

Refinery cost of products sold (exclusive of depreciation and amortization)	$	638,588	$	1,102,094	$	(463,506	)
Mid-Atlantic cost of products sold	83,426		133,362		(49,936		)
Cost of products sold (exclusive of depreciation and amortization)	$	722,014	$	1,235,456	$	(513,442	)

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The following table reconciles combined gross profit for our refineries to combined gross margin for our refineries for the periods presented:



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands, except per barrel data)
Net sales (including intersegment sales)	$	800,918	$	1,355,519	$	(554,601	)
Cost of products sold (exclusive of depreciation and amortization)	638,588		1,102,094		(463,506		)
Depreciation and amortization	21,285		20,484		801
Gross profit	141,045		232,941		(91,896		)
Plus depreciation and amortization	21,285		20,484		801
Refinery gross margin	$	162,330	$	253,425	$	(91,095	)
Refinery gross margin per throughput barrel	$	10.79	$	16.83	$	(6.04	)
Gross profit per throughput barrel	$	9.37	$	15.47	$	(6.10	)

(6)

Cost of products sold for the combined refining segment includes changes in the lower of cost or market inventory reserve shown in the table below. The changes in this reserve are included in the combined refinery gross margin but are not included in those measures for the individual refineries. The following table calculates the combined refinery gross margin per throughput barrel excluding changes in the lower of cost or market inventory reserve:



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands, except per barrel data)
Refinery gross margin	$	162,330		$	253,425		$	(91,095	)
Net change in lower of cost or market inventory reserve	(40,689		)	(4,883		)	(35,806		)
Refinery gross margin, excluding LCM adjustment	$	121,641		$	248,542		$	(126,901	)
Refinery gross margin, excluding LCM adjustment, per refinery throughput barrel	$	8.08		$	16.51		$	(8.43	)


(7)	Refinery direct operating expenses per throughput barrel is calculated by dividing direct operating expenses by total throughput volumes for the respective periods presented. Direct operating expenses do not include any depreciation or amortization.

Gross Margin. Refinery gross margin is calculated as net sales (including intersegment sales) less cost of products sold (exclusive of depreciation and amortization). Excluding the impact of hedging activities, refinery gross margin per throughput barrel decreased in a manner generally consistent with the decrease in industry benchmarks.

The Gulf Coast benchmark 3:2:1 crack spread declined to $10.84 in the first three months of 2016 from $17.84 in the first three months of 2015. Our crude oil purchases are based on pricing tied to WTI that, in recent quarters, has experienced price volatility relative to Brent crude oil reflective of the decline of global and domestic crude oil prices. During the first three months of 2016, this differential decreased to an average of $0.49 per barrel from an average of $5.44 per barrel for the first three months of 2015. Our El Paso refinery margins have historically benefited from the WTI Midland/Cushing crude oil differential. However, this differential has been volatile, has narrowed over the past several months, and at times has shifted to a premium rather than a discount. For the first three months of 2016, the WTI Midland/Cushing differential averaged a premium of $0.14 per barrel, compared to an average discount of $1.92 for the first three months of 2015. This differential continues to be volatile and fluctuates based on local crude oil production, crude oil outflows at Midland and Cushing and regional refining throughput volumes.

Refinery gross margin was also affected by net realized and unrealized economic hedging gains of $6.0 million for the first three months of 2016, compared to net realized and unrealized economic hedging losses of $3.7 million for the first three months of 2015. We enter into hedge contracts to manage our exposure to commodity price risks or to fix sales margins on future gasoline and distillate production. Unrealized mark-to-market gains and losses related to our economic hedging instruments are the result of differences between forward crack spreads and the fixed margins from our hedge contracts. We incur unrealized commodity hedging losses when forward spreads are in excess of our fixed contract margins. Hedging gains or losses are included within cost of product sold, directly impacting our refining gross margin.

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Other impacts to margin include the net cost of RINs, which was $13.6 million for the first three months of 2016, compared to $6.2 million for the first three months of 2015. This $7.4 million increase in RIN costs is primarily due to an increase in our 2016 required volume obligation and an increase in the cost of RINs. Our refined product sales volume decreased to 17.4 million barrels during the first three months of 2016 from 21.0 million barrels during the first three months of 2015. Offsetting these negative impacts on our overall refining margin was the impact to cost of products sold of non-cash lower of cost or market ("LCM") inventory recoveries of $40.7 million for the three months ended March 31, 2016 compared to a recovery of $4.9 million for the same period in 2015.

Direct Operating Expenses (exclusive of depreciation and amortization). Direct operating expenses decreased primarily as a result of a decrease in energy, chemical and catalyst expense of $4.3 million due to decreased natural gas prices and employee expenses of $1.4 million primarily generated by lower incentive compensation. A partial offset to these decreases was an increase in property tax expense of $0.9 million, an increase in railcar lease expense of $0.8 million due to new short term leases in 2016 and an increase in maintenance expense of $0.6 million due to maintenance projects at the Gallup refinery.

Selling, General and Administrative Expenses. The decrease in selling, general and administrative expenses was primarily due to decreases in information technology expenses ($0.6 million), expenses related to a 2015 contract payment without comparable 2016 activity ($0.6 million), employee expenses ($0.5 million), outside support services expenses ($0.3 million) and professional and legal expenses ($0.2 million).

Depreciation and Amortization. Depreciation and amortization increased due to additional depreciation associated with recently capitalized logistics assets.

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NTI

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands, except bpd, per gallon and outlet data)
Statement of Operations Data:
Net sales	$	497,473		$	697,776		$	(200,303	)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization) (1)	367,771			480,463			(112,692		)
Direct operating expenses (exclusive of depreciation and amortization)	78,144			69,705			8,439
Selling, general and administrative expenses	23,479			20,271			3,208
Gain on disposal of assets, net	(5		)	(15		)	10
Depreciation and amortization	19,969			19,365			604
Total operating costs and expenses	489,358			589,789			(100,431		)
Operating income	$	8,115		$	107,987		$	(99,872	)
Key Operating Statistics
Total sales volume (bpd)	99,094			98,481			613
Total refinery production (bpd)	100,793			94,312			6,481
Total refinery throughput (bpd) (2)	100,609			94,108			6,501
Per barrel of throughput:
Refinery gross margin (1) (3) (4)	$	9.28		$	20.77		$	(11.49	)
Direct operating expenses (5)	4.85			4.59			0.26

Retail fuel gallons sold (in thousands)	73,090			71,861			1,229
Retail fuel margin per gallon (6)	$	0.24		$	0.21		$	0.03
Merchandise sales	84,193			82,614			1,579
Merchandise margin (7)	26.1		%	25.9		%	0.2		%
Company-operated retail outlets at period end	169			165			4
Franchised retail outlets at period end	114			95			19


(1)	Cost of products sold for NTI includes the net realized and net non-cash unrealized hedging activity shown in the table below. Hedging gains and losses are also included in the combined gross profit and refinery gross margin.



	Three Months Ended
	March 31,
	2016			2015		Change
	(In thousands)
Realized hedging gain (loss), net	$	(4,465	)	$	98	$	(4,563	)
Unrealized hedging gain, net	3,788			1,125		2,663
Total hedging gain (loss), net	$	(677	)	$	1,223	$	(1,900	)


(2)	Total refinery throughput includes crude oil, other feedstocks and blendstocks.

(3)

Refinery gross margin is a per barrel measurement calculated by dividing the difference between net sales and cost of products sold by the refinery's total throughput volumes for the respective periods presented. Refinery net sales include $3.5 million and $21.8 million related to crude oil sales during the first three months of March 31, 2016 and 2015, respectively. Refinery gross margin is a non-GAAP performance measure that we believe is useful in evaluating refinery performance as a general indication of the excess of the refined product sales amount over the related cost of products sold. Each of the components used in this calculation (net sales and cost of products sold) can be reconciled to corresponding amounts included in the statement of operations. Our calculation of refinery gross margin may differ from similar calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure. Cost of products

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sold for the first three months of March 31, 2016 and 2015 includes non-cash recoveries of $11.0 million and $10.8 million, respectively, to state the inventory value at market prices that were lower than cost.

The following table reconciles gross profit to gross margin for the St. Paul Park refinery for the periods presented:



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands, except per barrel data)
Net refinery sales (including intersegment sales)	$	495,276	$	689,530	$	(194,254	)
Refinery cost of products sold (exclusive of depreciation and amortization)	410,294		513,746		(103,452		)
Refinery depreciation and amortization	17,409		17,113		296
Gross profit	67,573		158,671		(91,098		)
Plus depreciation and amortization	17,409		17,113		296
Refinery gross margin	$	84,982	$	175,784	$	(90,802	)
Refinery gross margin per refinery throughput barrel	$	9.28	$	20.77	$	(11.49	)
Gross profit per refinery throughput barrel	$	7.38	$	18.73	$	(11.35	)


(4)	Cost of products sold for NTI includes changes in the lower of cost or market inventory reserve shown in the table below. The following table calculates the refinery gross margin per refinery throughput barrel excluding changes in the lower of cost or market inventory reserve:



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands, except per barrel data)
Refinery gross margin	$	84,982		$	175,784		$	(90,802	)
Net change in lower of cost or market inventory reserve	(10,981		)	(10,525		)	(456		)
Refinery gross margin, excluding LCM adjustment	$	74,001		$	165,259		$	(91,258	)
Refinery gross margin, excluding LCM adjustment, per refinery throughput barrel	$	8.08		$	19.53		$	(11.45	)


(5)	NTI's direct operating expenses per throughput barrel are calculated by dividing refining direct operating expenses by total throughput volumes for the respective periods presented. Direct operating expenses do not include any depreciation or amortization.


(6)	Retail fuel margin per gallon is a measurement calculated by dividing the difference between retail fuel sales and retail fuel cost of products sold by the number of gallons sold. Retail fuel margin per gallon is a measure frequently used in the retail industry to measure operating results related to fuel sales.


(7)	Merchandise margin is a measurement calculated by dividing the difference between merchandise sales and merchandise cost of products sold by merchandise sales. Merchandise margin is a measure frequently used in the retail industry to measure operating results related to merchandise sales.

Gross Margin. Gross margin is calculated as net sales (including intersegment sales) less cost of products sold (exclusive of depreciation and amortization). NTI gross margin decreased primarily due to lower crack spreads on barrels sold in the three months ended March 31, 2016, partially offset by increased sales volumes of 0.6%. The decrease in sales and cost of sales was primarily due to lower selling prices of refined products and lower crude cost, respectively, in the three months ended March 31, 2016. Cost of products sold also includes the impact of non-cash LCM inventory recoveries of $11.0 million and $10.8 million, respectively, for the three months ended March 31, 2016 and 2015 to state NTI's LIFO inventory at market prices that were lower than LIFO cost.

Direct Operating Expenses (exclusive of depreciation and amortization). Direct operating expenses increased compared to the first quarter of 2015, primarily because favorable weather allowed NTI to accelerate routine refinery maintenance activities into the first quarter of 2016. The higher direct operating expenses were also driven by higher retail personnel costs in the current period. These increases in costs were partially offset by reduced third-party crude oil freight expenses.

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Selling, General and Administrative Expenses. The increase in selling, general and administrative expenses was primarily due to higher equity-based compensation expense resulting from new grants and performance award adjustments.

Depreciation and Amortization. Depreciation and amortization increased primarily due to refining assets placed in service since March 31, 2015, the most significant of which were improvements to NTI's refinery fire suppression systems, truck loading terminal and parking facilities along with retail stores acquired under capital leases.

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WNRL

WNRL's financial and operational data presented includes the historical results of all assets acquired from Western in the TexNew Mex Pipeline Transaction. This transaction was a transfer of assets between entities under common control. We have retrospectively adjusted historical financial and operational data of WNRL, for all periods presented, to reflect the purchase and consolidation of the TexNew Mex Pipeline System into WNRL.

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Statement of Operations Data:
Net sales	$	468,039		$	607,396		$	(139,357	)
Operating costs and expenses:
Cost of products sold	395,590			541,701			(146,111		)
Direct operating expenses	38,901			36,371			2,530
Selling, general and administrative expenses	5,065			5,955			(890		)
Gain on disposal of assets, net	(99		)	(84		)	(15		)
Depreciation and amortization	7,144			5,892			1,252
Total operating costs and expenses	446,601			589,835			(143,234		)
Operating income	$	21,438		$	17,561		$	3,877



	Three Months Ended
	March 31,
	2016		2015		Change
Key Operating Statistics
Pipeline and gathering (bpd):
Mainline movements:
Permian/Delaware Basin system	49,486		36,512		12,974
Four Corners system (1)	52,467		45,841		6,626
Tex New Mex system	12,544		—		12,544
Gathering (truck offloading):
Permian/Delaware Basin system	20,533		22,605		(2,072		)
Four Corners system	12,761		10,662		2,099
Terminalling, transportation and storage (bpd):
Shipments into and out of storage (includes asphalt)	388,258		391,318		(3,060		)
Wholesale:
Fuel gallons sold (in thousands)	314,943		303,431		11,512
Fuel gallons sold to retail (included in fuel gallons sold above) (in thousands)	79,841		75,263		4,578
Fuel margin per gallon (2)	$	0.028	$	0.027	$	0.001
Lubricant gallons sold (in thousands)	2,201		2,957		(756		)
Lubricant margin per gallon (3)	$	0.69	$	0.66	$	0.03
Crude oil trucking volume (bpd)	35,111		43,050		(7,939		)
Average crude oil revenue per barrel	$	2.24	$	2.76	$	(0.52	)


(1)	Some barrels of crude oil in route to Western's Gallup refinery and Permian/Delaware Basin are transported on more than one mainline. Mainline movements for the Four Corners and Delaware Basin systems include each barrel transported on each mainline.

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(2)	Fuel margin per gallon is a measurement calculated by dividing the difference between fuel sales, net of transportation charges, and cost of fuel sales for our wholesale business by the number of gallons sold. Fuel margin per gallon is a measure frequently used in the petroleum products wholesale industry to measure operating results related to fuel sales.


(3)	Lubricant margin per gallon is a measurement calculated by dividing the difference between lubricant sales, net of transportation charges, and lubricant cost of products sold by the number of gallons sold. Lubricant margin is a measure frequently used in the petroleum products wholesale industry to measure operating results related to lubricant sales.

Gross Margin. Gross margin is calculated as net sales (including intersegment sales) less cost of products sold (exclusive of depreciation and amortization). WNRL's gross margin increased by $6.8 million primarily due to increased fee based revenue of $6.2 million resulting from increasing certain pipeline, terminal and other service fee rates over 2015 rates. Also contributing to the increase were greater wholesale fuel margins of $0.6 million and increased revenue of $1.7 million period over period from new asphalt hauling activity by truck. These increases were partially offset by decreased revenue of $1.4 million crude oil gathering activity by truck and a $0.7 million decrease in margin from lubricant sales. Wholesale sales based revenues decreased due to a lower average price per gallon sold in the first three months of 2016 of $1.22 compared to $1.72 for the first three months of 2015.

Direct Operating Expenses (exclusive of depreciation and amortization). Direct operating expenses increased primarily due to higher outside support services ($1.7 million) due to in-line inspections for pipeline segments and various tank repairs, higher employee expenses ($1.1 million) resulting from an increase in the number of drivers in our truck fleet and environmental expense ($0.8 million), partially offset by decreased chemical expense ($0.3 million) specifically due to chemical additives used in the pipeline transportation process and by lower fuel expense for our transportation department ($0.5 million).

WNRL's logistics maintenance costs are generally cyclical in nature. WNRL's terminal facilities are subject to recurring maintenance for normal wear and related maintenance costs are generally consistent from period to period. Routine service cycle for tank inspections and maintenance at WNRL's storage facilities is generally every 10 years. Pipelines are also subject to routine periodic inspections. When WNRL changes the service use of a storage tank, maintenance costs will generally be higher due to increased costs of tank cleaning and hazardous material disposal. The cost of WNRL's maintenance is dependent upon the level of repairs deemed necessary as a result of the inspection of the specified asset.

Selling, General and Administrative Expenses. Selling, general and administrative expenses decreased primarily due to decreased professional and legal services ($0.3 million) related to business acquisitions and corresponding debt transactions and other taxes ($0.3 million).

Depreciation and Amortization. Depreciation and amortization increased due to additional TexNew Mex Pipeline System depreciation and the expansion of WNRL's Delaware Basin logistics system.

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Retail Segment

Three Months Ended March 31, 2016, Compared to the Three Months Ended March 31, 2015



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands, except per gallon data)
Statement of Operations Data
Net sales (including intersegment sales)	$	231,186		$	258,602		$	(27,416	)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	189,500			220,175			(30,675		)
Direct operating expenses (exclusive of depreciation and amortization)	33,052			32,354			698
Selling, general and administrative expenses	2,898			3,264			(366		)
Gain on disposal of assets, net	(26		)	(36		)	10
Depreciation and amortization	3,330			3,286			44
Total operating costs and expenses	228,754			259,043			(30,289		)
Operating income (loss)	$	2,432		$	(441	)	$	2,873
Key Operating Statistics
Retail fuel gallons sold	91,469			83,824			7,645
Average retail fuel sales price per gallon, net of excise taxes	$	1.43		$	1.82		$	(0.39	)
Average retail fuel cost per gallon, net of excise taxes)	1.28			1.68			(0.40		)
Retail fuel margin per gallon (1)	0.15			0.14			0.01
Merchandise sales	$	75,967		$	70,887		$	5,080
Merchandise margin (2)	29.5		%	29.4		%	0.1		%
Operating retail outlets at period end	258			261			(3		)
Cardlock fuel gallons sold	15,253			16,120			(867		)
Cardlock fuel margin per gallon	$	0.128		$	0.186		$	(0.058	)
Operating cardlocks at period end	52			50			2

The following table reconciles retail fuel sales and cost of retail fuel sales to net sales and cost of products sold:



	Three Months Ended
	March 31,
	2016		2015		Change
	(In thousands, except per gallon data)
Net Sales
Retail fuel sales, net of excise taxes	$	130,825	$	152,545	$	(21,720	)
Merchandise sales	75,967		70,887		5,080
Cardlock sales	20,733		31,994		(11,261		)
Other sales	3,661		3,176		485
Net sales	$	231,186	$	258,602	$	(27,416	)
Cost of Products Sold
Retail fuel cost of products sold, net of excise taxes	$	117,220	$	141,122	$	(23,902	)
Merchandise cost of products sold	53,519		50,065		3,454
Cardlock cost of products sold	18,701		28,932		(10,231		)
Other cost of products sold	60		56		4
Cost of products sold	$	189,500	$	220,175	$	(30,675	)
Retail fuel margin per gallon (1)	$	0.15	$	0.14	$	0.01

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(1)	Retail fuel margin per gallon is a measurement calculated by dividing the difference between retail fuel sales and cost of retail fuel sales for our retail segment by the number of gallons sold. Retail fuel margin per gallon is a measure frequently used in the convenience store industry to measure operating results related to retail fuel sales.


(2)	Merchandise margin is a measurement calculated by dividing the difference between merchandise sales and merchandise cost of products sold by merchandise sales. Merchandise margin is a measure frequently used in the convenience store industry to measure operating results related to merchandise sales.

Gross Margin. Retail gross margin is calculated as net sales (including intersegment sales) less cost of products sold (exclusive of depreciation and amortization). The net effect of 31 new retail outlets added during January of 2015, one retail outlet added in April of 2015 and four retail outlets closed in the third and fourth quarters of 2015 was an increase in retail gross margin of $1.4 million. The increase in retail gross margin was also the result of higher same store retail fuel gross margin of $1.7 million and increased same store merchandise gross margin of $0.8 million, partially offset by a decrease in cardlock gross margin due to lower sales volumes.

Direct Operating Expenses (exclusive of depreciation and amortization). Direct operating expenses for the three months ended March 31, 2016 increased from the three months ended March 31, 2015. The net effect of 31 retail outlets added during January of 2015, one added in April of 2015 and four outlets that closed in the third and fourth quarters of 2015 was an additional $0.2 million in expenses. Additionally, there was an increase in same store employee and maintenance expense of $0.4 million and $0.3 million, respectively, partially offset by a decrease in same store environmental expense of $0.2 million.

Selling, General and Administrative Expenses. The decrease in selling, general and administrative expenses was primarily due to decreased cardlock employee expenses ($0.3 million).

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Outlook

Our refining margins, excluding hedging activities, were weaker at the Gallup, El Paso and St. Paul Park refineries in the first quarter of 2016 compared to the first quarter of 2015. Both Western and NTI base our crude oil purchases on pricing tied to WTI. The discount of WTI crude oil to Brent crude oil (the "WTI/Brent discount") declined to an average of $0.49 per barrel during the first quarter of 2016, compared to an average of $5.44 per barrel for the first quarter of 2015.

The WTI Midland/Cushing differential can have a significant impact on our refining margin at El Paso. On a trade-month basis, the WTI Midland/Cushing differential averaged a premium of $0.14 per barrel for the first quarter of 2016, negatively impacting our El Paso refining margins for the quarter compared to the Midland/Cushing trade-month discount of $1.92 that we realized in El Paso during the first quarter of 2015. The WTI Midland/Cushing differential has averaged a trade-month discount of $0.03 thus far in the second quarter of 2016. The prices of crude oil and refined products have been volatile thus far in 2016. Continued volatility in these prices may impact the carrying value of our inventories and result in additional lower of cost or market inventory adjustments. A further increase in prices, such as we experienced in the first quarter of 2016, may positively impact the carrying value of our inventories. Conversely, a decrease in prices could negatively impact our inventory carrying values.

The Gulf Coast benchmark 3:2:1 crack spread decreased from an average of $17.84 for the three months ended March 31, 2015, to an average of $10.84 for the three months ended March 31, 2016. The Gulf Coast benchmark 3:2:1 crack spread and the WTI/Brent discount for April 2016 averaged $13.32 and $0.49 per barrel, respectively.

The growth of gathering activity on our Delaware Basin Logistics System continues to positively impact our refining margins through increased deliveries of advantaged crude oil to our El Paso refinery. Also, NTI’s location allows for direct pipeline access to advantaged crude oil from the Bakken Shale in North Dakota and other Canadian crude oils that may price at substantial discounts to WTI. We expect continued volatility in crude oil pricing differentials and crack spreads given the significant continuing decline in Brent and WTI crude oil prices.

Liquidity and Capital Resources

Our primary sources of liquidity are cash from operations, cash on hand and Western revolving credit facility availability. To a lesser extent, we also generate liquidity from the issuance of securities.

As of March 31, 2016, we had cash and cash equivalents of $593.1 million, including NTI cash of $35.0 million and WNRL cash of $28.7 million, restricted cash of $36.8 million and no direct borrowings under the Western revolving credit facility. Western had $767.2 million in total liquidity as of March 31, 2016, defined as Western’s cash and cash equivalents plus net availability under Western's revolving credit facility. Western, NTI and WNRL had net availability under their revolving credit facilities of $201.0 million, $134.7 million and $169.3 million, respectively.

WNRL borrowed $145.0 million under the WNRL Revolving Credit Facility on October 30, 2015, to partially fund the purchase of Western's TexNew Mex Pipeline System. On February 17, 2016, WNRL repaid $15.0 million of its outstanding direct borrowings under the WNRL Revolving Credit Facility. NTI had direct borrowings of $22.5 million under the NTI revolving credit facility as of March 31, 2016. See Note 9, Long-Term Debt, in the Notes to Condensed Consolidated Financial Statements for detailed information regarding our financing.

On December 21, 2015, we entered into the Merger Agreement to acquire all of NTI's remaining outstanding publicly held common units. At the effective time of the Merger, each of the outstanding NTI common units held by the NTI Public Unitholders will be converted into the right to receive, subject to election by the NTI Public Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western Common Stock, (ii) $26.06 in cash without interest or (iii) 0.7036 of a share of Western Common Stock. We expect to fund the cash portion of the Merger consideration, $862.3 million, with a combination of cash and through the incurrence of $500 million in new indebtedness. In 2016, debt financing for the energy industry has become increasingly difficult and more expensive. In light of this, the cost we may incur to finance a portion of the cash consideration in the Merger, as well as any increases to the cost of our existing indebtedness in connection with the Merger, could have a material adverse effect on our financial position, results of operations and cash flows.

Our board of directors has periodically approved various share repurchase programs authorizing us to repurchase up to $200 million of our outstanding common stock, per program. Our board of directors approved our current $200 million share repurchase program in September of 2015 (the "September 2015 Program") that is scheduled to expire on December 31, 2016. We have repurchased 2.5 million shares of our common stock at a cost of $75.0 million under the September 2015 Program. As of March 31, 2016, we had $125.0 million remaining in authorized expenditures under the September 2015 Program.

We will repurchase shares from time-to-time through open market transactions, block trades, privately negotiated transactions or otherwise and subject to market conditions, as well as corporate, regulatory and other considerations. The share repurchase program may be modified or discontinued at any time by our board of directors.

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Cash Flows

The following table sets forth our cash flows for the periods indicated:



	Three Months Ended
	March 31,
	2016			2015			Change
	(In thousands)
Net cash provided by operating activities	$	1,104		$	104,978		$	(103,874	)
Net cash used in investing activities	(46,487		)	(9,171		)	(37,316		)
Net cash used in financing activities	(134,018		)	(63,892		)	(70,126		)
Net increase (decrease) in cash and cash equivalents	$	(179,401	)	$	31,915		$	(211,316	)

The decrease in net cash from operating activities period over period was primarily the result of the increase in net income and the results of our commodity hedging activity, offset by changes in our working capital as disclosed in our Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2016 and 2015.

Cash flows from operating activities for the three months ended March 31, 2016, combined with borrowings on the NTI revolving credit facility of $70.0 million were primarily used for the following investing and financing activities:

•Fund capital expenditures ($79.0 million) including the use of $32.3 million of restricted cash;

•Purchase of treasury stock ($75.0 million);

•Repayment of NTI's revolving credit facility debt ($47.5 million);

•Payment of cash dividends ($35.6 million);

•Payment of distributions to non-controlling interest holders ($29.0 million); and

•Repayment of WNRL's revolving credit facility debt ($15.0 million).

Cash flows used in operating activities for the three months ended March 31, 2015, combined with $300.0 million in additions to WNRL long-term debt, were primarily used for the following investing and financing activities:

•Repayment of WNRL's revolving credit facility debt ($269.0 million);

•Fund capital expenditures ($53.2 million) including the use of $43.4 million of restricted cash;

•Payments of distributions to non-controlling interest holders ($33.7 million);

•Payment of cash dividends ($28.6 million);

•Purchase of treasury stock ($25.0 million); and

•Payment of deferred financing costs ($6.6 million).

Future Capital Expenditures

We expect to fund future capital expenditures primarily through cash from operations supplemented as needed by borrowings under our revolving credit facilities. The following table summarizes our 2016 forecasted spending allocation between sustaining, discretionary and regulatory projects for 2016:



	Western (1)		NTI		WNRL		Totals
	(In thousands)
Sustaining	$	54,959	$	40,000	$	13,886	$	108,845
Discretionary	51,726		62,000		34,678		148,404
Regulatory	33,716		8,000		3,630		45,346
Total	$	140,401	$	110,000	$	52,194	$	302,595


(1)	Western's capital expenditure forecast for the full year 2016 is $140.4 million, of which $121.1 million is for our refining segment, $15.4 million for our retail segment and $3.9 million for other general projects.

The majority of Western's planned discretionary capital expenditures relate to crude oil logistics projects in the Permian Basin. WNRL’s discretionary capital expenditures primarily relate to construction of a 10-inch pipeline connection from its

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pipeline system in the Four Corners region of Northern New Mexico to the TexNew Mex Pipeline System and continued expansion of its Permian Delaware Basin system.

Capital Structure

Our capital structure at March 31, 2016 and 2015 was as follows:



	March 31, 2016		March 31, 2015
	(In thousands)
Debt, including current maturities:
Western obligations:
Revolving Credit Facility due 2019	$	—	$	—
Term Loan Credit Facility due 2020	537,625		543,125
6.25% Senior Unsecured Notes due 2021	350,000		350,000
Total Western obligations	887,625		893,125
NTI obligations:
Revolving Credit Facility due 2019	22,500		—
7.125% Senior Secured Notes due 2020	350,000		350,000
Total NTI obligations	372,500		350,000
WNRL obligations:
Revolving Credit Facility due 2018	130,000		—
7.5% Senior Notes due 2023	300,000		300,000
Total WNRL obligations	430,000		300,000
Less unamortized premium and debt issuance costs	32,033		38,581
Long-term debt	1,658,092		1,504,544
Equity	2,850,800		2,879,158
Total capitalization	$	4,508,892	$	4,383,702

See Note 9, Long-Term Debt and Note 10, Equity, in the Notes to Condensed Consolidated Financial Statements for further information.

Contractual Obligations and Commercial Commitments

We include a complete summary of our future contractual obligations and commercial commitments as of December 31, 2015 in our 2015 Form 10-K under Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, Contractual Obligations and Commercial Commitments.

Dividends

We anticipate paying future quarterly dividends, subject to the board of directors' approval and compliance with the restrictions in our outstanding financing agreements. The table below summarizes our 2016 cash dividend declarations, payments and scheduled payments through April 29, 2016:

Declaration Date

Record Date

Payment Date

Dividend per Common Share

Total Payment

(In thousands)

First quarter

January 6

January 20

February 4

0.38

35,601

Second quarter (1)

April 8

April 18

May 2

0.38

—

Total

35,601


(1)	The second quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $34.7 million.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

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Item 3.	Quantitative and Qualitative Disclosure About Market Risk

Commodity price fluctuation is our primary source of market risk.

Commodity Price Risk

We are exposed to market risks related to the volatility of crude oil and refined product prices, as well as volatility in the price of natural gas used in our refinery operations. Our financial results can be affected significantly by fluctuations in these prices that depend on many factors, including demand for crude oil, gasoline and other refined products; changes in the economy; worldwide and domestic production levels; worldwide inventory levels; and governmental regulatory initiatives. Our risk management strategy identifies circumstances in which we may utilize the commodity futures market to manage risk associated with these price fluctuations or to fix sales margins on future gasoline and distillate production.

In order to manage the uncertainty relating to inventory price volatility, we have generally applied a policy of maintaining inventories at or below a targeted operating level. In the past, circumstances have occurred, such as turnaround schedules or shifts in market demand, that have resulted in variances between our actual inventory level and our desired target level. We may utilize the commodity futures market to manage these anticipated inventory variances.

We maintain inventories of crude oil, other feedstocks and blendstocks and refined products with values that are subject to wide fluctuations in market prices driven by worldwide economic conditions, regional and global inventory levels and seasonal conditions.

At March 31, 2016, we held 12.6 million barrels of crude oil, refined product and other inventories valued under the LIFO valuation method with an average cost of $58.66 per barrel. At March 31, 2016, the excess of the current cost of our crude oil, refined products and other feedstocks and blendstocks inventories over aggregated LIFO costs was $221.4 million.

All commodity futures contracts, price swaps and options are recorded at fair value and any changes in fair value between periods are recorded under cost of products sold in our Condensed Consolidated Statements of Operations.

We selectively utilize commodity hedging instruments to manage our price exposure to our LIFO inventory positions or to fix margins on certain future sales volumes. The commodity hedging instruments may take the form of futures contracts, price and crack spread swaps or options and are entered into with counterparties that we believe to be creditworthy. The financial instruments used to fix margins on future sales volumes do not qualify for hedge accounting. Therefore, changes in the fair value of these hedging instruments are included in income in the period of change. Net gains or losses associated with these transactions are reflected within cost of products sold at the end of each period.

The following tables summarize our economic hedging activity recognized within cost of products sold for the three months ended March 31, 2016 and 2015 and open commodity hedging positions as of March 31, 2016 and December 31, 2015:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Economic hedging results
Realized hedging gain, net	$	17,803		$	17,553
Unrealized hedging loss, net	(12,483		)	(20,057		)
Total hedging gain (loss), net	$	5,320		$	(2,504	)

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	March 31, 2016			December 31, 2015
	(In thousands)
Open commodity hedging instruments (barrels)
Crude oil differential swaps, net long positions	7,201			5,155
Crude oil futures, net short positions	(1,823		)	(562		)
Refined product price and crack spread swaps, net short positions	(2,900		)	(5,645		)
Total open commodity hedging instruments, net long (short) positions	2,478			(1,052		)

Fair value of outstanding contracts, net
Other current assets	$	67,064		$	78,125
Other assets	7,152			11,881
Accrued liabilities	(7,137		)	(10,273		)
Other long-term liabilities	—			—
Fair value of outstanding contracts - unrealized gain, net	$	67,079		$	79,733

During the three months ended March 31, 2016 and 2015, we did not have any commodity derivative instruments that were designated or accounted for as hedges.


Item 4.	Controls and Procedures

Under the supervision and with the participation of our management, including the Chief Executive Officer and Chief Financial Officer, we evaluated the effectiveness of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as of March 31, 2016. Based on that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of March 31, 2016.

There were no changes in our internal control over financial reporting during the quarter ended March 31, 2016, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Part II

Other Information

Item 1A. Risk Factors

The risk factor below amends and restates the corresponding risk factor previously disclosed in the section entitled "Risk Factors" in our 2015 Form 10-K under Part I, Item 1A: Risk Factors.

The debt that Western expects to incur in connection with the Merger could adversely affect its financial position and make it more vulnerable to adverse economic conditions.

Western expects the cash portion of the consideration to be paid by it in the Merger to be approximately $862.3 million, $500 million of which Western expects to finance through the incurrence of new indebtedness. In 2016, debt financing for the energy industry has become increasingly difficult and more expensive. However, it is not a condition to the obligations of Western to complete the Merger that it obtain this financing on terms that are acceptable to Western or at all. In light of this, the cost Western may incur to finance a portion of the cash consideration in the Merger, as well as any increases to the cost of its existing indebtedness as a result of amendments required in connection with the Merger or otherwise, could have a material adverse effect on its financial position, results of operations and cash flows.

As of March 31, 2016, Western had $887.6 million of indebtedness outstanding. Following the closing of the Merger, Western may determine to seek new financing to terminate NTI’s existing credit facility and/or consummate an exchange offer, tender offer, repurchase offer, consent solicitation, discharge, defeasance, redemption or similar transaction for all or any portion of NTI’s outstanding notes. Interest costs related to Western’s indebtedness may be substantial. This level of debt could have important consequences, such as:


•	limiting Western’s ability to obtain additional financing to fund its working capital, capital expenditures, debt service requirements or potential growth or for other purposes;


•	increasing the cost of future borrowings by Western;

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•	limiting Western’s ability to use operating cash flow in other areas of its business or to pay dividends because it must dedicate a substantial portion of these funds to make payments on its debt;


•	placing Western at a competitive disadvantage compared to competitors with less debt; and


•	increasing Western’s vulnerability to adverse economic and industry conditions.

Western’s ability to service its debt will depend upon, among other things, its future financial and operating performance and distributions from WNRL, which will be affected by prevailing economic conditions and financial, business, regulatory and other factors, many of which are beyond Western’s control. If Western’s operating results are not sufficient to service its indebtedness and any future indebtedness that it may incur, Western may be forced to take actions such as reducing dividends, reducing or delaying its business activities, acquisitions, investments or capital expenditures, selling assets or seeking additional equity capital. Western may not be able to effect any of these actions on satisfactory terms or at all.

There have been no other material changes from the risk factors during the three months ended March 31, 2016 from those previously disclosed in the section entitled "Risk Factors" in our 2015 Form 10-K under Part I, Item 1A. Risk Factors.

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

Since 2012, our board of directors has approved five separate share repurchase programs authorizing us to repurchase up to $200 million of our outstanding common stock, per program. On September 21, 2015, our board of directors authorized the September 2015 Program for up to $200 million for the repurchase of our outstanding common stock. The September 2015 Program is scheduled to expire on December 31, 2016 and is subject to discontinuance by our board of directors at any time.

The following table presents shares repurchased, by month, during the first quarter of 2016:



	Total number of shares purchased	Average price paid per share (1)		Total number of shares purchased as part of publicly announced plans or programs	Maximum dollar value that may yet be purchased under the program (In thousands)
January 1 - January 31	786,138	$	31.80	786,138	$	175,000
February 1 - February 29	1,676,212	29.83		1,676,212	125,000
March 1 - March 31	—	—		—	125,000
	2,462,350	30.46		2,462,350

(1) Average price per share excludes commissions.

We will repurchase shares from time-to-time through open market transactions, block trades, privately negotiated transactions or otherwise and subject to market conditions, as well as corporate, regulatory and other considerations. The share repurchase programs may be modified or discontinued at any time by our board of directors.

Our payment of dividends is limited under the terms of our Western 2019 Revolving Credit Agreement, our Western 2021 Senior Unsecured Notes and our Western 2020 Term Loan Credit Facility, and in part, depends on our ability to satisfy certain financial covenants. Also, as a holding company, we rely on dividends or advances from our subsidiaries to fund any dividends. The ability of our subsidiaries including NTI and WNRL to pay us dividends is restricted by covenants in their respective debt instruments and any future financing agreements.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

None.

Item 5. Other Information

None.

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Item 6. Exhibits

Exhibit Index***



Number		Exhibit Title

3.2		Amended and Restated Bylaws of the Company, effective as of March 24, 2016 (incorporated by reference to Exhibit 3.1 to the Company's Current Report on Form 8-K, filed with the SEC on March 30, 2016)

31.1*		Certification Statement of Chief Executive Officer of the Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.2*		Certification Statement of Chief Financial Officer of the Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1**		Certification Statement of Chief Executive Officer of the Company pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

32.2**		Certification Statement of Chief Financial Officer of the Company pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

101		Interactive Data Files



*		Filed herewith.

**		Furnished herewith.

***		Reports filed under the Securities Exchange Act of 1934, as amended, (Form 10-K, Form 10-Q and Form 8-K) are filed under File No. 001-32721.

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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 REFINING, INC.




Signature	Title	Date

/s/ Gary R. Dalke	Chief Financial Officer	May 4, 2016
Gary R. Dalke	(Principal Financial Officer and Duly Authorized Signatory)

Exhibit

Exhibit 31.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

Pursuant to Rule 13a-14(a) and 15d-14(a)

I, Jeff A. Stevens, certify that:


1.	I have reviewed this quarterly report on Form 10-Q of Western Refining, Inc.;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):


a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 4, 2016

/s/ Jeff A. Stevens

Jeff A. Stevens

Chief Executive Officer

Exhibit

Exhibit 31.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

Pursuant to Rule 13a-14(a) and 15d-14(a)

I, Gary R. Dalke, certify that:


1.	I have reviewed this quarterly report on Form 10-Q of Western Refining, Inc.;


2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;


3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;


4.	The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:


a.	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;


b.	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;


c.	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and


d.	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and


5.	The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):


a.	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b.	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: May 4, 2016

/s/ Gary R. Dalke

Gary R. Dalke

Chief Financial Officer

Exhibit

Exhibit 32.1

CERTIFICATION BY CHIEF EXECUTIVE OFFICER

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

I, Jeff A. Stevens, Chief Executive Officer, of Western Refining, Inc. (the “Company”), certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, that:


1.	The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2016 (the “Report”) fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934, as amended; and


2.	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 4, 2016

/s/ Jeff A. Stevens

Jeff A. Stevens

Chief Executive Officer

Exhibit

Exhibit 32.2

CERTIFICATION BY CHIEF FINANCIAL OFFICER

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

I, Gary R. Dalke, Chief Financial Officer, of Western Refining, Inc. (the “Company”), certify, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, that:


1.	The Quarterly Report on Form 10-Q of the Company for the quarter ended March 31, 2016 (the “Report”) fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934, as amended; and


2.	The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date: May 4, 2016

/s/ Gary R. Dalke

Gary R. Dalke

Chief Financial Officer

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Document and Entity Information - USD ($)	3 Months Ended
Document and Entity Information - USD ($)	Mar. 31, 2016	Apr. 29, 2016	Jun. 30, 2015
Document Information [Line Items]
Entity Registrant Name	Western Refining, Inc.
Entity Central Index Key	0001339048
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 3,118,296,397
Common Stock, Shares, Outstanding		91,276,677

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents (WNRL: $28,653 and $44,605, respectively)	$ 593,101	$ 772,502
Accounts receivable, trade, net of a reserve for doubtful accounts of $195 and $169, respectively (WNRL: $60,946 and $55,053, respectively)	337,077	359,237
Inventories (WNRL: $12,476 and $15,200, respectively)	683,593	547,538
Prepaid expenses (WNRL: $5,380 and $4,133, respectively)	79,971	73,213
Other current assets (WNRL: $5,510 and $5,562, respectively)	159,591	169,728
Total current assets	1,853,333	1,922,218
Restricted cash	36,783	69,106
Equity method investment	102,971	97,513
Property, plant and equipment, net (WNRL: $324,342 and $321,251, respectively)	2,324,591	2,305,171
Goodwill	1,289,443	1,289,443
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	85,275	84,945
Other assets, net (WNRL: $3,348 and $3,376, respectively)	61,366	64,997
Total assets	5,753,762	5,833,393
Current liabilities:
Accounts payable (WNRL: $14,663 and $9,489, respectively)	562,430	553,957
Accrued liabilities (WNRL: $25,858 and $30,378, respectively)	218,752	248,395
Current portion of long-term debt	5,500	5,500
Total current liabilities	786,682	807,852
Long-term liabilities:
Long-term debt, less current portion (WNRL: $422,810 and $437,467, respectively)	1,652,592	1,644,894
Lease financing obligations	53,190	53,232
Deferred income tax liability, net	341,475	312,914
Other liabilities (WNRL: $9 in both periods)	69,023	68,595
Total long-term liabilities	$ 2,116,280	$ 2,079,635
Commitments and contingencies
Equity:
Common stock, par value $0.01, 240,000,000 shares authorized; 102,828,650 and 102,773,705 shares issued, respectively	$ 1,028	$ 1,028
Preferred stock, par value $0.01, 10,000,000 shares authorized; no shares issued or outstanding	0	0
Additional paid-in capital	492,847	492,848
Retained earnings	1,162,876	1,167,938
Accumulated other comprehensive loss, net of tax	651	651
Treasury stock, 11,551,973 and 9,089,623 shares, respectively at cost	(438,168)	(363,168)
Total Western shareholders' equity	1,219,234	1,299,297
Non-controlling interests	1,631,566	1,646,609
Total equity	2,850,800	2,945,906
Total liabilities and equity	$ 5,753,762	$ 5,833,393

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 593,101	$ 772,502
Accounts receivable, trade, net of a reserve for doubtful accounts	337,077	359,237
Reserve for doubtful accounts	195	169
Inventories	683,593	547,538
Prepaid expenses	79,971	73,213
Other current assets	159,591	169,728
Assets, Noncurrent [Abstract]
Property, plant and equipment, net	2,324,591	2,305,171
Intangible Assets, Net (Excluding Goodwill)	85,275	84,945
Other Assets, Noncurrent	61,366	64,997
Current liabilities:
Accounts Payable, Current	562,430	553,957
Accrued liabilities	218,752	248,395
Long-term liabilities:
Long-term debt, less current portion	1,652,592	1,644,894
Other long-term liabilities	$ 69,023	$ 68,595
Equity:
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	240,000,000	240,000,000
Common stock, shares issued	102,828,650	102,773,705
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Treasury stock, shares	11,551,973	9,089,623
Western Refining Logistics, LP [Member]
Current assets:
Cash and cash equivalents	$ 28,653	$ 44,605
Accounts receivable, trade, net of a reserve for doubtful accounts	60,946	55,053
Inventories	12,476	15,200
Prepaid expenses	5,380	4,133
Other current assets	5,510	5,562
Assets, Noncurrent [Abstract]
Property, plant and equipment, net	324,342	321,251
Intangible Assets, Net (Excluding Goodwill)	7,566	7,757
Other Assets, Noncurrent	3,348	3,376
Current liabilities:
Accounts Payable, Current	14,663	9,489
Accrued liabilities	25,858	30,378
Long-term liabilities:
Long-term debt, less current portion	422,810	437,467
Other long-term liabilities	$ 9	$ 9

Condensed Consolidated Statement of Operations (Unaudited) Statement - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Net sales	$ 1,455,504	$ 2,318,730
Operating Costs and Expenses [Abstract]
Cost of products sold (exclusive of depreciation and amortization)	1,047,361	1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	223,585	215,311
Selling, general and administrative expenses	53,285	55,803
Loss (gain) on disposal of assets, net	130	(282)
Maintenance turnaround expense	125	105
Depreciation and amortization	52,651	49,926
Total operating costs and expenses	1,376,877	2,062,737
Operating income	78,627	255,993
Other income (expense):
Interest income	164	163
Interest and debt expense	(26,681)	(24,957)
Other, net	6,104	3,206
Income before income taxes	58,214	234,405
Provision for income taxes	(18,629)	(59,437)
Net income	39,585	174,968
Less net income attributable to non-controlling interests	9,047	68,979
Net income attributable to Western Refining, Inc.	$ 30,538	$ 105,989
Earnings Per Share [Abstract]
Earnings Per Share, Basic	$ 0.34	$ 1.11
Earnings Per Share, Diluted	$ 0.33	$ 1.11
Weighted Average Number of Shares Outstanding [Abstract]
Weighted Average Number of Shares Outstanding, Basic	92,078	95,567
Weighted Average Number of Shares Outstanding, Diluted	92,144	95,682
Dividends [Abstract]
Cash dividends declared per common share	$ 0.38	$ 0.30

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Net income	$ 39,585	$ 174,968
Benefit plans:
Reclassification of loss to income	0	13
Other comprehensive income before tax	0	13
Income tax	0	(5)
Other comprehensive income, net of tax	0	8
Comprehensive income	39,585	174,976
Less comprehensive income attributable to non-controlling interests	9,047	68,979
Comprehensive income attributable to Western Refining, Inc.	$ 30,538	$ 105,997

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities:
Net income	$ 39,585	$ 174,968
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	52,651	49,926
Changes in fair value of commodity hedging instruments	12,483	20,057
Reserve for doubtful accounts	26	(46)
Amortization of loan fees and original issue discount	1,628	1,515
Stock-based compensation expense	6,181	4,010
Deferred income taxes	28,561	4,989
Excess tax benefit from stock-based compensation	0	(337)
Income from equity method investment, net of dividends	5,517	3,619
Loss (gain) on disposal of assets, net	130	(282)
Changes in operating assets and liabilities:
Accounts receivable	21,824	19,016
Inventories	(136,055)	(43,851)
Prepaid expenses	(6,758)	11,909
Other assets	(62)	(33,451)
Accounts payable and accrued liabilities	(14,362)	(99,041)
Other long-term liabilities	1,049	(1,349)
Net cash provided by operating activities	1,104	104,978
Cash flows from investing activities:
Capital expenditures	79,029	53,195
Use of restricted cash	32,323	43,400
Proceeds from the sale of assets	219	624
Net cash used in investing activities	(46,487)	(9,171)
Cash flows from financing activities:
Additions to long-term debt	0	300,000
Payments on long-term debt and capital lease obligations	(1,922)	(1,375)
Borrowings on revolving credit facility	70,000	0
Repayments on revolving credit facility	(62,500)	(269,000)
Deferred financing costs	0	6,551
Purchase of common stock for treasury	(75,000)	(25,000)
Distribution to non-controlling interest holders	(28,995)	(33,665)
Dividends paid	(35,601)	(28,638)
Excess tax benefit from stock-based compensation	0	337
Net cash used in financing activities	(134,018)	(63,892)
Net increase (decrease) in cash and cash equivalents	(179,401)	31,915
Cash and cash equivalents at beginning of period	772,502	431,159
Cash and cash equivalents at end of period	$ 593,101	$ 463,074

Organization (Notes)	3 Months Ended
Organization (Notes)	Mar. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	1. Organization "Western," "we," "us," "our" and the "Company" refer to Western Refining, Inc. and, unless the context otherwise requires, our subsidiaries. Western Refining, Inc. was formed on September 16, 2005, as a holding company prior to our initial public offering and is incorporated in Delaware. We produce refined products at three refineries: one in El Paso, Texas, one near Gallup, New Mexico and one in St. Paul Park, Minnesota. We sell refined products in Arizona, Colorado, Minnesota, New Mexico, Wisconsin, West Texas, the Mid-Atlantic region and Mexico. Our product sales occur through bulk distribution terminals, wholesale marketing networks and two retail networks with a total of 541 company-owned and franchised retail sites in the United States. At March 31, 2016, we owned a 38.3% limited partner interest in Northern Tier Energy LP ("NTI") and the public held a 61.7% limited partner interest. We control NTI through our 100% ownership of its general partner. NTI owns and operates a refinery in St. Paul Park, Minnesota and has a retail-marketing network of 283 convenience stores; 114 of which operate through franchise agreements. NTI's primary areas of operation include Minnesota and Wisconsin. We entered into an Agreement and Plan of Merger dated as of December 21, 2015 (the “Merger Agreement”) with Western Acquisition Co, LLC, a wholly-owned subsidiary of Western (“MergerCo”), NTI and Northern Tier Energy GP LLC, to acquire all of NTI’s outstanding common units not already held by us (the “Merger”). Each of the outstanding NTI common units held by unitholders other than us (the “NTI Public Unitholders”) will be converted under the terms of the Merger Agreement, into the right to receive, subject to election by the NTI Public Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western’s common stock, par value $0.01 per share (“Western Common Stock”), (ii) $26.06 in cash without interest or (iii) 0.7036 of a share of Western Common Stock. Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo will merge with and into NTI and the separate limited liability company existence of MergerCo will cease and NTI will continue to exist, as a limited partnership under Delaware law and as our indirect wholly-owned subsidiary, as the surviving entity in the Merger. The Merger is expected to close in the second quarter of 2016, pending the satisfaction of certain customary conditions and the approval of the Merger and other matters at a special meeting of NTI unitholders by the affirmative vote of holders of a majority of the outstanding NTI common units (including the NTI common units held by us). The transaction is expected to result in 17.2 million additional shares of Western Common Stock outstanding. Consistent with NTI’s distribution policy, cash distributions with respect to the second quarter of 2016, if any, would normally be declared and paid in August 2016. However, pursuant to the terms of the Merger Agreement, with respect to the quarter in which the closing date ("Closing Date") occurs, which is currently expected to be the second quarter of 2016, assuming all closing conditions are satisfied, NTI will, to the extent it generates available cash in such quarter, make a prorated quarterly distribution to unitholders of record as of immediately prior to the effective time of the Merger (the “Effective Time”) of any such available cash if the record date for the Western's quarterly cash dividend to be paid in that quarter occurs before the Closing Date. Accordingly, in the quarter that the Closing Date occurs, NTI common unitholders who receive Western Common Stock in the Merger will receive (i) an NTI cash distribution in respect of the previous quarter, to the extent that NTI generates available cash in such quarter, and (ii) either an NTI prorated cash distribution in respect of available cash generated by NTI in the quarter in which the Closing Date occurs or (assuming such unitholders continue to hold the shares of Western Common Stock received in the Merger through the record date for such Western dividend) the Western quarterly cash dividend payable in the quarter in which the Closing Date occurs. The amount of any distribution will not have any effect on the merger consideration to be received by the NTI’s unitholders. See Note 21, NTI, for further discussion. At March 31, 2016, we owned a 66.4% limited partner interest in Western Refining Logistics, LP ("WNRL") and the public held a 33.6% limited partner interest. We control WNRL through our 100% ownership of its general partner and we own the majority of WNRL's limited partnership interests. WNRL owns and operates logistics assets consisting of pipeline and gathering, terminalling, storage and transportation assets as well a wholesale business that operates primarily in the Southwest. WNRL operates its logistics assets primarily for the benefit of the Company. See Note 22, WNRL, for further discussion. On October 30, 2015, we sold a 375 mile segment of the TexNew Mex Pipeline system to WNRL that extends from WNRL's crude oil station in Star Lake, New Mexico, in the Four Corners region to its T station in Eddy County, New Mexico (the "TexNew Mex Pipeline System"). We also sold an 80,000 barrel crude oil storage tank located at WNRL's crude oil pumping station in Star Lake, New Mexico and certain other related assets. WNRL acquired these assets from us in exchange for $170 million in cash, 421,031 common units representing limited partner interests in WNRL and 80,000 units of a newly created class of limited partner interests in WNRL, referred to as the "TexNew Mex Units." We refer to this transaction as the "TexNew Mex Pipeline Transaction." The WNRL financial and operational data presented includes the historical results of all assets acquired from Western in the TexNew Mex Pipeline Transaction. The acquisition from Western was a transfer of assets between entities under common control. Accordingly, the financial information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the TexNew Mex Pipeline System assets acquired, for periods prior to the effective date of the TexNew Mex Pipeline Transaction. Our operations include four business segments: refining, NTI, WNRL and retail. See Note 3, Segment Information, for further discussion of our business segments.

Basis of Presentation and Significant Accounting Policies (Notes)

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation and Significant Accounting Policies [Text Block]

2. Basis of Presentation and Significant Accounting Policies

Principles of Consolidation

Variable Interest Entity

Goodwill and Other Unamortizable Intangible Assets

Use of Estimates and Seasonality

Recent Accounting Pronouncements

•

Segment Information (Notes)

3 Months Ended

Mar. 31, 2016

Segment Reporting [Abstract]

Segment Information

3. Segment Information

A description of each segment and the principal products follows:

The total assets of each segment consist primarily of cash and cash equivalents; inventories; net accounts receivable; net property, plant and equipment and other assets directly associated with the individual segment’s operations. Included in the total assets of the corporate operations are cash and cash equivalents; various net accounts receivable; prepaid expenses; other current assets; net property, plant and equipment and other long-term assets.

Disclosures regarding our reportable segments with reconciliations to consolidated totals for the three months ended March 31, 2016 and 2015 are presented below:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Operating Results:
Refining (2)
Net sales	$	886,320		$	1,491,441
Intersegment eliminations	467,807			542,542
Net refining sales to external customers	418,513			948,899
NTI
Net sales	497,473			697,776
Intersegment eliminations	8,696			12,990
Net NTI sales to external customers	488,777			684,786
WNRL (2)
Net sales	468,039			607,396
Intersegment eliminations	149,462			178,249
Net WNRL sales to external customers	318,577			429,147
Retail
Net sales	231,186			258,602
Intersegment eliminations	1,549			2,704
Net retail sales to external customers	229,637			255,898

Consolidated net sales to external customers	$	1,455,504		$	2,318,730

Operating income (loss)
Refining (1) (2)	$	62,138		$	148,612
NTI (1)	8,115			107,987
WNRL (2)	21,438			17,561
Retail	2,432			(441		)
Other	(15,496		)	(17,726		)
Operating income from segments	78,627			255,993
Other income (expense), net	(20,413		)	(21,588		)
Consolidated income before income taxes	$	58,214		$	234,405



	Three Months Ended
	March 31,
	2016		2015
Depreciation and amortization
Refining (2)	$	21,285	$	20,484
NTI	19,969		19,365
WNRL (2)	7,144		5,892
Retail	3,330		3,286
Other	923		899
Consolidated depreciation and amortization	$	52,651	$	49,926

Capital expenditures
Refining (2)	$	43,563	$	17,826
NTI	27,990		6,673
WNRL (2)	6,241		25,996
Retail	637		1,402
Other	598		1,298
Consolidated capital expenditures	$	79,029	$	53,195

Total assets
Refining (2)	$	1,620,113	$	1,606,073
NTI (including $1,289,443 of goodwill)	2,328,446		2,258,695
WNRL (2)	448,218		495,028
Retail	239,359		249,318
Other	1,117,626		1,075,408
Consolidated total assets	$	5,753,762	$	5,684,522

(1)

(2)

Fair Value Measurement (Notes)

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurement

4. Fair Value Measurement

The fair value hierarchy consists of the following three levels:


Level 1	Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.


Level 2	Inputs are quoted prices for similar assets or liabilities in an active market, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable and market-corroborated inputs that are derived principally from or corroborated by observable market data.


Level 3	Inputs are derived from valuation techniques that one or more significant inputs or value drivers are unobservable and cannot be corroborated by market data or other entity-specific inputs.



	Carrying Value at March 31, 2016			Fair Value Measurement Using								Netting Adjustments			Recorded Value at March 31, 2016
	Carrying Value at March 31, 2016			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at March 31, 2016
	(In thousands)
Gross financial assets:
Other current assets	$	86,144		$	—	$	86,144		$	—		$	(19,080	)	$	67,064
Other assets	8,019			—		8,019			—			(867		)	7,152
Gross financial liabilities:
Accrued liabilities	(12,647		)	—		(8,689		)	(3,958		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	—		(14,437		)	—			14,437			—
	$	67,079		$	—	$	71,037		$	(3,958	)	$	—		$	67,079



	Carrying Value at December 31, 2015			Fair Value Measurement Using								Netting Adjustments			Recorded Value at December 31, 2015
	Carrying Value at December 31, 2015			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at December 31, 2015
	(In thousands)
Gross financial assets:
Other current assets	$	95,062		$	—	$	95,062		$	—		$	(16,937	)	$	78,125
Other assets	11,881			—		11,881			—			—			11,881
Gross financial liabilities:
Accrued liabilities	(21,454		)	—		(15,698		)	(5,756		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	—		(5,756		)	—			5,756			—
	$	79,733		$	—	$	85,489		$	(5,756	)	$	—		$	79,733



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Asset (liability) balance at beginning of period	$	(5,756	)	$	330
Change in fair value	186			—
Fair value of trades entered into during the period	—			1,462
Fair value reclassification from Level 3 to Level 2	1,612			(82		)
Asset (liability) balance at end of period	$	(3,958	)	$	1,710

A hypothetical change of 10% to the estimated future cash flows attributable to our Level 3 commodity price swaps would result in a $0.4 million change in the estimated fair value at March 31, 2016.

As of March 31, 2016 and December 31, 2015, the carrying amount and estimated fair value of our debt was as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Western obligations:
Carrying amount	$	887,625	$	889,000
Fair value	838,373		867,178
NTI obligations:
Carrying amount	$	372,500	$	350,000
Fair value	367,250		360,500
WNRL obligations:
Carrying amount	$	430,000	$	445,000
Fair value	400,000		439,000

The carrying amount of our debt is the amount reflected in the Condensed Consolidated Balance Sheets, including the current portion. The fair value of the debt was determined using Level 2 inputs.

Inventories (Notes)

3 Months Ended

Mar. 31, 2016

Inventory Disclosure [Abstract]

Inventory Disclosure [Text Block]

5. Inventories

Inventories were as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Refined products (1)	$	267,861	$	201,928
Crude oil and other raw materials	362,415		288,403
Lubricants	12,356		14,996
Retail store merchandise	40,961		42,211
Inventories	$	683,593	$	547,538


(1)	Includes $15.0 million and $14.5 million of inventory valued using the first-in, first-out ("FIFO") valuation method at March 31, 2016 and December 31, 2015, respectively.

Average LIFO cost per barrel of our refined products and crude oil and other raw materials inventories as of March 31, 2016 and December 31, 2015, were as follows:



	March 31, 2016					December 31, 2015
	Barrels	LIFO Cost		Average LIFO Cost Per Barrel		Barrels	LIFO Cost		Average LIFO Cost Per Barrel
	(In thousands, except cost per barrel)
Refined products	5,130	$	314,934	$	61.39	3,536	$	259,722	$	73.45
Crude oil and other	7,462	423,694		56.78		6,490	391,237		60.28
	12,592	$	738,628	58.66		10,026	$	650,959	64.93

Equity Method Investment (Notes)	3 Months Ended
Equity Method Investment (Notes)	Mar. 31, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investment [Text Block]	6. Equity Method Investment NTI owns a 17% common equity interest in Minnesota Pipe Line Company, LLC ("MPL"). The carrying value of this equity method investment was $103.0 million and $97.5 million at March 31, 2016 and December 31, 2015, respectively. As of March 31, 2016 and December 31, 2015, the carrying amount of the equity method investment was $21.3 million higher than the underlying net assets of the investee. We are amortizing this difference over the remaining life of MPL’s primary asset (the fixed asset life of the pipeline). There is no market for the common units of MPL and, accordingly, no quoted market price is available. We received no distributions during the three months ended March 31, 2016. During the three months ended March 31, 2015, we recognized $3.7 million in declared but unpaid distributions from MPL. Equity income from MPL for the three months ended March 31, 2016 and 2015, was $5.5 million and $3.6 million, respectively. Equity income has been included in other, net in the accompanying Condensed Consolidated Statements of Operations.

(Notes)

3 Months Ended

Mar. 31, 2016

Property, Plant and Equipment [Abstract]

Property, Plant, and Equipment, Net

7. Property, Plant and Equipment, Net

Property, plant and equipment, net was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Refinery facilities and related equipment	$	2,390,745		$	2,348,663
Pipelines, terminals and transportation equipment	559,040			533,040
Retail facilities and related equipment	329,808			328,419
Wholesale facilities and related equipment	61,369			61,133
Corporate	51,451			50,812
	3,392,413			3,322,067
Accumulated depreciation	(1,067,822		)	(1,016,896		)
Property, plant and equipment, net	$	2,324,591		$	2,305,171

Depreciation expense was $51.6 million and $48.9 million for the three months ended March 31, 2016 and 2015, respectively.

Intangible Assets, Net (Notes)

3 Months Ended

Mar. 31, 2016

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Intangible Assets, Net

8. Intangible Assets, Net

Intangible assets, net was as follows:



	March 31, 2016							December 31, 2015							Weighted- Average Amortization Period (Years)
	Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Weighted- Average Amortization Period (Years)
	(In thousands)
Amortizable assets:
Licenses and permits	$	20,427	$	(14,124	)	$	6,303	$	20,427	$	(13,729	)	$	6,698	4.0
Customer relationships	7,551		(4,060		)	3,491		7,551		(3,921		)	3,630		6.3
Rights-of-way and other	7,905		(1,999		)	5,906		6,839		(1,797		)	5,042		8.6
	35,883		(20,183		)	15,700		34,817		(19,447		)	15,370
Unamortizable assets:
Franchise rights and trademarks	50,500		—			50,500		50,500		—			50,500
Liquor licenses	19,075		—			19,075		19,075		—			19,075
Intangible assets, net	$	105,458	$	(20,183	)	$	85,275	$	104,392	$	(19,447	)	$	84,945

Estimated amortization expense for the indicated periods is as follows (in thousands):



Remainder of 2016	$	2,204
2017	2,906
2018	2,905
2019	2,237
2020	1,292
2021	1,006

Long-Term Debt (Notes)

3 Months Ended

Mar. 31, 2016

Debt Disclosure [Abstract]

Long-Term Debt

9. Long-Term Debt

Long-term debt was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Western obligations:
Revolving Credit Facility due 2019	$	—		$	—
Term Loan Credit Facility due 2020	537,625			539,000
6.25% Senior Unsecured Notes due 2021	350,000			350,000
Total Western obligations	887,625			889,000
NTI obligations:
Revolving Credit Facility due 2019	22,500			—
7.125% Senior Secured Notes due 2020	350,000			350,000
Total NTI obligations	372,500			350,000
WNRL obligations:
Revolving Credit Facility due 2018	130,000			145,000
7.5% Senior Notes due 2023	300,000			300,000
Total WNRL obligations	430,000			445,000
Less unamortized premium and debt issuance costs	32,033			33,606
Long-term debt	1,658,092			1,650,394
Current portion of long-term debt	(5,500		)	(5,500		)
Long-term debt, net of current portion	$	1,652,592		$	1,644,894

Interest and debt expense were as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Contractual interest:
Western obligations	$	12,052		$	12,007
NTI obligations	6,914			6,591
WNRL obligations	6,705			3,726
	25,671			22,324
Amortization of loan fees	1,911			1,786
Other interest expense	(176		)	1,075
Capitalized interest	(725		)	(228		)
Interest and debt expense	$	26,681		$	24,957

Western Obligations

Revolving Credit Facility

Term Loan Credit Agreement

6.25% Senior Unsecured Notes

NTI Obligations

Revolving Credit Facility

On September 29, 2014, certain subsidiaries of NTI entered into the Amended and Restated Revolving Credit Agreement (the "NTI Revolving Credit Facility"), increasing the aggregate principal amount available prior to the amendment and restatement from $300.0 million to $500.0 million. The NTI Revolving Credit Facility, which matures on September 29, 2019, incorporates a borrowing base tied to eligible accounts receivable and inventory and provides for up to $500.0 million for the issuance of letters of credit and up to $45.0 million for swing line loans. The NTI Revolving Credit Facility may be increased up to a maximum aggregate principal amount of $750.0 million, subject to certain conditions (including the agreement of financial institutions, in their sole discretion, to provide such additional commitments). Obligations under the NTI Revolving Credit Facility are secured by substantially all of NTI’s assets. Indebtedness under the NTI Revolving Credit Facility is recourse to Northern Tier Energy GP LLC ("NTI LLC") and certain of its subsidiaries that are borrowers thereunder, its general partner, and is guaranteed by NTI and certain of its subsidiaries. Borrowings under the NTI Revolving Credit Facility bear interest at either (a) a base rate plus an applicable margin (ranging between 0.50% and 1.00%) or (b) a LIBOR rate plus an applicable margin (ranging between 1.50% and 2.00%), in each case subject to adjustment based upon the average historical excess availability. In addition to paying interest on outstanding borrowings, NTI is also required to pay a quarterly commitment fee ranging from 0.250% to 0.375% subject to adjustment based upon the average utilization ratio and letter of credit fees ranging from 1.50% to 2.00% subject to adjustment based upon the average historical excess availability. The NTI Revolving Credit Facility contains certain covenants, including but not limited to, limitations on debt, investments and dividends and the maintenance of a minimum fixed charge coverage ratio in certain circumstances. NTI incurred financing costs of $3.0 million associated with the amended and restated NTI Revolving Credit Facility.

7.125% Secured Notes

WNRL Obligations

Revolving Credit Facility

7.5% Senior Notes

Equity (Notes)

3 Months Ended

Mar. 31, 2016

Equity [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

10. Equity

Changes to equity during the three months ended March 31, 2016, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2015	$	1,299,297		$	1,646,609		$	2,945,906
Net income	30,538			9,047			39,585
Dividends	(35,601		)	—			(35,601		)
Stock-based compensation	328			4,657			4,985
Tax deficiency from stock-based compensation	(328		)	—			(328		)
Distributions to non-controlling interests	—			(28,747		)	(28,747		)
Treasury stock purchases	(75,000		)	—			(75,000		)
Balance at March 31, 2016	$	1,219,234		$	1,631,566		$	2,850,800

Changes to equity during the three months ended March 31, 2015, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2014	$	1,119,708		$	1,667,936		$	2,787,644
Net income	105,989			68,979			174,968
Other comprehensive income, net of tax	8			—			8
Dividends	(28,638		)	—			(28,638		)
Stock-based compensation	1,001			2,503			3,504
Excess tax benefit from stock-based compensation	337			—			337
Distributions to non-controlling interests	—			(33,665		)	(33,665		)
Treasury stock purchases	(25,000		)	—			(25,000		)
Balance at March 31, 2015	$	1,173,405		$	1,705,753		$	2,879,158

Share Repurchase Programs

The following table summarizes our share repurchase activity for the September 2015 Program:



	Number of shares purchased	Cost of share purchases (In thousands)
Shares purchased at December 31, 2015	—	$	—
Shares purchased during Q1, 2016	2,462,350	75,000
Shares purchased at March 31, 2016	2,462,350	$	75,000

As of March 31, 2016, we had $125.0 million remaining in authorized expenditures under the September 2015 Program.

Dividends

The table below summarizes our 2016 cash dividend declarations, payments and scheduled payments:

Declaration Date

Record Date

Payment Date

Dividend per Common Share

Total Payment

(In thousands)

First quarter

January 6

January 20

February 4

0.38

35,601

Second quarter (1)

April 8

April 18

May 2

0.38

—

Total

35,601

(1) The second quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $34.7 million.

NTI Distributions

The table below summarizes NTI's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Unit
February 3, 2016	February 12, 2016	February 19, 2016	$	0.38
Total			$	0.38

On April 29, 2016, the board of directors of NTI's general partner chose not to approve a quarterly distribution.

WNRL Distributions

The table below summarizes WNRL's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Common and Subordinated Unit
February 1, 2016	February 11, 2016	February 26, 2016	$	0.3925
April 25, 2016	May 13, 2016	May 27, 2016	0.4025
Total			$	0.7950

Income Taxes (Notes)	3 Months Ended
Income Taxes (Notes)	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	11. Income Taxes Compared to the federal statutory rate of 35%, our effective tax rates for the three months ended March 31, 2016 and 2015, were 32.0% and 25.4%, respectively. The effective tax rates for the three months ended March 31, 2016 and 2015, were lower than the statutory rate primarily due to the reduction of taxable income associated with the non-controlling interests in NTI and WNRL. We are subject to examination by the Internal Revenue Service for tax years ending December 31, 2012, or after and by various state and local taxing jurisdictions for tax years ending December 31, 2011, or after. We believe that it is more likely than not that the benefit from certain state net operating loss ("NOL") carryforwards related to the Yorktown refinery will not be realized. Accordingly, a valuation allowance of $20.8 million was previously provided against the deferred tax assets relating to these NOL carryforwards at March 31, 2016. There was no change in the valuation allowance for the Yorktown NOL carryforwards from December 31, 2015. As of March 31, 2016, we have recorded a liability of $40.2 million for unrecognized tax benefits, of which $20.9 million would affect our effective tax rate if recognized. There was no material change for unrecognized tax benefits for the three months ended March 31, 2016. We also recognized $0.2 million and $0.1 million in interest and penalties for the three months ended March 31, 2016 and 2015, respectively.

Retirement Plans (Notes)

3 Months Ended

Mar. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Retirement Plans

12. Retirement Plans

We fully recognize the obligations associated with our retiree healthcare and other postretirement plans and NTI's single-employer defined benefit cash balance plan in our financial statements.

Pensions

The net periodic benefit cost associated with NTI's cash balance plan for both the three months ended March 31, 2016 and 2015, was $0.6 million.

Postretirement Obligations

The net periodic benefit cost associated with our postretirement medical benefit plans for the three months ended March 31, 2016 and 2015, was $0.03 million and $0.2 million, respectively.

Our benefit obligation at December 31, 2015, for our postretirement medical benefit plans was $6.2 million. We fund our medical benefit plans on an as-needed basis.



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Beginning of period balance	$	651	$	(1,291	)
Reclassification of loss to income	—		13
Income tax	—		(5		)
End of period balance	$	651	$	(1,283	)

Defined Contribution Plan

Crude Oil and Refined Product Risk Management (Notes)

3 Months Ended

Mar. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Crude Oil and Refined Product Risk Management

13. Crude Oil and Refined Product Risk Management



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Economic hedging results
Realized hedging gain, net	$	17,803		$	17,553
Unrealized hedging loss, net	(12,483		)	(20,057		)
Total hedging gain (loss), net	$	5,320		$	(2,504	)



	March 31, 2016			December 31, 2015
	(In thousands)
Open commodity hedging instruments (barrels)
Crude oil differential swaps, net long positions	7,201			5,155
Crude oil futures, net short positions	(1,823		)	(562		)
Refined product price and crack spread swaps, net short positions	(2,900		)	(5,645		)
Total open commodity hedging instruments, net long (short) positions	2,478			(1,052		)

Fair value of outstanding contracts, net
Other current assets	$	67,064		$	78,125
Other assets	7,152			11,881
Accrued liabilities	(7,137		)	(10,273		)
Other long-term liabilities	—			—
Fair value of outstanding contracts - unrealized gain, net	$	67,079		$	79,733

Offsetting Assets and Liabilities

The following table presents offsetting information regarding Western's commodity hedging contracts as of March 31, 2016 and December 31, 2015:



	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of March 31, 2016	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	86,144		$	(19,080	)	$	67,064
Other assets	8,019			(867		)	7,152
Financial liabilities:
Accrued liabilities	(12,647		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	14,437			—
	$	67,079		$	—		$	67,079



	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of December 31, 2015	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	95,062		$	(16,937	)	$	78,125
Other assets	11,881			—			11,881
Financial liabilities:
Accrued liabilities	(21,454		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	5,756			—
	$	79,733		$	—		$	79,733



	Notional Contract Volumes by Year of Maturity
	2016		2017		2018
Inventory positions (futures and swaps):
Crude oil differential swaps, net long positions	5,283		1,918		—
Crude oil futures, net short positions	(1,823	)	—		—
Refined products — net short positions	(999	)	—		—
Natural gas futures — net long positions	720		329		—
Refined product positions (crack spread swaps):
Distillate — net short positions	(744	)	(1,305	)	—
Unleaded gasoline — net short positions	(900	)	—		—

Stock-Based Compensation (Notes)

3 Months Ended

Mar. 31, 2016

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation

14. Stock-Based Compensation

Western Incentive Plans

The following table summarizes our RSU activity for the three months ended March 31, 2016:



	Number of Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	399,214		$	37.43
Awards granted	339,618		29.60
Awards vested	(79,118	)	40.71
Awards forfeited	(3,424	)	43.81
Not vested at March 31, 2016	656,290		32.95

NTI 2012 Long-Term Incentive Plan

As of March 31, 2016 and December 31, 2015, the total unrecognized compensation cost for NTI LTIP units was $26.3 million and $16.1 million, respectively.

NTI incurred $4.6 million and $2.6 million of unit-based compensation expense for the three months ended March 31, 2016 and 2015, respectively.

Restricted Common Units

Phantom Common Units

Service-based Awards

During 2014, NTI began awarding service-based phantom common units to certain employees. As of March 31, 2016, NTI had 726,842 service-based phantom common units outstanding. Upon vesting, NTI may settle these units in NTI common units or cash at the discretion of NTI's board of directors or its Compensation Committee. Like the restricted common units, the phantom common units participate in distributions on an equal basis with common units. However, distributions on phantom common units are accrued until the underlying units vest at which time the distributions are paid in cash. In the event that unvested phantom common units are forfeited or canceled, any accrued distributions on the underlying units are forfeited by the grantee. As of March 31, 2016 and December 31, 2015, NTI had $1.7 million and $2.5 million, respectively, in accrued service-based phantom common unit distributions included in accrued liabilities and other liabilities in the Condensed Consolidated Balance Sheets. For phantom common unit awards outstanding at March 31, 2016, the forfeiture rates on NTI LTIP awards ranged from zero to 20%, depending on the employee classification.

Performance-based Phantom Units



	2016 Awards		2015 Awards
Expected volatility	29.80	%	34.10	%
Risk-free interest rate	1.08	%	0.84	%

A summary of the NTI LTIP common unit activity for the three months ended March 31, 2016, is set forth below:



	Restricted Units				Phantom Units
	Restricted Units				Service-Based Units		Performance-Based Units		Total		Weighted Average Grant Date Fair Value
	Number of Units		Weighted Average Grant Date Fair Value		Number of Units		Number of Units		Total		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	191,424		$	24.75	581,882		260,690		842,572		$	24.00
Awards granted	—		—		381,029		163,571		544,600		30.27
Incremental performance units	—		—		—		231,777		231,777		38.17
Awards vested	(34,054	)	26.84		(235,546	)	(1,789	)	(237,335	)	24.05
Awards forfeited	—		—		(523	)	(1,463	)	(1,986	)	24.01
Not vested at March 31, 2016	157,370		24.30		726,842		652,786		1,379,628		28.90

Western Refining Logistics, LP 2013 Long-Term Incentive Plan

A summary of WNRL's common and phantom unit award activity for the three months ended March 31, 2016, is set forth below:



	Number of Phantom Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	279,787		$	28.06
Awards granted	75,919		22.53
Awards vested	(60,705	)	26.80
Awards forfeited	—		—
Not vested at March 31, 2016	295,001		26.64

Earnings per Share (Notes)

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Earnings Per Share [Text Block]

15. Earnings per Share

The computation of basic and diluted earnings per share under the two-class method is presented as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands, except per share data)
Basic earnings per common share:
Allocation of earnings:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Distributed earnings	(35,601		)	(28,638		)
Undistributed income (loss) available to Western Refining, Inc.	$	(5,063	)	$	77,351
Weighted-average number of common shares outstanding	92,078			95,567
Basic earnings per common share:
Distributed earnings per share	$	0.39		$	0.30
Undistributed earnings (loss) per share	(0.05		)	0.81
Basic earnings per common share	$	0.34		$	1.11

Diluted earnings per common share:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Weighted-average diluted common shares outstanding	92,144			95,682
Diluted earnings per common share	$	0.33		$	1.11

The computation of the weighted average number of diluted shares outstanding is presented below:



	Three Months Ended
	March 31,
	2016	2015
	(In thousands)
Weighted-average number of common shares outstanding	92,078	95,567
Restricted share units	66	115
Weighted-average number of diluted shares outstanding	92,144	95,682

Cash Flows (Notes)

3 Months Ended

Mar. 31, 2016

Supplemental Cash Flow Elements [Abstract]

Cash Flows

16. Cash Flows

Restricted Cash

Supplemental Cash Flow Information

Supplemental disclosures of cash flow information were as follows:



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Income taxes paid	$	11,215	$	40,009
Interest paid, excluding amounts capitalized	20,676		8,959

Non-cash investing and financing activities were as follows:
Assets acquired through capital lease obligations	$	328	$	19,511
Accrued capital expenditures	46,045		12,741
Distributions receivable from equity method investee	—		3,740
Distributions accrued on unvested NTI equity awards	3,964		—
Transfer of capital spares from fixed assets to other assets	699		—

Leases and Other Commitments (Notes)

3 Months Ended

Mar. 31, 2016

Leases [Abstract]

Commitments Disclosure [Text Block]

17. Leases and Other Commitments



	Operating		Capital
Remaining 2016	$	43,908	$	3,859
2017	52,828		5,060
2018	49,495		5,084
2019	44,407		5,195
2020	40,218		5,386
2021 and thereafter	340,046		70,941
Total minimum lease payments	$	570,902	95,525
Less amount that represents interest			43,476
Present value of net minimum capital lease payments			$	52,049

Contingencies (Notes)	3 Months Ended
Contingencies (Notes)	Mar. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Contingencies	18. Contingencies Environmental Matters Similar to other petroleum refiners, our operations are subject to extensive and periodically changing federal and state environmental regulations governing air emissions, wastewater discharges and solid and hazardous waste management activities. Many of these regulations are becoming increasingly stringent and the cost of compliance can be expected to increase over time. Our policy is to accrue environmental and clean-up related costs of a non-capital nature when it is probable that a liability has been incurred and the amount can be reasonably estimated. Such estimates may be subject to revision in the future as regulations and other conditions change. Periodically, we receive communications from various federal, state and local governmental authorities asserting violations of environmental laws and/or regulations. These governmental entities may also propose or assess fines or require corrective action for these asserted violations. We intend to respond in a timely manner to all such communications and to take appropriate corrective action. We do not anticipate that any such matters currently asserted will have a material impact on our financial condition, results of operations or cash flows. As of March 31, 2016 and December 31, 2015, we had consolidated environmental accruals of $19.4 million and $18.3 million, respectively. El Paso Refinery Prior spills, releases and discharges of petroleum or hazardous substances have impacted the groundwater and soils in certain areas at and adjacent to our El Paso refinery. We are currently remediating, in conjunction with Chevron U.S.A., Inc. ("Chevron"), these areas in accordance with certain agreed administrative orders with the Texas Commission on Environmental Quality (the "TCEQ"). Pursuant to our purchase of the north side of the El Paso refinery from Chevron, Chevron retained responsibility to remediate its solid waste management units in accordance with its Resource Conservation Recovery Act ("RCRA") permit that Chevron has fulfilled. Chevron also retained control of and liability for certain groundwater remediation responsibilities that are ongoing. In May 2000, we entered into an Agreed Order with the TCEQ for remediation of the south side of our El Paso refinery property. We purchased a non-cancelable Pollution and Legal Liability and Clean-Up Cost Cap Insurance policy that covers environmental clean-up costs related to contamination that occurred prior to December 31, 1999, including the costs of the Agreed Order activities. The insurance provider assumed responsibility for all environmental clean-up costs related to the Agreed Order up to $20.0 million, of which $6.6 million remained as of March 31, 2016. In addition, a subsidiary of Chevron is obligated under a settlement agreement to pay 60% of any Agreed Order environmental clean-up costs that exceed the $20.0 million policy coverage. Four Corners Refineries Four Corners 2005 Consent Agreements. In July 2005, as part of the EPA Initiative, Giant Industries, Inc., our wholly-owned subsidiary, reached an administrative settlement with the New Mexico Environment Department (the "NMED") and the EPA in the form of consent agreements that resolved certain alleged violations of air quality regulations at the Gallup and Bloomfield refineries in the Four Corners area of New Mexico. In January 2009 and June 2012, we and the NMED agreed to amendments of the 2005 administrative settlement (the "2005 NMED Amended Agreement") that altered certain deadlines and allowed for alternative air pollution controls. We incurred $50.8 million in total capital expenditures between 2009 and 2013 to address the requirements of the 2005 NMED Amended Agreement. These capital expenditures were primarily for installation of emission controls on the heaters, boilers and Fluid Catalytic Cracking Unit ("FCCU") and for reducing sulfur in fuel gas to reduce emissions of sulfur dioxide, NOx and particulate matter from our Gallup refinery. As of March 31, 2016, we have completed the capital expenditures required by the 2005 NMED Amended Agreement to implement one or more FCCU emission offset projects prior to the end of 2017. We incurred $0.1 million and $1.9 million, respectively, for the years ended December 31, 2015 and 2014, and $0.1 million in the three months ended March 31, 2016 to implement an FCC emission offset project. We paid penalties between 2009 and 2012 totaling $2.7 million. Bloomfield 2007 NMED Remediation Order. In July 2007, we received a final administrative compliance order from the NMED alleging that releases of contaminants and hazardous substances that have occurred at the Bloomfield refinery over the course of its operation prior to June 1, 2007, have resulted in soil and groundwater contamination. Among other things, the order requires that we investigate the extent of such releases, perform interim remediation measures and implement corrective measures. Prior to July 2007, with the approval of the NMED and the New Mexico Oil Conservation Division, we placed into operation certain remediation measures that remain operational. Gallup 2014 Environment Protection Division of NMED Settlement. In March 2014, we received a revised notice of violation and offer of settlement from the NMED Air Quality Bureau for alleged violations of the Clean Air Act. We agreed to settle and paid a penalty of $0.1 million in May 2014. No capital expenditures are required under the settlement. NTI At March 31, 2016 and December 31, 2015, liabilities for remediation and closure obligations by NTI totaled $8.5 million and $8.6 million, respectively, of which $2.5 million and $2.6 million, respectively, are recorded on a discounted basis. These discounted liabilities are expected to be settled over at least the next 22 years. At March 31, 2016, the estimated future cash flows to settle these discounted liabilities totaled $3.0 million and are discounted at a rate of 2.27%. Receivables for recoverable costs from the state, under programs to assist companies in clean-up efforts related to underground storage tanks at retail marketing outlets, and others were $0.1 million and $0.2 million at March 31, 2016 and December 31, 2015, respectively. On June 3, 2014, the St. Paul Park refinery was issued a National Pollutant Discharge Elimination Permit/State Disposal System Permit by the Minnesota Pollution Control Agency ("MPCA") relating to its upgraded wastewater treatment plant at its St. Paul Park refinery. This permit required the refinery to conduct additional testing of its remaining lagoon. The testing was completed in the fourth quarter of 2014, following NTI's review of the test results and additional discussions with MPCA, NTI plans to close the remaining lagoon. At March 31, 2016 and December 31, 2015, NTI estimated the remediation and closure costs to be $6.0 million, subject to receipt of final bids from contractors. In connection with NTI's December 2010 acquisition of the St. Paul Park refinery, among other assets, from the Marathon Petroleum Company LP ("Marathon"), NTI entered into an agreement with Marathon that required Marathon to share in the future remediation costs of this lagoon, should they be required. During the third quarter of 2015, NTI entered into a settlement and release agreement with Marathon and received $3.5 million pursuant to this settlement that NTI recorded as a reduction of direct operating expenses. Other Matters The EPA has issued Renewable Fuels Standards ("RFS"), that require us and other refiners to blend renewable fuels into the refined products produced at our refineries. Annually, the EPA is required to establish a volume of renewable fuels that refineries must blend into their refined petroleum fuels. To the extent we are unable to blend at the rate necessary to satisfy the EPA mandated volume, we purchase Renewable Identification Numbers ("RINs"). The purchase price for RINs is volatile and may vary significantly from period to period. The net cost of meeting our estimated renewable volume obligations, including sales and purchases of RINs, was $13.6 million and $6.2 million for the three months ended March 31, 2016 and 2015, respectively. The supply and demand environment for RINs is uncertain and we cannot predict the impact of RINs purchases on our results of operations in any given period. In addition, the EPA has investigated and brought enforcement actions against companies it believes produced invalid RINs. We may have purchased RINs that the EPA will determine are invalid. Previously, we have entered into settlements and entered into another settlement in May 2015, with the EPA regarding RINs we purchased that the EPA ultimately determined were invalid. While we do not know if the EPA will determine that other RINs we have purchased are invalid, at this time we do not expect any settlements we would enter into with the EPA would have a material effect on our financial condition, results of operations or cash flows. We are party to various other claims and legal actions arising in the normal course of business. We believe that the resolution of these matters will not have a material effect on our financial condition, results of operations or cash flows.

Related Party Transactions (Notes)	3 Months Ended
Related Party Transactions (Notes)	Mar. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions Disclosure [Text Block]	19. Related Party Transactions We lease office space in a building located in El Paso, Texas that is owned by an entity controlled by one of our officers. The lease agreement expires in May 2017. Under the terms of the lease, we make annual payments of $0.2 million. For the three months ended March 31, 2016 and 2015, we made rental payments under this lease to the related party of $0.06 million. We have no amounts due as of March 31, 2016, related to this lease agreement. Beginning on September 30, 2014, NTI began paying MPL for transportation services at published tariff rates. During the three months ended March 31, 2016 and 2015, NTI paid $14.0 million and $12.7 million, respectively, in crude transportation costs with MPL. Prior to September 30, 2014, NTI had a crude oil supply and logistics agreement with a third-party and had no direct supply transactions with MPL prior to this date. NTI's Chief Executive Officer is a member of MPL's board of managers.

Condensed Consolidating Financial Information (Notes)

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Condensed Financial Statements [Text Block]

20. Condensed Consolidating Financial Information

CONDENSED CONSOLIDATING BALANCE SHEETS

As of March 31, 2016

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	529,460	$	63,620	$	—		$	593,101
Accounts receivable, trade, net of a reserve for doubtful accounts	—		104,551		232,526		—			337,077
Accounts receivable, affiliate	3,007		66,012		2,544		(71,563		)	—
Inventories	—		419,692		263,901		—			683,593
Prepaid expenses	—		61,472		18,499		—			79,971
Other current assets	—		118,778		40,813		—			159,591
Total current assets	3,028		1,299,965		621,903		(71,563		)	1,853,333
Restricted cash	—		36,783		—		—			36,783
Equity method investment	—		—		102,971		—			102,971
Property, plant and equipment, net	—		1,106,879		1,217,712		—			2,324,591
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,923		53,352		—			85,275
Investment in subsidiaries	3,994,766		—		—		(3,994,766		)	—
Due from affiliate	—		1,894,627		—		(1,894,627		)	—
Other assets, net	—		37,975		23,391		—			61,366
Total assets	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	10,938	$	251,898	$	299,594	$	—		$	562,430
Accounts payable, affiliate	—		—		71,563		(71,563		)	—
Accrued liabilities	10,975		110,587		97,190		—			218,752
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	27,413		362,485		468,347		(71,563		)	786,682
Long-term liabilities:
Long-term debt, less current portion	856,520		—		796,072		—			1,652,592
Due to affiliate	1,894,627		—		—		(1,894,627		)	—
Lease financing obligation	—		41,943		11,247		—			53,190
Deferred income tax liability, net	—		304,195		37,280		—			341,475
Deficit in subsidiaries	—		399,553		—		(399,553		)	—
Other liabilities	—		64,489		4,534		—			69,023
Total long-term liabilities	2,751,147		810,180		849,133		(2,294,180		)	2,116,280
Equity:
Equity - Western	1,219,234		3,235,487		359,726		(3,595,213		)	1,219,234
Equity - Non-controlling interest	—		—		1,631,566		—			1,631,566
Total equity	1,219,234		3,235,487		1,991,292		(3,595,213		)	2,850,800
Total liabilities and equity	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762

CONDENSED CONSOLIDATING BALANCE SHEETS

As of December 31, 2015

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	656,966	$	115,515	$	—		$	772,502
Accounts receivable, trade, net of a reserve for doubtful accounts	—		122,593		236,644		—			359,237
Accounts receivable, affiliate	—		55,550		3,505		(59,055		)	—
Inventories	—		311,589		235,949		—			547,538
Prepaid expenses	—		55,699		17,514		—			73,213
Other current assets	—		135,139		34,589		—			169,728
Total current assets	21		1,337,536		643,716		(59,055		)	1,922,218
Restricted cash	—		69,106		—		—			69,106
Equity method investment	—		—		97,513		—			97,513
Property, plant and equipment, net	—		1,099,787		1,205,384		—			2,305,171
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,401		53,544		—			84,945
Investment in subsidiaries	3,964,578		—		—		(3,964,578		)	—
Due from affiliate	—		1,797,047		—		(1,797,047		)	—
Other assets, net	—		42,166		22,831		—			64,997
Total assets	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	—	$	262,550	$	291,407	$	—		$	553,957
Accounts payable, affiliate	920		—		58,135		(59,055		)	—
Accrued liabilities	5,508		142,257		100,630		—			248,395
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	11,928		404,807		450,172		(59,055		)	807,852
Long-term liabilities:
Long-term debt, less current portion	856,327		—		788,567		—			1,644,894
Due to affiliate	1,797,047		—		—		(1,797,047		)	—
Lease financing obligation	—		42,168		11,064		—			53,232
Deferred income tax liability, net	—		275,634		37,280		—			312,914
Deficit in subsidiaries	—		395,774		—		(395,774		)	—
Other liabilities	—		63,674		4,921		—			68,595
Total long-term liabilities	2,653,374		777,250		841,832		(2,192,821		)	2,079,635
Equity:
Equity - Western	1,299,297		3,194,986		373,818		(3,568,804		)	1,299,297
Equity - Non-controlling interest	—		—		1,646,609		—			1,646,609
Total equity	1,299,297		3,194,986		2,020,427		(3,568,804		)	2,945,906
Total liabilities and equity	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,004,540		$	965,512		$	(514,548	)	$	1,455,504
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			798,548			763,361			(514,548		)	1,047,361
Direct operating expenses (exclusive of depreciation and amortization)	—			106,540			117,045			—			223,585
Selling, general and administrative expenses	46			24,695			28,544			—			53,285
Gain on disposal of assets, net	—			(26		)	(104		)	—			(130		)
Maintenance turnaround expense	—			125			—			—			125
Depreciation and amortization	—			25,538			27,113			—			52,651
Total operating costs and expenses	46			955,420			935,959			(514,548		)	1,376,877
Operating income (loss)	(46		)	49,120			29,553			—			78,627
Other income (expense):
Equity in earnings of subsidiaries	43,725			9,304			—			(53,029		)	—
Interest income	—			114			50			—			164
Interest and debt expense	(13,141		)	(738		)	(12,802		)	—			(26,681		)
Other, net	—			1,069			5,035			—			6,104
Income before income taxes	30,538			58,869			21,836			(53,029		)	58,214
Provision for income taxes	—			(18,368		)	(261		)	—			(18,629		)
Net income	30,538			40,501			21,575			(53,029		)	39,585
Less net income attributable to non-controlling interests	—			—			9,047			—			9,047
Net income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538
Comprehensive income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,783,100		$	1,305,172		$	(769,542	)	$	2,318,730
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			1,488,688			1,022,164			(769,542		)	1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	—			109,235			106,076			—			215,311
Selling, general and administrative expenses	47			29,530			26,226			—			55,803
Loss (gain) on disposal of assets, net	—			381			(99		)	—			282
Maintenance turnaround expense	—			105			—			—			105
Depreciation and amortization	—			24,669			25,257			—			49,926
Total operating costs and expenses	47			1,652,608			1,179,624			(769,542		)	2,062,737
Operating income (loss)	(47		)	130,492			125,548			—			255,993
Other income (expense):
Equity in earnings of subsidiaries	119,759			8,228			—			(127,987		)	—
Interest income	—			97			66			—			163
Interest and debt expense	(13,723		)	(507		)	(10,727		)	—			(24,957		)
Other, net	—			45			3,161			—			3,206
Income before income taxes	105,989			138,355			118,048			(127,987		)	234,405
Provision for income taxes	—			(59,234		)	(203		)	—			(59,437		)
Net income	105,989			79,121			117,845			(127,987		)	174,968
Less net income attributable to non-controlling interests	—			—			68,979			—			68,979
Net income attributable to Western Refining, Inc.	$	105,989		$	79,121		$	48,866		$	(127,987	)	$	105,989
Comprehensive income attributable to Western Refining, Inc.	$	105,989		$	79,129		$	48,866		$	(127,987	)	$	105,997

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	4,786		$	(21,284	)	$	30,994		$	(13,392	)	$	1,104
Cash flows from investing activities:
Capital expenditures	—			(44,798		)	(34,231		)	—			(79,029		)
Return of capital from equity method investment	13,537			—			—			(13,537		)	—
Use of restricted cash	—			32,323			—			—			32,323
Contributions to affiliate	—			(93,653		)	—			93,653			—
Proceeds from the sale of assets	—			100			119			—			219
Net cash provided by (used in) investing activities	13,537			(106,028		)	(34,112		)	80,116			(46,487		)
Cash flows from financing activities:
Payments on long-term debt and capital lease obligations	(1,375		)	(194		)	(353		)	—			(1,922		)
Borrowings on revolving credit facility	—			—			70,000			—			70,000
Repayments on revolving credit facility	—			—			(62,500		)	—			(62,500		)
Distribution to affiliate	—			—			(26,929		)	26,929			—
Purchases of common stock for treasury	(75,000		)	—			—			—			(75,000		)
Distribution to non-controlling interest holders	—			—			(28,995		)	—			(28,995		)
Dividends paid	(35,601		)	—			—			—			(35,601		)
Contributions from affiliates	93,653			—			—			(93,653		)	—
Net cash used in financing activities	(18,323		)	(194		)	(48,777		)	(66,724		)	(134,018		)
Net decrease in cash and cash equivalents	—			(127,506		)	(51,895		)	—			(179,401		)
Cash and cash equivalents at beginning of year	21			656,966			115,515			—			772,502
Cash and cash equivalents at end of year	$	21		$	529,460		$	63,620		$	—		$	593,101

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	12,172		$	4,907		$	115,668		$	(27,769	)	$	104,978
Cash flows from investing activities:
Capital expenditures	—			(20,526		)	(33,317		)	648			(53,195		)
Use of restricted cash	—			43,400			—			—			43,400
Contributions to affiliate	—			(61,636		)	—			61,636			—
Proceeds from the sale of assets	—			1,093			179			(648		)	624
Net cash provided by (used in) investing activities	—			(37,669		)	(33,138		)	61,636			(9,171		)
Cash flows from financing activities:
Additions to long-term debt	—			—			300,000			—			300,000
Payments on long-term debt and capital lease obligations	(1,375		)	—			—			—			(1,375		)
Repayments on revolving credit facility	—			—			(269,000		)	—			(269,000		)
Distribution to affiliate	—			—			(27,769		)	27,769			—
Deferred financing costs	—			—			(6,551		)	—			(6,551		)
Purchases of common stock for treasury	(25,000		)	—			—			—			(25,000		)
Distribution to non-controlling interest holders	—			—			(33,665		)	—			(33,665		)
Dividends paid	(28,638		)	—			—			—			(28,638		)
Contributions from affiliates	42,841			—			18,795			(61,636		)	—
Excess tax benefit from stock-based compensation	—			337			—			—			337
Net cash provided by (used in) financing activities	(12,172		)	337			(18,190		)	(33,867		)	(63,892		)
Net increase (decrease) in cash and cash equivalents	—			(32,425		)	64,340			—			31,915
Cash and cash equivalents at beginning of year	21			288,986			142,152			—			431,159
Cash and cash equivalents at end of year	$	21		$	256,561		$	206,492		$	—		$	463,074

NTI (Notes)	3 Months Ended
NTI (Notes)	Mar. 31, 2016
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	21. NTI On December 21, 2015, Western entered into the Merger Agreement, by and among Western, MergerCo, NTI and Northern Tier Energy GP LLC, the general partner of NTI and a wholly-owned subsidiary of Western (“NTI GP”). Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo will merge with and into NTI, the separate limited liability company existence of MergerCo will cease and NTI will continue to exist, as a limited partnership under Delaware law and as an indirect wholly-owned subsidiary of Western, as the surviving entity in the Merger. NT InterHoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("NT InterHoldCo"), owns 100% of the membership interests in NTI GP and 38.3% of NTI’s outstanding common units representing limited partner interests in NTI (“NTI Common Units”). NT InterHoldCo also owns 100% of the membership interests in Western Acquisition Holdings, LLC, a Delaware limited liability company and holder of 100% of the membership interests in MergerCo (“MergerCo HoldCo”). Following the Merger, NTI GP will remain the sole general partner of NTI, the NTI Common Units held by Western and its subsidiaries will be unchanged and remain issued and outstanding, and, by virtue of the Merger, all of the membership interests in MergerCo will automatically be converted into the number of NTI Common Units (excluding any NTI Common Units owned by Western and its subsidiaries) issued and outstanding immediately prior to the effective time of the Merger (the “Effective Time”). Consequently, NT InterHoldCo and its wholly-owned subsidiary, MergerCo HoldCo, will become the sole limited partners of NTI. At the Effective Time, each of the outstanding NTI Common Units held by the NTI Public Unitholders will be converted into the right to receive, subject to election by the NTI Public Unitholders and proration, (i) $15.00 in cash without interest and 0.2986 of a share of Western Common Stock (the “Standard Mix of Consideration”), (ii) $26.06 in cash without interest (the “Cash Election”), or (iii) 0.7036 of a share of Western Common Stock (the “Stock Election”). The Cash and Stock Elections will be subject to proration to ensure that the total amount of cash paid and the total number of shares of Western Common Stock issued and delivered (which may include shares of Western Common Stock held in treasury by Western and reissued) in the Merger to NTI Public Unitholders as a whole are equal to the total amount of cash and number of shares of Western Common Stock that would have been paid and issued if all NTI Public Unitholders received the Standard Mix of Consideration. The transaction is expected to result in the payment and delivery of $862.3 million in cash and 17.2 million shares of Western Common Stock to the NTI Public Unitholders. The parties anticipate that the Merger will close in the second quarter of 2016, pending the satisfaction of certain customary conditions thereto. Pursuant to the terms of the Merger Agreement, with respect to the Closing Date, NTI will, to the extent it generates available cash in such quarter, make a prorated quarterly cash distribution to all NTI common unitholders, including NT InterHoldCo, for the portion of the quarter that NTI Public Unitholders own NTI Common Units prior to the Closing Date, in the event that NTI Public Unitholders who receive Western Common Stock in the Merger would not receive a dividend with respect to the Western Common Stock received in the Merger, due to the record date for such dividend occurring before the Closing Date. Any prorated quarterly distribution for the quarter in which the Closing Date occurs would be paid to NTI Public Unitholders as of the Effective Time for the Merger, together with the merger consideration payable with respect to the Merger. The Merger Agreement contains customary representations, warranties, covenants and agreements by each of the parties. Completion of the Merger is conditioned upon, among other things: (1) approval of the Merger Agreement and the transactions contemplated by the Merger Agreement, including the Merger (the “Merger Transactions”), by the affirmative vote of NTI common unitholders, as of the record date for the NTI special meeting, holding a majority of the outstanding NTI Common Units; (2) any waiting period applicable to the Merger Transactions under the Hart-Scott-Rodino Antitrust Act of 1976, as amended (the “HSR Act”) having been terminated or expired; (3) all filings, consents, approvals, permits and authorizations required to be made or obtained prior to the Effective Time in connection with the Merger Transactions having been made or obtained; (4) the absence of legal injunctions or impediments prohibiting the Merger Transactions; (5) the effectiveness of a registration statement on Form S-4 (the “Registration Statement”) with respect to the issuance of new shares of Western Common Stock in the Merger; and (6) approval of the listing on the New York Stock Exchange, subject to official notice of issuance, of the new shares of Western Common Stock to be issued and delivered (or, to the extent held in treasury by Western, delivered but not issued) in the Merger. On January 29, 2016, the United States Federal Trade Commission granted early termination of the waiting periods applicable to the Merger Transactions under the HSR Act. Pursuant to the Merger Agreement, Western has agreed to vote the NTI common units owned beneficially or of record by it or any of its subsidiaries in favor of the adoption and approval of the Merger Agreement and the Merger Transactions. The Board of Directors of Western has approved the Merger Agreement and the Merger Transactions. The NTI GP Conflicts Committee, acting for NTI GP in its capacity as the general partner of NTI, approved the Merger Agreement and the Merger Transactions, and determined that the Merger Agreement and the Merger Transactions are fair and reasonable to NTI and the holders of NTI Common Units other than NTI GP and its affiliates (the “NTI Unaffiliated Unitholders”) and are not adverse to the interests of NTI or the interests of the NTI Unaffiliated Unitholders. On January 19, 2016, Western filed a preliminary registration statement on Form S-4 (the “Preliminary S-4”) to register the shares of Western Common Stock to be issued and delivered (or, to the extent held in treasury by Western, delivered but not issued) in the Merger. Western filed two subsequent amendments to the Preliminary S-4 on March 18 and April 19, 2016, in response to review and comments by the Securities and Exchange Commission (the “SEC”). On each respective filing date, the parties to the Merger Agreement jointly filed a transaction statement on Schedule 13E-3 ("Schedule 13-E") that discloses the material terms of the Merger Transactions. Both the preliminary S-4 and the Schedule 13-E are currently under review by the SEC and are subject to future amendments.

WNRL (Notes)	3 Months Ended
WNRL (Notes)	Mar. 31, 2016
Variable Interest Entity, Measure of Activity [Abstract]
Variable Interest Entity Disclosure [Text Block]	22. WNRL WNRL is a publicly held master limited partnership that owns and operates logistic assets that consist of pipeline and gathering, terminalling, storage and transportation assets, providing related services to our refining segment in the Southwest, including 685 miles of pipelines and 8.2 million barrels of active storage capacity. The majority of WNRL's logistics assets are integral to the operations of the El Paso and Gallup refineries. WNRL also owns a wholesale business that operates primarily in the Southwest. WNRL's wholesale business includes the operations of several lubricant and bulk petroleum distribution plants and a fleet of crude oil, refined product and lubricant delivery trucks. WNRL distributes commercial wholesale petroleum products primarily in Arizona, California, Colorado, Nevada, New Mexico and Texas. WNRL purchases petroleum fuels and lubricants from our refining segment and from third-party suppliers. As of March 31, 2016, we owned a 66.4% interest in WNRL and a 100% general partner interest. As the general partner of WNRL, we have the sole ability to direct the activities that most significantly impact WNRL's financial performance, and therefore we consolidate WNRL. We are WNRL’s primary logistics customer and a significant wholesale customer through our retail business. WNRL generates revenues by charging tariffs for transporting petroleum products and crude oil though its pipelines, by charging fees for terminalling refined products and other hydrocarbons, and storing and providing other services at its storage tanks and terminals. Additionally, WNRL sells various finished petroleum products to us and other third party customers. Under our long-term agreements with WNRL (discussed below), we accounted for 31.9% and 29.3% of WNRL’s total revenues for the three month periods ended March 31, 2016 and 2015, respectively. We do not provide financial or equity support through any liquidity arrangements and/or debt guarantees to WNRL. WNRL has outstanding debt under a senior secured revolving credit facility and its senior notes. Excluding assets held by WNRL, WNRL’s creditors have no recourse to our assets. Any recourse to WNRL’s general partner would be limited to the extent of Western Refining Logistics GP LLC.’s assets that other than its investment in WNRL, are not significant. Our creditors have no recourse to the assets of WNRL and its consolidated subsidiaries. WNRL provides us with various pipeline transportation, terminal distribution and storage services under long-term, fee-based commercial agreements expiring in 2023. These agreements contain minimum volume commitments. Each agreement has fees that are indexed for inflation and provides us with options to renew for two additional five-year terms. In addition to commercial agreements, we are also party to an omnibus agreement with WNRL that among other things provides for reimbursement to us for various general and administrative services provided to WNRL. We are also party to an operational services agreement with WNRL, under which we are reimbursed for personnel services provided by Western in support of WNRL's operations of its pipelines, terminals and storage facilities. WNRL has risk associated with its operations. If a major customer of WNRL were to terminate its contracts or fail to meet desired shipping or throughput levels for an extended period of time, revenue would be reduced and WNRL could suffer substantial losses to the extent that a new customer is not found. In the event that WNRL incurs a loss, our operating results will reflect WNRL’s loss, net of intercompany eliminations, to the extent of our ownership interest in WNRL at that point in time.

Basis of Presentation and Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidation, Policy [Policy Text Block]	Principles of Consolidation The accompanying condensed consolidated financial statements include the accounts of Western and our subsidiaries. We own a 38.3% limited partner interest in NTI and a 66.4% limited partner interest in WNRL. We own 100% of NTI's and WNRL's respective general partners. As the general partner of NTI and WNRL, we have the ability to direct the activities of NTI and WNRL that most significantly impact their respective economic performance. We have reported non-controlling interests for NTI and WNRL of $1,631.6 million and $1,646.6 million in our Condensed Consolidated Balance Sheets as of March 31, 2016 and December 31, 2015, respectively.
Consolidation, Variable Interest Entity, Policy [Policy Text Block]	Variable Interest Entity WNRL is a variable interest entity ("VIE") as defined under GAAP. A VIE is a legal entity whose equity owners do not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support or, as a group, the equity holders lack the power, through voting rights, to direct the activities that most significantly impact the entity's financial performance, the obligation to absorb the entity's expected losses or rights to expected residual returns. As the general partner of WNRL, we have the sole ability to direct the activities of WNRL that most significantly impact WNRL's financial performance, and therefore we consolidate WNRL. See Note 22, WNRL, for further discussion.
Goodwill and Intangible Assets, Policy [Policy Text Block]	Goodwill and Other Unamortizable Intangible Assets Goodwill represents the excess of the purchase price (cost) over the fair value of the net assets acquired and is carried at cost. We do not amortize goodwill for financial reporting purposes. We test goodwill for impairment at the reporting unit level. The reporting unit or units used to evaluate and measure goodwill for impairment are determined primarily from the manner in which the business is managed. Our policy is to test goodwill and other unamortizable intangible assets for impairment annually at June 30, or more frequently if indications of impairment exist.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates and Seasonality The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Demand for gasoline is generally higher during the summer months than during the winter months. As a result, our operating results for the first and fourth calendar quarters are generally lower than those for the second and third calendar quarters of each year. During 2014 and continuing into 2015, the volatility in crude oil prices and refining margins contributed to the variability of our results of operations.
Inventory, Policy [Policy Text Block]	We value our refinery inventories of crude oil, other raw materials and asphalt at the lower of cost or market under the LIFO valuation method. Other than refined products inventories held by WNRL and our retail segment, refined products inventories are valued under the LIFO valuation method. WNRL's wholesale refined product, lubricants and related inventories are valued using the FIFO inventory valuation method. Retail refined product inventory is valued using the FIFO inventory valuation method. Retail merchandise inventory is valued using the retail inventory method.

Segment Information (Tables)

3 Months Ended

Mar. 31, 2016

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment [Table Text Block]

Disclosures regarding our reportable segments with reconciliations to consolidated totals for the three months ended March 31, 2016 and 2015 are presented below:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Operating Results:
Refining (2)
Net sales	$	886,320		$	1,491,441
Intersegment eliminations	467,807			542,542
Net refining sales to external customers	418,513			948,899
NTI
Net sales	497,473			697,776
Intersegment eliminations	8,696			12,990
Net NTI sales to external customers	488,777			684,786
WNRL (2)
Net sales	468,039			607,396
Intersegment eliminations	149,462			178,249
Net WNRL sales to external customers	318,577			429,147
Retail
Net sales	231,186			258,602
Intersegment eliminations	1,549			2,704
Net retail sales to external customers	229,637			255,898

Consolidated net sales to external customers	$	1,455,504		$	2,318,730

Operating income (loss)
Refining (1) (2)	$	62,138		$	148,612
NTI (1)	8,115			107,987
WNRL (2)	21,438			17,561
Retail	2,432			(441		)
Other	(15,496		)	(17,726		)
Operating income from segments	78,627			255,993
Other income (expense), net	(20,413		)	(21,588		)
Consolidated income before income taxes	$	58,214		$	234,405



	Three Months Ended
	March 31,
	2016		2015
Depreciation and amortization
Refining (2)	$	21,285	$	20,484
NTI	19,969		19,365
WNRL (2)	7,144		5,892
Retail	3,330		3,286
Other	923		899
Consolidated depreciation and amortization	$	52,651	$	49,926

Capital expenditures
Refining (2)	$	43,563	$	17,826
NTI	27,990		6,673
WNRL (2)	6,241		25,996
Retail	637		1,402
Other	598		1,298
Consolidated capital expenditures	$	79,029	$	53,195

Total assets
Refining (2)	$	1,620,113	$	1,606,073
NTI (including $1,289,443 of goodwill)	2,328,446		2,258,695
WNRL (2)	448,218		495,028
Retail	239,359		249,318
Other	1,117,626		1,075,408
Consolidated total assets	$	5,753,762	$	5,684,522

(1)

(2)

Fair Value Measurement (Tables)

3 Months Ended

Mar. 31, 2016

Fair Value Disclosures [Abstract]

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis, Valuation Techniques [Table Text Block]



	Carrying Value at March 31, 2016			Fair Value Measurement Using								Netting Adjustments			Recorded Value at March 31, 2016
	Carrying Value at March 31, 2016			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at March 31, 2016
	(In thousands)
Gross financial assets:
Other current assets	$	86,144		$	—	$	86,144		$	—		$	(19,080	)	$	67,064
Other assets	8,019			—		8,019			—			(867		)	7,152
Gross financial liabilities:
Accrued liabilities	(12,647		)	—		(8,689		)	(3,958		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	—		(14,437		)	—			14,437			—
	$	67,079		$	—	$	71,037		$	(3,958	)	$	—		$	67,079



	Carrying Value at December 31, 2015			Fair Value Measurement Using								Netting Adjustments			Recorded Value at December 31, 2015
	Carrying Value at December 31, 2015			Level 1		Level 2			Level 3			Netting Adjustments			Recorded Value at December 31, 2015
	(In thousands)
Gross financial assets:
Other current assets	$	95,062		$	—	$	95,062		$	—		$	(16,937	)	$	78,125
Other assets	11,881			—		11,881			—			—			11,881
Gross financial liabilities:
Accrued liabilities	(21,454		)	—		(15,698		)	(5,756		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	—		(5,756		)	—			5,756			—
	$	79,733		$	—	$	85,489		$	(5,756	)	$	—		$	79,733

Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Asset (liability) balance at beginning of period	$	(5,756	)	$	330
Change in fair value	186			—
Fair value of trades entered into during the period	—			1,462
Fair value reclassification from Level 3 to Level 2	1,612			(82		)
Asset (liability) balance at end of period	$	(3,958	)	$	1,710

A hypothetical change of 10% to the estimated future cash flows attributable to our Level 3 commodity price swaps would result in a $0.4 million change in the estimated fair value at March 31, 2016.

Fair Value, by Balance Sheet Grouping [Table Text Block]

As of March 31, 2016 and December 31, 2015, the carrying amount and estimated fair value of our debt was as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Western obligations:
Carrying amount	$	887,625	$	889,000
Fair value	838,373		867,178
NTI obligations:
Carrying amount	$	372,500	$	350,000
Fair value	367,250		360,500
WNRL obligations:
Carrying amount	$	430,000	$	445,000
Fair value	400,000		439,000

Inventories (Tables)

3 Months Ended

Mar. 31, 2016

Inventory Disclosure [Abstract]

Schedule of Inventory, Current [Table Text Block]

Inventories were as follows:



	March 31, 2016		December 31, 2015
	(In thousands)
Refined products (1)	$	267,861	$	201,928
Crude oil and other raw materials	362,415		288,403
Lubricants	12,356		14,996
Retail store merchandise	40,961		42,211
Inventories	$	683,593	$	547,538


(1)	Includes $15.0 million and $14.5 million of inventory valued using the first-in, first-out ("FIFO") valuation method at March 31, 2016 and December 31, 2015, respectively.

Average LIFO cost per barrel of our refined products and crude oil and other raw materials inventories as of March 31, 2016 and December 31, 2015, were as follows:



	March 31, 2016					December 31, 2015
	Barrels	LIFO Cost		Average LIFO Cost Per Barrel		Barrels	LIFO Cost		Average LIFO Cost Per Barrel
	(In thousands, except cost per barrel)
Refined products	5,130	$	314,934	$	61.39	3,536	$	259,722	$	73.45
Crude oil and other	7,462	423,694		56.78		6,490	391,237		60.28
	12,592	$	738,628	58.66		10,026	$	650,959	64.93

Property, Plant and Equipment, Net (Tables)

3 Months Ended

Mar. 31, 2016

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment [Table Text Block]

Property, plant and equipment, net was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Refinery facilities and related equipment	$	2,390,745		$	2,348,663
Pipelines, terminals and transportation equipment	559,040			533,040
Retail facilities and related equipment	329,808			328,419
Wholesale facilities and related equipment	61,369			61,133
Corporate	51,451			50,812
	3,392,413			3,322,067
Accumulated depreciation	(1,067,822		)	(1,016,896		)
Property, plant and equipment, net	$	2,324,591		$	2,305,171

Intangible Assets, Net (Tables)

3 Months Ended

Mar. 31, 2016

Intangible Assets, Net (Excluding Goodwill) [Abstract]

Schedule of Intangible Assets and Goodwill [Table Text Block]

Intangible assets, net was as follows:



	March 31, 2016							December 31, 2015							Weighted- Average Amortization Period (Years)
	Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Weighted- Average Amortization Period (Years)
	(In thousands)
Amortizable assets:
Licenses and permits	$	20,427	$	(14,124	)	$	6,303	$	20,427	$	(13,729	)	$	6,698	4.0
Customer relationships	7,551		(4,060		)	3,491		7,551		(3,921		)	3,630		6.3
Rights-of-way and other	7,905		(1,999		)	5,906		6,839		(1,797		)	5,042		8.6
	35,883		(20,183		)	15,700		34,817		(19,447		)	15,370
Unamortizable assets:
Franchise rights and trademarks	50,500		—			50,500		50,500		—			50,500
Liquor licenses	19,075		—			19,075		19,075		—			19,075
Intangible assets, net	$	105,458	$	(20,183	)	$	85,275	$	104,392	$	(19,447	)	$	84,945

Schedule of Expected Amortization Expense [Table Text Block]

Estimated amortization expense for the indicated periods is as follows (in thousands):



Remainder of 2016	$	2,204
2017	2,906
2018	2,905
2019	2,237
2020	1,292
2021	1,006

Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2016

Debt Disclosure [Abstract]

Schedule of Debt [Table Text Block]

Long-term debt was as follows:



	March 31, 2016			December 31, 2015
	(In thousands)
Western obligations:
Revolving Credit Facility due 2019	$	—		$	—
Term Loan Credit Facility due 2020	537,625			539,000
6.25% Senior Unsecured Notes due 2021	350,000			350,000
Total Western obligations	887,625			889,000
NTI obligations:
Revolving Credit Facility due 2019	22,500			—
7.125% Senior Secured Notes due 2020	350,000			350,000
Total NTI obligations	372,500			350,000
WNRL obligations:
Revolving Credit Facility due 2018	130,000			145,000
7.5% Senior Notes due 2023	300,000			300,000
Total WNRL obligations	430,000			445,000
Less unamortized premium and debt issuance costs	32,033			33,606
Long-term debt	1,658,092			1,650,394
Current portion of long-term debt	(5,500		)	(5,500		)
Long-term debt, net of current portion	$	1,652,592		$	1,644,894

Interest and debt expense were as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Contractual interest:
Western obligations	$	12,052		$	12,007
NTI obligations	6,914			6,591
WNRL obligations	6,705			3,726
	25,671			22,324
Amortization of loan fees	1,911			1,786
Other interest expense	(176		)	1,075
Capitalized interest	(725		)	(228		)
Interest and debt expense	$	26,681		$	24,957

Equity (Tables)

3 Months Ended

Mar. 31, 2016

Distribution Made to Limited Partner [Line Items]

Schedule of Stockholders Equity [Table Text Block]

Changes to equity during the three months ended March 31, 2016, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2015	$	1,299,297		$	1,646,609		$	2,945,906
Net income	30,538			9,047			39,585
Dividends	(35,601		)	—			(35,601		)
Stock-based compensation	328			4,657			4,985
Tax deficiency from stock-based compensation	(328		)	—			(328		)
Distributions to non-controlling interests	—			(28,747		)	(28,747		)
Treasury stock purchases	(75,000		)	—			(75,000		)
Balance at March 31, 2016	$	1,219,234		$	1,631,566		$	2,850,800

Changes to equity during the three months ended March 31, 2015, were as follows:



	Western Shareholders' Equity			Non-controlling Interest			Total Equity
	(In thousands)
Balance at December 31, 2014	$	1,119,708		$	1,667,936		$	2,787,644
Net income	105,989			68,979			174,968
Other comprehensive income, net of tax	8			—			8
Dividends	(28,638		)	—			(28,638		)
Stock-based compensation	1,001			2,503			3,504
Excess tax benefit from stock-based compensation	337			—			337
Distributions to non-controlling interests	—			(33,665		)	(33,665		)
Treasury stock purchases	(25,000		)	—			(25,000		)
Balance at March 31, 2015	$	1,173,405		$	1,705,753		$	2,879,158

Class of Treasury Stock [Table Text Block]

The following table summarizes our share repurchase activity for the September 2015 Program:



	Number of shares purchased	Cost of share purchases (In thousands)
Shares purchased at December 31, 2015	—	$	—
Shares purchased during Q1, 2016	2,462,350	75,000
Shares purchased at March 31, 2016	2,462,350	$	75,000

Dividends Declared [Table Text Block]

The table below summarizes our 2016 cash dividend declarations, payments and scheduled payments:

Declaration Date

Record Date

Payment Date

Dividend per Common Share

Total Payment

(In thousands)

First quarter

January 6

January 20

February 4

0.38

35,601

Second quarter (1)

April 8

April 18

May 2

0.38

—

Total

35,601

(1) The second quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $34.7 million.

Northern Tier Energy LP [Member]

Distribution Made to Limited Partner [Line Items]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

The table below summarizes NTI's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Unit
February 3, 2016	February 12, 2016	February 19, 2016	$	0.38
Total			$	0.38

Western Refining Logistics, LP [Member]

Distribution Made to Limited Partner [Line Items]

Distributions Made to Limited Partner, by Distribution [Table Text Block]

The table below summarizes WNRL's 2016 quarterly distribution declarations, payments and scheduled payments:



Declaration Date	Record Date	Payment Date	Distribution per Common and Subordinated Unit
February 1, 2016	February 11, 2016	February 26, 2016	$	0.3925
April 25, 2016	May 13, 2016	May 27, 2016	0.4025
Total			$	0.7950

Retirement Plans (Tables)

3 Months Ended

Mar. 31, 2016

Compensation and Retirement Disclosure [Abstract]

Schedule of Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Beginning of period balance	$	651	$	(1,291	)
Reclassification of loss to income	—		13
Income tax	—		(5		)
End of period balance	$	651	$	(1,283	)

Crude Oil and Refined Product Risk Management (Tables)

3 Months Ended

Mar. 31, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments, Gain (Loss) [Table Text Block]



	Three Months Ended
	March 31,
	2016			2015
	(In thousands)
Economic hedging results
Realized hedging gain, net	$	17,803		$	17,553
Unrealized hedging loss, net	(12,483		)	(20,057		)
Total hedging gain (loss), net	$	5,320		$	(2,504	)



	March 31, 2016			December 31, 2015
	(In thousands)
Open commodity hedging instruments (barrels)
Crude oil differential swaps, net long positions	7,201			5,155
Crude oil futures, net short positions	(1,823		)	(562		)
Refined product price and crack spread swaps, net short positions	(2,900		)	(5,645		)
Total open commodity hedging instruments, net long (short) positions	2,478			(1,052		)

Fair value of outstanding contracts, net
Other current assets	$	67,064		$	78,125
Other assets	7,152			11,881
Accrued liabilities	(7,137		)	(10,273		)
Other long-term liabilities	—			—
Fair value of outstanding contracts - unrealized gain, net	$	67,079		$	79,733

Offsetting Assets [Table Text Block]

The following table presents offsetting information regarding Western's commodity hedging contracts as of March 31, 2016 and December 31, 2015:



	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of March 31, 2016	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	86,144		$	(19,080	)	$	67,064
Other assets	8,019			(867		)	7,152
Financial liabilities:
Accrued liabilities	(12,647		)	5,510			(7,137		)
Other long-term liabilities	(14,437		)	14,437			—
	$	67,079		$	—		$	67,079



	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Condensed Consolidated Balance Sheet			Net Amounts of Assets (Liabilities) Presented in the Condensed Consolidated Balance Sheet
As of December 31, 2015	Gross Amounts of Recognized Assets (Liabilities)
	(In thousands)
Financial assets:
Current assets	$	95,062		$	(16,937	)	$	78,125
Other assets	11,881			—			11,881
Financial liabilities:
Accrued liabilities	(21,454		)	11,181			(10,273		)
Other long-term liabilities	(5,756		)	5,756			—
	$	79,733		$	—		$	79,733

Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block]

The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels):



	Notional Contract Volumes by Year of Maturity
	2016		2017		2018
Inventory positions (futures and swaps):
Crude oil differential swaps, net long positions	5,283		1,918		—
Crude oil futures, net short positions	(1,823	)	—		—
Refined products — net short positions	(999	)	—		—
Natural gas futures — net long positions	720		329		—
Refined product positions (crack spread swaps):
Distillate — net short positions	(744	)	(1,305	)	—
Unleaded gasoline — net short positions	(900	)	—		—

Stock-Based Compensation (Tables)

3 Months Ended

Mar. 31, 2016

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]

March 31, 2016, are presented below:



	2016 Awards		2015 Awards
Expected volatility	29.80	%	34.10	%
Risk-free interest rate	1.08	%	0.84	%

Incentive Plans of Western Refining, Inc. [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

The following table summarizes our RSU activity for the three months ended March 31, 2016:



	Number of Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	399,214		$	37.43
Awards granted	339,618		29.60
Awards vested	(79,118	)	40.71
Awards forfeited	(3,424	)	43.81
Not vested at March 31, 2016	656,290		32.95

WNRL 2013 LTIP [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

A summary of WNRL's common and phantom unit award activity for the three months ended March 31, 2016, is set forth below:



	Number of Phantom Units		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	279,787		$	28.06
Awards granted	75,919		22.53
Awards vested	(60,705	)	26.80
Awards forfeited	—		—
Not vested at March 31, 2016	295,001		26.64

NTI 2012 LTIP [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]

A summary of the NTI LTIP common unit activity for the three months ended March 31, 2016, is set forth below:



	Restricted Units				Phantom Units
	Restricted Units				Service-Based Units		Performance-Based Units		Total		Weighted Average Grant Date Fair Value
	Number of Units		Weighted Average Grant Date Fair Value		Number of Units		Number of Units		Total		Weighted Average Grant Date Fair Value
Not vested at December 31, 2015	191,424		$	24.75	581,882		260,690		842,572		$	24.00
Awards granted	—		—		381,029		163,571		544,600		30.27
Incremental performance units	—		—		—		231,777		231,777		38.17
Awards vested	(34,054	)	26.84		(235,546	)	(1,789	)	(237,335	)	24.05
Awards forfeited	—		—		(523	)	(1,463	)	(1,986	)	24.01
Not vested at March 31, 2016	157,370		24.30		726,842		652,786		1,379,628		28.90

Earnings per Share (Tables)

3 Months Ended

Mar. 31, 2016

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

The computation of basic and diluted earnings per share under the two-class method is presented as follows:



	Three Months Ended
	March 31,
	2016			2015
	(In thousands, except per share data)
Basic earnings per common share:
Allocation of earnings:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Distributed earnings	(35,601		)	(28,638		)
Undistributed income (loss) available to Western Refining, Inc.	$	(5,063	)	$	77,351
Weighted-average number of common shares outstanding	92,078			95,567
Basic earnings per common share:
Distributed earnings per share	$	0.39		$	0.30
Undistributed earnings (loss) per share	(0.05		)	0.81
Basic earnings per common share	$	0.34		$	1.11

Diluted earnings per common share:
Net income attributable to Western Refining, Inc.	$	30,538		$	105,989
Weighted-average diluted common shares outstanding	92,144			95,682
Diluted earnings per common share	$	0.33		$	1.11

Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]

The computation of the weighted average number of diluted shares outstanding is presented below:



	Three Months Ended
	March 31,
	2016	2015
	(In thousands)
Weighted-average number of common shares outstanding	92,078	95,567
Restricted share units	66	115
Weighted-average number of diluted shares outstanding	92,144	95,682

Cash Flows (Tables)

3 Months Ended

Mar. 31, 2016

Supplemental Cash Flow Elements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]

Supplemental Cash Flow Information

Supplemental disclosures of cash flow information were as follows:



	Three Months Ended
	March 31,
	2016		2015
	(In thousands)
Income taxes paid	$	11,215	$	40,009
Interest paid, excluding amounts capitalized	20,676		8,959

Non-cash investing and financing activities were as follows:
Assets acquired through capital lease obligations	$	328	$	19,511
Accrued capital expenditures	46,045		12,741
Distributions receivable from equity method investee	—		3,740
Distributions accrued on unvested NTI equity awards	3,964		—
Transfer of capital spares from fixed assets to other assets	699		—

Leases and Other Commitments (Tables)

3 Months Ended

Mar. 31, 2016

Leases [Abstract]

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]



	Operating		Capital
Remaining 2016	$	43,908	$	3,859
2017	52,828		5,060
2018	49,495		5,084
2019	44,407		5,195
2020	40,218		5,386
2021 and thereafter	340,046		70,941
Total minimum lease payments	$	570,902	95,525
Less amount that represents interest			43,476
Present value of net minimum capital lease payments			$	52,049

Condensed Consolidating Financial Information (Tables)

3 Months Ended

Mar. 31, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Condensed Balance Sheet [Table Text Block]

CONDENSED CONSOLIDATING BALANCE SHEETS

As of March 31, 2016

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	529,460	$	63,620	$	—		$	593,101
Accounts receivable, trade, net of a reserve for doubtful accounts	—		104,551		232,526		—			337,077
Accounts receivable, affiliate	3,007		66,012		2,544		(71,563		)	—
Inventories	—		419,692		263,901		—			683,593
Prepaid expenses	—		61,472		18,499		—			79,971
Other current assets	—		118,778		40,813		—			159,591
Total current assets	3,028		1,299,965		621,903		(71,563		)	1,853,333
Restricted cash	—		36,783		—		—			36,783
Equity method investment	—		—		102,971		—			102,971
Property, plant and equipment, net	—		1,106,879		1,217,712		—			2,324,591
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,923		53,352		—			85,275
Investment in subsidiaries	3,994,766		—		—		(3,994,766		)	—
Due from affiliate	—		1,894,627		—		(1,894,627		)	—
Other assets, net	—		37,975		23,391		—			61,366
Total assets	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	10,938	$	251,898	$	299,594	$	—		$	562,430
Accounts payable, affiliate	—		—		71,563		(71,563		)	—
Accrued liabilities	10,975		110,587		97,190		—			218,752
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	27,413		362,485		468,347		(71,563		)	786,682
Long-term liabilities:
Long-term debt, less current portion	856,520		—		796,072		—			1,652,592
Due to affiliate	1,894,627		—		—		(1,894,627		)	—
Lease financing obligation	—		41,943		11,247		—			53,190
Deferred income tax liability, net	—		304,195		37,280		—			341,475
Deficit in subsidiaries	—		399,553		—		(399,553		)	—
Other liabilities	—		64,489		4,534		—			69,023
Total long-term liabilities	2,751,147		810,180		849,133		(2,294,180		)	2,116,280
Equity:
Equity - Western	1,219,234		3,235,487		359,726		(3,595,213		)	1,219,234
Equity - Non-controlling interest	—		—		1,631,566		—			1,631,566
Total equity	1,219,234		3,235,487		1,991,292		(3,595,213		)	2,850,800
Total liabilities and equity	$	3,997,794	$	4,408,152	$	3,308,772	$	(5,960,956	)	$	5,753,762

CONDENSED CONSOLIDATING BALANCE SHEETS

As of December 31, 2015

(In thousands)



	Parent		Guarantor Subsidiaries		Non-Guarantors		Eliminations			Consolidated
ASSETS
Current assets:
Cash and cash equivalents	$	21	$	656,966	$	115,515	$	—		$	772,502
Accounts receivable, trade, net of a reserve for doubtful accounts	—		122,593		236,644		—			359,237
Accounts receivable, affiliate	—		55,550		3,505		(59,055		)	—
Inventories	—		311,589		235,949		—			547,538
Prepaid expenses	—		55,699		17,514		—			73,213
Other current assets	—		135,139		34,589		—			169,728
Total current assets	21		1,337,536		643,716		(59,055		)	1,922,218
Restricted cash	—		69,106		—		—			69,106
Equity method investment	—		—		97,513		—			97,513
Property, plant and equipment, net	—		1,099,787		1,205,384		—			2,305,171
Goodwill	—		—		1,289,443		—			1,289,443
Intangible assets, net	—		31,401		53,544		—			84,945
Investment in subsidiaries	3,964,578		—		—		(3,964,578		)	—
Due from affiliate	—		1,797,047		—		(1,797,047		)	—
Other assets, net	—		42,166		22,831		—			64,997
Total assets	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable, trade	$	—	$	262,550	$	291,407	$	—		$	553,957
Accounts payable, affiliate	920		—		58,135		(59,055		)	—
Accrued liabilities	5,508		142,257		100,630		—			248,395
Current portion of long-term debt	5,500		—		—		—			5,500
Total current liabilities	11,928		404,807		450,172		(59,055		)	807,852
Long-term liabilities:
Long-term debt, less current portion	856,327		—		788,567		—			1,644,894
Due to affiliate	1,797,047		—		—		(1,797,047		)	—
Lease financing obligation	—		42,168		11,064		—			53,232
Deferred income tax liability, net	—		275,634		37,280		—			312,914
Deficit in subsidiaries	—		395,774		—		(395,774		)	—
Other liabilities	—		63,674		4,921		—			68,595
Total long-term liabilities	2,653,374		777,250		841,832		(2,192,821		)	2,079,635
Equity:
Equity - Western	1,299,297		3,194,986		373,818		(3,568,804		)	1,299,297
Equity - Non-controlling interest	—		—		1,646,609		—			1,646,609
Total equity	1,299,297		3,194,986		2,020,427		(3,568,804		)	2,945,906
Total liabilities and equity	$	3,964,599	$	4,377,043	$	3,312,431	$	(5,820,680	)	$	5,833,393

Condensed Income Statement [Table Text Block]

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,004,540		$	965,512		$	(514,548	)	$	1,455,504
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			798,548			763,361			(514,548		)	1,047,361
Direct operating expenses (exclusive of depreciation and amortization)	—			106,540			117,045			—			223,585
Selling, general and administrative expenses	46			24,695			28,544			—			53,285
Gain on disposal of assets, net	—			(26		)	(104		)	—			(130		)
Maintenance turnaround expense	—			125			—			—			125
Depreciation and amortization	—			25,538			27,113			—			52,651
Total operating costs and expenses	46			955,420			935,959			(514,548		)	1,376,877
Operating income (loss)	(46		)	49,120			29,553			—			78,627
Other income (expense):
Equity in earnings of subsidiaries	43,725			9,304			—			(53,029		)	—
Interest income	—			114			50			—			164
Interest and debt expense	(13,141		)	(738		)	(12,802		)	—			(26,681		)
Other, net	—			1,069			5,035			—			6,104
Income before income taxes	30,538			58,869			21,836			(53,029		)	58,214
Provision for income taxes	—			(18,368		)	(261		)	—			(18,629		)
Net income	30,538			40,501			21,575			(53,029		)	39,585
Less net income attributable to non-controlling interests	—			—			9,047			—			9,047
Net income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538
Comprehensive income attributable to Western Refining, Inc.	$	30,538		$	40,501		$	12,528		$	(53,029	)	$	30,538

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Net sales	$	—		$	1,783,100		$	1,305,172		$	(769,542	)	$	2,318,730
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	—			1,488,688			1,022,164			(769,542		)	1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	—			109,235			106,076			—			215,311
Selling, general and administrative expenses	47			29,530			26,226			—			55,803
Loss (gain) on disposal of assets, net	—			381			(99		)	—			282
Maintenance turnaround expense	—			105			—			—			105
Depreciation and amortization	—			24,669			25,257			—			49,926
Total operating costs and expenses	47			1,652,608			1,179,624			(769,542		)	2,062,737
Operating income (loss)	(47		)	130,492			125,548			—			255,993
Other income (expense):
Equity in earnings of subsidiaries	119,759			8,228			—			(127,987		)	—
Interest income	—			97			66			—			163
Interest and debt expense	(13,723		)	(507		)	(10,727		)	—			(24,957		)
Other, net	—			45			3,161			—			3,206
Income before income taxes	105,989			138,355			118,048			(127,987		)	234,405
Provision for income taxes	—			(59,234		)	(203		)	—			(59,437		)
Net income	105,989			79,121			117,845			(127,987		)	174,968
Less net income attributable to non-controlling interests	—			—			68,979			—			68,979
Net income attributable to Western Refining, Inc.	$	105,989		$	79,121		$	48,866		$	(127,987	)	$	105,989
Comprehensive income attributable to Western Refining, Inc.	$	105,989		$	79,129		$	48,866		$	(127,987	)	$	105,997

Condensed Cash Flow Statement [Table Text Block]

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2016

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	4,786		$	(21,284	)	$	30,994		$	(13,392	)	$	1,104
Cash flows from investing activities:
Capital expenditures	—			(44,798		)	(34,231		)	—			(79,029		)
Return of capital from equity method investment	13,537			—			—			(13,537		)	—
Use of restricted cash	—			32,323			—			—			32,323
Contributions to affiliate	—			(93,653		)	—			93,653			—
Proceeds from the sale of assets	—			100			119			—			219
Net cash provided by (used in) investing activities	13,537			(106,028		)	(34,112		)	80,116			(46,487		)
Cash flows from financing activities:
Payments on long-term debt and capital lease obligations	(1,375		)	(194		)	(353		)	—			(1,922		)
Borrowings on revolving credit facility	—			—			70,000			—			70,000
Repayments on revolving credit facility	—			—			(62,500		)	—			(62,500		)
Distribution to affiliate	—			—			(26,929		)	26,929			—
Purchases of common stock for treasury	(75,000		)	—			—			—			(75,000		)
Distribution to non-controlling interest holders	—			—			(28,995		)	—			(28,995		)
Dividends paid	(35,601		)	—			—			—			(35,601		)
Contributions from affiliates	93,653			—			—			(93,653		)	—
Net cash used in financing activities	(18,323		)	(194		)	(48,777		)	(66,724		)	(134,018		)
Net decrease in cash and cash equivalents	—			(127,506		)	(51,895		)	—			(179,401		)
Cash and cash equivalents at beginning of year	21			656,966			115,515			—			772,502
Cash and cash equivalents at end of year	$	21		$	529,460		$	63,620		$	—		$	593,101

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

Three Months Ended March 31, 2015

(In thousands)



	Parent			Guarantor Subsidiaries			Non-Guarantors			Eliminations			Consolidated
Cash flows from operating activities:
Net cash provided by (used in) operating activities	$	12,172		$	4,907		$	115,668		$	(27,769	)	$	104,978
Cash flows from investing activities:
Capital expenditures	—			(20,526		)	(33,317		)	648			(53,195		)
Use of restricted cash	—			43,400			—			—			43,400
Contributions to affiliate	—			(61,636		)	—			61,636			—
Proceeds from the sale of assets	—			1,093			179			(648		)	624
Net cash provided by (used in) investing activities	—			(37,669		)	(33,138		)	61,636			(9,171		)
Cash flows from financing activities:
Additions to long-term debt	—			—			300,000			—			300,000
Payments on long-term debt and capital lease obligations	(1,375		)	—			—			—			(1,375		)
Repayments on revolving credit facility	—			—			(269,000		)	—			(269,000		)
Distribution to affiliate	—			—			(27,769		)	27,769			—
Deferred financing costs	—			—			(6,551		)	—			(6,551		)
Purchases of common stock for treasury	(25,000		)	—			—			—			(25,000		)
Distribution to non-controlling interest holders	—			—			(33,665		)	—			(33,665		)
Dividends paid	(28,638		)	—			—			—			(28,638		)
Contributions from affiliates	42,841			—			18,795			(61,636		)	—
Excess tax benefit from stock-based compensation	—			337			—			—			337
Net cash provided by (used in) financing activities	(12,172		)	337			(18,190		)	(33,867		)	(63,892		)
Net increase (decrease) in cash and cash equivalents	—			(32,425		)	64,340			—			31,915
Cash and cash equivalents at beginning of year	21			288,986			142,152			—			431,159
Cash and cash equivalents at end of year	$	21		$	256,561		$	206,492		$	—		$	463,074

Organization (Details) $ / shares in Units, shares in Millions	3 Months Ended
	Jun. 30, 2016 $ / shares shares	Mar. 31, 2016 operating_segments stores_stations refineries $ / shares	Dec. 31, 2015 USD ($) mi $ / shares bbl
Segment Reporting Information [Line Items]
Common Stock, Par or Stated Value Per Share \| $ / shares		$ 0.01	$ 0.01
Retail service stations and convenience stores \| stores_stations		541
Number of Reportable Segments \| operating_segments		4
Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries		3
Retail network [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries		2
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		66.40%
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Retail service stations and convenience stores \| stores_stations		283
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		38.30%
Northern Tier Energy GP LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		100.00%
Western Refining Logistics GP, LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		100.00%
El Paso Facility [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries		1
Gallup Facility [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries		1
St. Paul Park, Minnesota [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries		1
TexNew Mex 16 inch pipeline [Member] \| Pipelines [Member]
Segment Reporting Information [Line Items]
Pipeline, Miles \| mi			375
Franchised Units [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Retail service stations and convenience stores \| stores_stations		114
Public [Member] \| Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		33.60%
Public [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		61.70%
TexNew Mex 16 inch pipeline [Member]
Segment Reporting Information [Line Items]
Proceeds from Divestiture of Businesses \| $			$ 170,000,000
TexNew Mex 16 inch pipeline [Member] \| Crude Oil Storage Tanks [Member] \| Western Refining Logistics, LP [Member] \| Gas Gathering and Processing Equipment [Member]
Segment Reporting Information [Line Items]
Long-term Purchase Commitment, Minimum Volume Required \| bbl			80,000
Subsequent Event [Member] \| Minimum [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Cash payments to acquire business, per unit \| $ / shares	$ 15.00
Subsequent Event [Member] \| Maximum [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Cash payments to acquire business, per unit \| $ / shares	$ 26.06
Common Stock [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares \| shares	17.2
Common Stock [Member] \| Subsequent Event [Member] \| Minimum [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Payment of shares to acquire business, per unit \| $ / shares	$ 0.2986
Common Stock [Member] \| Subsequent Event [Member] \| Maximum [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Payment of shares to acquire business, per unit \| $ / shares	$ 0.7036
TexNew Mex Units [Member] \| TexNew Mex 16 inch pipeline [Member] \| Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable \| $			$ 80,000
Common Units [Member] \| TexNew Mex 16 inch pipeline [Member] \| Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable \| $			$ 421,031

Basis of Presentation and Significant Accounting Policies (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Non-controlling interests	$ 1,631,566	$ 1,646,609
Western Refining Logistics GP, LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	66.40%
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	38.30%
Northern Tier Energy GP LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%

Segment Information (Details) $ in Thousands	3 Months Ended
Segment Information (Details) $ in Thousands	Mar. 31, 2016 USD ($) operating_segments stores_stations refineries mi bbl	Mar. 31, 2015 USD ($) stores_stations	Dec. 31, 2015 USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments \| operating_segments	4
Derivative, Gain (Loss) on Derivative, Net	$ 5,320	$ (2,504)
Number of Stores \| stores_stations	541
Inventory, Change in Lower of Cost or Market Reserve	$ (51,700)	$ (15,700)
Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	3
Refining Group [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	2
Retail Group [Member]
Segment Reporting Information [Line Items]
Number of Stores \| stores_stations	258	261
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Pipeline, Miles \| mi	685
Active Storage Capacity \| bbl	8,200,000
Non-Staffed Fueling Locations [Member] \| Retail Group [Member]
Segment Reporting Information [Line Items]
Number of Stores \| stores_stations	52	50
Glencore Supply Agreement [Member] \| Refining Group [Member]
Segment Reporting Information [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 26,400	$ 21,500
Net Assets	$ 1,400		$ 1,800
El Paso Facility [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	1
El Paso Facility [Member] \| Refining Group [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	1
Active Storage Capacity \| bbl	131,000
Gallup Facility [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	1
Gallup Facility [Member] \| Refining Group [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	1
Active Storage Capacity \| bbl	25,000
St. Paul Park, Minnesota [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets \| refineries	1
St. Paul Park, Minnesota [Member] \| Northern Tier Energy LP [Member] \| Refining Equipment [Member]
Segment Reporting Information [Line Items]
Active Storage Capacity \| bbl	98,000
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Number of Stores \| stores_stations	283
Northern Tier Energy LP [Member] \| Wholly Owned Properties [Member]
Segment Reporting Information [Line Items]
Number of Stores \| stores_stations	169
Northern Tier Energy LP [Member] \| Franchised Units [Member]
Segment Reporting Information [Line Items]
Number of Stores \| stores_stations	114
Cost of Sales [Member] \| Operating Segments [Member] \| Refining Group [Member]
Segment Reporting Information [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 6,000	(3,700)
Inventory, Change in Lower of Cost or Market Reserve	(40,700)	(4,900)
Cost of Sales [Member] \| Operating Segments [Member] \| Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(700)	1,200
Inventory, Change in Lower of Cost or Market Reserve	$ (11,000)	$ (10,800)

(Segment Financial Information) (Details) - USD ($)
$ in Thousands

3 Months Ended

Mar. 31, 2016

Mar. 31, 2015

Dec. 31, 2015

Segment Reporting Information [Line Items]

Net sales

$ 1,455,504

$ 2,318,730

Operating income

78,627

255,993

Other income (expense), net

(20,413)

(21,588)

Income before income taxes

58,214

234,405

Depreciation and amortization

52,651

49,926

Capital expenditures

79,029

53,195

Goodwill

1,289,443

$ 1,289,443

Total assets

5,753,762

5,684,522

$ 5,833,393

Refining Group [Member]

Segment Reporting Information [Line Items]

Revenues

(418,513)

(948,899)

^[1]

Operating income

^[2]

62,138

148,612

^[1]

Depreciation and amortization

21,285

20,484

^[1]

Capital expenditures

43,563

17,826

^[1]

Total assets

1,620,113

1,606,073

^[1]

Retail Group [Member]

Segment Reporting Information [Line Items]

Revenues

(229,637)

(255,898)

Operating income

2,432

(441)

Depreciation and amortization

3,330

3,286

Capital expenditures

637

1,402

Total assets

239,359

249,318

Corporate and Other [Member]

Segment Reporting Information [Line Items]

Operating income

(15,496)

(17,726)

Depreciation and amortization

923

899

Capital expenditures

598

1,298

Total assets

1,117,626

1,075,408

Western Refining Logistics, LP [Member]

Segment Reporting Information [Line Items]

Revenues

(318,577)

(429,147)

^[1]

Operating income

21,438

17,561

^[1]

Depreciation and amortization

7,144

5,892

^[1]

Capital expenditures

6,241

25,996

^[1]

Total assets

448,218

495,028

^[1]

Northern Tier Energy LP [Member]

Segment Reporting Information [Line Items]

Revenues

(488,777)

(684,786)

Operating income

^[2]

8,115

107,987

Depreciation and amortization

19,969

19,365

Capital expenditures

27,990

6,673

Total assets

2,328,446

2,258,695

Intersegment Eliminations [Member] | Refining Group [Member]

Segment Reporting Information [Line Items]

Revenues

(467,807)

(542,542)

^[1]

Intersegment Eliminations [Member] | Retail Group [Member]

Segment Reporting Information [Line Items]

Revenues

(1,549)

(2,704)

Intersegment Eliminations [Member] | Western Refining Logistics, LP [Member]

Segment Reporting Information [Line Items]

Revenues

(149,462)

(178,249)

^[1]

Intersegment Eliminations [Member] | Northern Tier Energy LP [Member]

Segment Reporting Information [Line Items]

Revenues

(8,696)

(12,990)

Operating Segments [Member] | Refining Group [Member]

Segment Reporting Information [Line Items]

Revenues

(886,320)

(1,491,441)

^[1]

Operating Segments [Member] | Retail Group [Member]

Segment Reporting Information [Line Items]

Revenues

(231,186)

(258,602)

Operating Segments [Member] | Western Refining Logistics, LP [Member]

Segment Reporting Information [Line Items]

Revenues

(468,039)

(607,396)

^[1]

Operating Segments [Member] | Northern Tier Energy LP [Member]

Segment Reporting Information [Line Items]

Revenues

(497,473)

(697,776)

Goodwill

$ 1,289,443

^[1]

[1]

[2]

Fair Value Measurement (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 70,100	$ 70,070
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	0
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hypothetical Change in Estimated Future Cash Flows	$ (400)

(Assets & Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	$ 67,079	$ 79,733
Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	67,079	79,733
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	0	0
Derivative Asset	67,079	79,733
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	71,037	85,489
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(3,958)	(5,756)
Commodity Contract [Member] \| Other Current Assets [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	86,144	95,062
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	19,080	16,937
Derivative Asset	67,064	78,125
Commodity Contract [Member] \| Other Current Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Commodity Contract [Member] \| Other Current Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	86,144	95,062
Commodity Contract [Member] \| Other Current Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Commodity Contract [Member] \| Other Assets [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	8,019	11,881
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	867	0
Derivative Asset	7,152	11,881
Commodity Contract [Member] \| Other Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Commodity Contract [Member] \| Other Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	8,019	11,881
Commodity Contract [Member] \| Other Assets [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	0	0
Commodity Contract [Member] \| Accrued Liabilities [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(12,647)	(21,454)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	5,510	11,181
Derivative Liability	(7,137)	(10,273)
Commodity Contract [Member] \| Accrued Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Commodity Contract [Member] \| Accrued Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(8,689)	(15,698)
Commodity Contract [Member] \| Accrued Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(3,958)	(5,756)
Commodity Contract [Member] \| Other Long-term Liabilities [Member] \| Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(14,437)	(5,756)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	14,437	5,756
Derivative Liability	0	0
Commodity Contract [Member] \| Other Long-term Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	0	0
Commodity Contract [Member] \| Other Long-term Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(14,437)	(5,756)
Commodity Contract [Member] \| Other Long-term Liabilities [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	$ 0	$ 0

Fair Value Measurement (Level 3 Rollforward) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivative Asset	$ 79,733
Derivative Asset	67,079
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Fair Value, Inputs, Level 3 [Member]
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivative Asset		$ 330
Derivative Liability	(5,756)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	186	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Purchases	0	1,462
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3	1,612	(82)
Derivative Asset		$ 1,710
Derivative Liability	$ (3,958)

Fair Value Measurement (Fair Value, Debt) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 1,658,092	$ 1,650,394
Western Refining, Inc. [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	887,625	889,000
Western Refining, Inc. [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	838,373	867,178
Northern Tier Energy LP [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	372,500	350,000
Northern Tier Energy LP [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	367,250	360,500
Western Refining Logistics, LP [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	430,000	445,000
Western Refining Logistics, LP [Member] \| Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	$ 400,000	$ 439,000

Inventories (Inventory Summary) (Details)
bbl in Thousands, $ in Thousands

3 Months Ended

Mar. 31, 2016

USD ($)

bbl

Mar. 31, 2015

USD ($)

Dec. 31, 2015

USD ($)

bbl

Inventory, Net [Abstract]

Refined products (1)

^[1]

$ 267,861

$ 201,928

Crude oil and other raw materials

362,415

288,403

Lubricants

12,356

14,996

Retail store merchandise

40,961

42,211

Inventories

683,593

547,538

Inventory Adjustments [Abstract]

FIFO Inventory Amount

15,000

14,500

Inventory Valuation Reserves

123,400

$ 175,100

Inventory, Change in Lower of Cost or Market Reserve

$ (51,700)

$ (15,700)

Inventory Valued Using LIFO | bbl

12,592

10,026

Inventory, LIFO Reserve

$ 221,400

$ 198,400

Inventory, LIFO Reserve, Effect on Income, Net

$ (23,000)

$ (113,600)

[1]	Includes $15.0 million and $14.5 million of inventory valued using the first-in, first-out ("FIFO") valuation method at March 31, 2016 and December 31, 2015, respectively.

Inventories (LIFO Cost per Barrel) (Details) bbl in Thousands, $ in Thousands	Mar. 31, 2016 USD ($) bbl $ / Barrel	Dec. 31, 2015 USD ($) bbl $ / Barrel
Inventory Disclosure [Abstract]
Energy Related Inventory, Refined Products, Volume \| bbl	5,130	3,536
Energy Related Inventory, Refined Products, LIFO Inventory Amount \| $	$ 314,934	$ 259,722
Energy Related Inventory, Refined Products, Average Lifo Cost Per Barrel \| $ / Barrel	61.39	73.45
Energy Related Inventory, Crude Oil and Natural Gas Liquids, Volume \| bbl	7,462	6,490
Energy Related Inventory, Crude Oil and Natural Gas Liquids, LIFO Inventory Amount \| $	$ 423,694	$ 391,237
Energy Related Inventory, Crude Oil and Natural Gas Liquids, Average LIFO Cost Per Barrel \| $ / Barrel	56.78	60.28
Inventory Valued Using LIFO \| bbl	12,592	10,026
LIFO Inventory Amount \| $	$ 738,628	$ 650,959
Energy Related Inventory, Average LIFO Cost Per Barrel \| $ / Barrel	58.66	64.93

Equity Method Investment (Details) - USD ($)	3 Months Ended
Equity Method Investment (Details) - USD ($)	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 102,971,000		$ 97,513,000
Income from equity method investment, net of dividends	$ 0	$ 0
Minnesota Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	17.00%
Equity method investment	$ 103,000,000		97,500,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	21,300,000		$ 21,328,000
Equity Method Investment, Quoted Market Value	0
Proceeds from Equity Method Investment, Dividends or Distributions	0	3,700,000
Income from equity method investment, net of dividends	$ 5,500,000	$ 3,600,000

Property, Plant and Equipment, Net (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 3,392,413		$ 3,322,067
Accumulated depreciation	(1,067,822)		(1,016,896)
Property, plant and equipment, net	2,324,591		2,305,171
Depreciation	51,600	$ 48,900
Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,390,745		2,348,663
Pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	559,040		533,040
Retail Site [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	329,808		328,419
Wholesale Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	61,369		61,133
Corporate and Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 51,451		$ 50,812

Intangible Assets, Net Finite-Lived Intangibles (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 35,883		$ 34,817
Finite-Lived Intangible Assets, Accumulated Amortization	20,183		19,447
Finite-Lived Intangible Assets, Net	15,700		15,370
Amortization of Intangible Assets	700	$ 700
Finite-Lived Intangible Assets, Net, Amortization Expense, Rolling Maturity [Abstract]
Finite-Lived Intangible Assets, Amortization Expense, Remainder of Fiscal Year	2,204
Finite-Lived Intangible Assets, Amortization Expense, Year Two	2,906
Finite-Lived Intangible Assets, Amortization Expense, Year Three	2,905
Finite-Lived Intangible Assets, Amortization Expense, Year Four	2,237
Finite-Lived Intangible Assets, Amortization Expense, Year Five	1,292
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	$ 1,006
Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	1 year	1 year
Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life	35 years	23 years
Licensing Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 20,427		20,427
Finite-Lived Intangible Assets, Accumulated Amortization	14,124		13,729
Finite-Lived Intangible Assets, Net	$ 6,303		6,698
Finite-Lived Intangible Asset, Useful Life	4 years
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 7,551		7,551
Finite-Lived Intangible Assets, Accumulated Amortization	4,060		3,921
Finite-Lived Intangible Assets, Net	$ 3,491		3,630
Finite-Lived Intangible Asset, Useful Life	6 years 3 months 10 days
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 7,905		6,839
Finite-Lived Intangible Assets, Accumulated Amortization	1,999		1,797
Finite-Lived Intangible Assets, Net	$ 5,906		$ 5,042
Finite-Lived Intangible Asset, Useful Life	8 years 7 months

Intangible Assets, Net Indefinite-Lived Intangibles (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Indefinite-lived Intangible Assets [Line Items]
Intangible Assets, Gross (Excluding Goodwill)	$ 105,458	$ 104,392
Finite-Lived Intangible Assets, Accumulated Amortization	20,183	19,447
Intangible Assets, Net (Excluding Goodwill)	85,275	84,945
Franchise Rights and Trademarks [Member]
Indefinite-lived Intangible Assets [Line Items]
Indefinite-Lived Intangible Assets (Excluding Goodwill)	50,500	50,500
Liquor Licenses [Member]
Indefinite-lived Intangible Assets [Line Items]
Indefinite-Lived Intangible Assets (Excluding Goodwill)	$ 19,075	$ 19,075

(Debt Summary) (Details) - USD ($)	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt	$ 1,658,092,000	$ 1,650,394,000
Debt Instrument, Unamortized Discount (Premium), Net	32,033,000	33,606,000
Current portion of long-term debt	5,500,000	5,500,000
Long-term debt, less current portion	1,652,592,000	1,644,894,000
Revolving Credit Facility [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	0
Revolving Credit Facility [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	22,500,000
Western Refining, Inc. [Member]
Debt Instrument [Line Items]
Long-term debt	887,625,000	889,000,000
Western Refining, Inc. [Member] \| Revolving Credit Facility [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Long-term debt	0	0
Western Refining, Inc. [Member] \| Line of Credit [Member] \| Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	537,625,000	539,000,000
Western Refining, Inc. [Member] \| Senior Notes [Member] \| 6.25% Senior Notes due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt	350,000,000	350,000,000
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Long-term debt	372,500,000	350,000,000
Northern Tier Energy LP [Member] \| Revolving Credit Facility [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt		0
Northern Tier Energy LP [Member] \| Senior Notes [Member] \| 7.125% NTI Secured Notes, due 2020 [Member]
Debt Instrument [Line Items]
Long-term debt	350,000,000	350,000,000
Western Refining Logistics, LP [Member]
Debt Instrument [Line Items]
Long-term debt	430,000,000	445,000,000
Western Refining Logistics, LP [Member] \| Revolving Credit Facility [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Long-term debt	130,000,000	145,000,000
Western Refining Logistics, LP [Member] \| Senior Notes [Member] \| 7.5% WNRL Secured Notes, due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt	$ 300,000,000	$ 300,000,000

Long-Term Debt (Interest Expense and Other Financing Costs) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	$ 25,671	$ 22,324
Amortization of Financing Costs	1,911	1,786
Interest Expense, Other	(176)	1,075
Capitalized interest	725	228
Interest Expense	26,681	24,957
Western Refining, Inc. [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	12,052	12,007
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	6,914	6,591
Western Refining Logistics, LP [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	$ 6,705	$ 3,726

Long-Term Debt (Revolving Credit Facilities) (Details) - USD ($)		3 Months Ended
	Oct. 15, 2013	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Oct. 02, 2014	Sep. 29, 2014	Oct. 16, 2013	Jul. 17, 2012
Debt Instrument [Line Items]
Deferred financing costs		$ 0		$ 6,551,000
Borrowings on revolving credit facility		70,000,000		0
Repayments of Long-term Lines of Credit		62,500,000		$ 269,000,000
Loans [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding		$ 0
Loans [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity							$ 45,000,000
Revolving Credit Facility [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity								$ 300,000,000
Line of Credit Facility, Difference Between Current Borrowing Capacity and Maximum Borrowing Capacity								200,000,000
Line of Credit Facility, Maximum Borrowing Capacity								500,000,000
Line of Credit Facility, Expiration Date	Oct. 16, 2018
Debt Instrument, Interest Rate, Stated Percentage		2.69%
Borrowings on revolving credit facility			$ 145,000,000		$ 269,000,000
Repayments of Long-term Lines of Credit		$ 15,000,000
Debt Instrument, Interest Rate, Effective Percentage		2.76%
Revolving Credit Facility [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity						$ 900,000,000
Line of Credit Facility, Maximum Borrowing Capacity						$ 1,400,000,000
Line of Credit Facility, Expiration Date				Oct. 02, 2019
Line of Credit Facility, Remaining Borrowing Capacity		$ 201,000,000
Line of Credit Facility, Amount Outstanding		$ 0
Revolving Credit Facility [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity							500,000,000		$ 300,000,000
Line of Credit Facility, Maximum Borrowing Capacity							750,000,000
Line of Credit Facility, Expiration Date		Sep. 29, 2019
Deferred financing costs		$ 3,000,000
Line of Credit Facility, Remaining Borrowing Capacity		134,700,000
Line of Credit Facility, Amount Outstanding		22,500,000
Letters of Credit Outstanding, Amount		$ 29,400,000
Debt Instrument, Interest Rate, Effective Percentage		5.77%
Revolving Credit Facility [Member] \| Minimum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage				0.25%
Line of Credit Facility, Commitment Fee Percentage				1.50%
Revolving Credit Facility [Member] \| Minimum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		1.50%
Line of Credit Facility, Commitment Fee Percentage		0.25%
Revolving Credit Facility [Member] \| Maximum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage				0.375%
Line of Credit Facility, Commitment Fee Percentage				2.00%
Revolving Credit Facility [Member] \| Maximum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage		2.00%
Line of Credit Facility, Commitment Fee Percentage		0.375%
Revolving Credit Facility [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity		$ 169,300,000
Line of Credit Facility, Amount Outstanding		130,000,000
Letters of Credit Outstanding, Amount		700,000
Revolving Credit Facility [Member] \| Loans [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								10,000,000
Revolving Credit Facility [Member] \| Standby Letters of Credit [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity								$ 25,000,000
Letter of Credit [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		$ 64,400,000
Letter of Credit [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity							$ 500,000,000
Base Rate [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	0.75%
Base Rate [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						0.50%
Base Rate [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Base Rate [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
Base Rate [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						1.00%
Base Rate [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.00%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	LIBOR
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis				LIBOR
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.75%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate				1.50%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Minimum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.50%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.75%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| Revolving Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate				2.00%
London Interbank Offered Rate (LIBOR) [Member] \| Revolving Credit Facility [Member] \| Maximum [Member] \| NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.00%

Long-Term Debt (Term Loans) (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2013	Mar. 31, 2016	Nov. 13, 2013	Mar. 25, 2013
Line of Credit [Member] \| Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 550.0
Debt Instrument, Periodic Payment, Principal	$ 1.4
Debt Instrument, Interest Rate, Stated Percentage			4.25%
Debt Instrument, Interest Rate, Effective Percentage		4.65%
Senior Notes [Member] \| 6.25% Senior Notes due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount				$ 350.0
Debt Instrument, Interest Rate, Stated Percentage				6.25%
Debt Instrument, Interest Rate, Effective Percentage		6.52%
Base Rate [Member] \| Line of Credit [Member] \| Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.25%
Eurodollar [Member] \| Line of Credit [Member] \| Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.25%
Eurodollar [Member] \| Line of Credit [Member] \| Minimum [Member] \| Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			1.00%

Long-Term Debt (Notes) (Details) - USD ($) $ in Thousands	3 Months Ended
Long-Term Debt (Notes) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Mar. 31, 2015	Sep. 30, 2014	Feb. 11, 2015	Sep. 25, 2014	Nov. 12, 2013	Mar. 25, 2013	Nov. 08, 2012
Debt Instrument [Line Items]
Repayments of Long-term Lines of Credit	$ 62,500	$ 269,000
Additions to long-term debt	0	300,000
Deferred financing costs	0	$ 6,551
Long-term Debt, Maturities, Repayments of Principal, Remainder of Fiscal Year	4,100
Long-term Debt, Maturities, Repayments of Principal in Year Two	5,500
Long-term Debt, Maturities, Repayments of Principal in Year Three	135,500
Long-term Debt, Maturities, Repayments of Principal in Year Four	28,000
Long-term Debt, Maturities, Repayments of Principal in Year Five	867,000
Long-term Debt, Maturities, Repayments of Principal after Year Five	$ 650,000
Senior Notes [Member] \| 7.5% WNRL Secured Notes, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				7.50%
Debt Instrument, Face Amount				$ 300,000
Debt Instrument, Interest Rate, Effective Percentage	7.78%
Senior Notes [Member] \| 7.125% NTI Secured Notes, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage						7.125%		7.125%
Debt Instrument, Face Amount					$ 75,000			$ 275,000
Debt Instrument, Unamortized Premium					$ 4,200
Additions to long-term debt			$ 79,200
Deferred financing costs			$ 2,500
Debt Instrument, Interest Rate, Effective Percentage	6.91%
Senior Notes [Member] \| 6.25% Senior Notes due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage							6.25%
Debt Instrument, Face Amount							$ 350,000
Debt Instrument, Interest Rate, Effective Percentage	6.52%

Equity (Equity Rollforward) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Schedule of Capitalization, Equity [Line Items]
Beginning Balance	$ 2,945,906	$ 2,787,644
Net income attributable to Western Refining, Inc.	30,538	105,989
Less net income attributable to non-controlling interests	9,047	68,979
Net income	39,585	174,968
Other Comprehensive Income (Loss), Net of Tax	0	8
Dividends	(35,601)	(28,638)
Stock-based compensation expense	4,985	3,504
Tax benefit deficiency from stock-based compensation	(328)	(337)
Distributions to non-controlling interests	(28,747)	(33,665)
Treasury Stock, Value, Acquired, Cost Method	(75,000)	(25,000)
Ending Balance	2,850,800	2,879,158
Parent [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning Balance	1,299,297	1,119,708
Other Comprehensive Income (Loss), Net of Tax		8
Dividends	(35,601)	(28,638)
Stock-based compensation expense	328	1,001
Tax benefit deficiency from stock-based compensation	(328)	(337)
Distributions to non-controlling interests	0	0
Treasury Stock, Value, Acquired, Cost Method	(75,000)	(25,000)
Ending Balance	1,219,234	1,173,405
Noncontrolling Interest [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning Balance	1,646,609	1,667,936
Less net income attributable to non-controlling interests	9,047	68,979
Other Comprehensive Income (Loss), Net of Tax		0
Dividends	0	0
Stock-based compensation expense	4,657	2,503
Tax benefit deficiency from stock-based compensation	0	0
Distributions to non-controlling interests	(28,747)	(33,665)
Treasury Stock, Value, Acquired, Cost Method	0	0
Ending Balance	$ 1,631,566	$ 1,705,753

Equity (Share Repurchase Program Summary) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Authorized Amount	$ 200,000
Disclosure of Repurchase Agreements [Abstract]
Treasury Stock, Shares	9,089,623
Treasury Stock, Shares	11,551,973
Payments for Repurchase of Equity [Abstract]
Treasury Stock, Value	$ 363,168
Purchase of common stock for treasury	(75,000)	$ (25,000)
Treasury Stock, Value	438,168
Share Repurchase Program - Authorized September 2015 [Member]
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 125,000
Disclosure of Repurchase Agreements [Abstract]
Treasury Stock, Shares	0
Treasury Stock, Shares, Acquired	2,462,350
Treasury Stock, Shares	2,462,350
Payments for Repurchase of Equity [Abstract]
Treasury Stock, Value	$ 0
Purchase of common stock for treasury	(75,000)
Treasury Stock, Value	$ 75,000

Equity (Dividends) (Details) - USD ($)
$ / shares in Units, $ in Thousands

3 Months Ended

Jun. 30, 2016

Mar. 31, 2016

Mar. 31, 2015

Dividends Payable [Line Items]

Payments of Ordinary Dividends, Common Stock

$ 35,601

$ 28,638

Cash dividends declared per common share

$ 0.38

$ 0.30

Subsequent Event [Member]

Dividends Payable [Line Items]

Payments of Ordinary Dividends, Common Stock

$ 34,700

Cash dividends declared per common share

^[1]

$ 0.38

[1]	(1) The second quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $34.7 million.

Equity (Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Mar. 31, 2015	Jun. 30, 2016
Northern Tier Energy LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.38
Western Refining Logistics, LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.39
Incentive Distribution, Distribution		$ 0.8	$ 0.0
Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit				$ 0.38
Subsequent Event [Member] \| Western Refining Logistics, LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.4025			$ 0.7950

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
Income Taxes (Details) - USD ($) $ in Millions	Mar. 31, 2016	Mar. 31, 2015
Operating Loss Carryforwards [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate	35.00%
Effective Income Tax Rate, Continuing Operations	(32.00%)	(25.40%)
Operating Loss Carryforwards, Reduction to Valuation Allowance	$ 0.0
Unrecognized tax benefits	40.2
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	20.9
Unrecognized Tax Benefits, Period Increase (Decrease)	0.0
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0.2	$ 0.1
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Valuation Allowance	$ 20.8

Retirement Plans (Details) - USD ($) $ in Thousands	3 Months Ended
Retirement Plans (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ 651	$ (1,291)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Tax	0	13
Income tax	0	(5)
Accumulated Other Comprehensive Income (Loss), Net of Tax	651	(1,283)
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	600	600
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	0	200
Defined Benefit Plan, Benefit Obligation			$ 6,200
Western Refining, Inc. [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	2,000	2,000
Northern Tier Energy LP [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 2,600	$ 2,200

(Risk Management) (Details)	3 Months Ended
(Risk Management) (Details)	Mar. 31, 2016 $ / Incident
Unleaded Gasoline Crack Spread Swap [Member] \| Minimum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	14.61
Unleaded Gasoline Crack Spread Swap [Member] \| Maximum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	17.13
Distillate Crack Spread Swaps [Member] \| Minimum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	7.08
Distillate Crack Spread Swaps [Member] \| Maximum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	12.19

Crude Oil and Refined Product Risk Management (Economic Hedging Activity) (Details) bbl in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016 USD ($) bbl	Mar. 31, 2015 USD ($) bbl	Dec. 31, 2015 USD ($)
Derivative [Line Items]
Realized Investment Gains (Losses) \| $	$ 17,803	$ 17,553
Derivative, Gain (Loss) on Derivative, Net \| $	5,320	(2,504)
Unrealized Gain (Loss) on Derivatives and Commodity Contracts \| $	(12,483)	$ (20,057)
Derivative Asset \| $	$ 67,079		$ 79,733
Not Designated as Hedging Instrument [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(2,478)
Not Designated as Hedging Instrument [Member] \| Long [Member] \| Inventory Positions - Crude Oil & Refined Products - Swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(7,201)	(5,155)
Not Designated as Hedging Instrument [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume		(1,052)
Not Designated as Hedging Instrument [Member] \| Short [Member] \| Inventory Positions - Crude Oil & Refined Products - Futures & Swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,823)	(562)
Not Designated as Hedging Instrument [Member] \| Short [Member] \| Refined Products - Crack Spread Swaps [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(2,900)	(5,645)

Crude Oil and Refined Product Risk Management (Derivative Instrument by Balance Sheet Location) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Asset	$ 67,079	$ 79,733
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	67,079	79,733
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	67,079	79,733
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	0	0
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	86,144	95,062
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	19,080	16,937
Derivative Asset	67,064	78,125
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Other Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	8,019	11,881
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	867	0
Derivative Asset	7,152	11,881
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Accrued Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	12,647	21,454
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	5,510	11,181
Derivative Liability	(7,137)	(10,273)
Commodity Contract [Member] \| Fair Value, Measurements, Recurring [Member] \| Other Long-term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	14,437	5,756
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	14,437	5,756
Derivative Liability	$ 0	$ 0

Crude Oil and Refined Product Risk Management (Notional Volume of Outstanding Contracts) (Details) - Not Designated as Hedging Instrument [Member] - bbl bbl in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume		(1,052)
Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(2,478)
Inventory Positions - Crude Oil - Differential Swaps - Current Fiscal Year [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(5,283)
Inventory Positions - Crude Oil & Refined Products - Futures & Swaps [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,823)	(562)
Inventory Positions - Natural Gas - Futures & Swaps [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(720)
Inventory Positions - Natural Gas - Futures & Swaps - Year Two [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(329)
Refined Product Positions - Unleaded Gasoline - Crack Spread Swaps [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(900)
Refined Product Positions - Unleaded Gasoline - Crack Spread Swaps - Year Two [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Refined Product Positions - Distillate - Crack Spread Swaps [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(744)
Refined Product Positions - Distillate - Crack Spread Swaps - Year Two [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,305)
Inventory Positions - Natural Gas - Futures & Swaps - Year Three [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Refined Product Positions - Distillate - Crack Spread Swaps - Year Three [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Refined Product Positions - Unleaded Gasoline - Crack Spread Swaps - Year Three [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Inventory Positions - Crude Oil - Differential Swaps - Year Two [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,918)
Inventory Positions - Crude Oil - Differential Swaps - Year Three [Member] \| Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Inventory Positions - Crude Oil - Futures - Current Fiscal Year [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,823)
Inventory Positions - Crude Oil - Futures - Year Two [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Inventory Positions - Crude Oil - Futures - Year Three [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Inventory Positions - Refined Products - Futures & Swaps - Current Fiscal Year [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(999)
Inventory Positions - Refined Products - Futures & Swaps - Year Two [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Inventory Positions - Refined Products - Futures & Swaps - Year Three [Member] \| Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0

Stock-Based Compensation (Stock-Based Compensation, Western) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Excess tax benefit from stock-based compensation	$ 0	$ 337
Statutory Blended Tax Rate, Excess Tax Benefit	38.10%	38.10%
Long Term Incentive Plan, 2006 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	19,856
Incentive Plan of Western Refining, 2010 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	2,418,248
Incentive Plans of Western Refining, Inc. [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested		$ 2,800
Excess tax benefit from stock-based compensation		300
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value		1,900
Incentive Plans of Western Refining, Inc. [Member] \| Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 1,000	$ 1,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested	2,400
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Weighted Average Grant Date Fair Value	21,600
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Intrinsic Value	19,100
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 19,600
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	3 years 1 month 17 days
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	$ (300)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$ 3,200
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	399,214
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	339,618
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(79,118)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(3,424)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	656,290
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 37.43
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	29.60
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	40.71
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	43.81
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 32.95
Minimum [Member] \| Incentive Plans of Western Refining, Inc. [Member] \| Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	1 year
Maximum [Member] \| Incentive Plans of Western Refining, Inc. [Member] \| Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	5 years

Stock-Based Compensation (Stock-Based Compensation, NTI) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distributions accrued on unvested NTI equity awards	$ 3,964	$ 0
NTI 2012 LTIP [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	6,659,555
Allocated Share-based Compensation Expense	$ 4,600	$ 2,600
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 26,300		$ 16,100
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,536,998
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years
NTI 2012 LTIP [Member] \| Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Nonvested, Number of Shares	1
Distributions accrued on unvested NTI equity awards	$ 800		700
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	191,424
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Number of Shares, Period Increase (Decrease)	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(34,054)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	157,370
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 24.75
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	0.00
Share-based Compensation Arrangements by Share-based Payment Award, Options, Other Share Increase (Decrease) in Period, Weighted Average Exercise Price	0.00
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	(26.84)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	(0.00)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 24.30
NTI 2012 LTIP [Member] \| Phantom Common Units, Service-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distributions accrued on unvested NTI equity awards	$ 1,700		2,500
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	581,882
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	381,029
Share-based Compensation Arrangement by Share-based Payment Award, Options, Number of Shares, Period Increase (Decrease)	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(235,546)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(523)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	726,842
NTI 2012 LTIP [Member] \| Phantom Common Units, Performance-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distributions accrued on unvested NTI equity awards	$ 1,500		$ 1,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 260,690
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	163,571
Share-based Compensation Arrangements by Share-based Payment Award, Options, Other Share Increase (Decrease) in Period, Weighted Average Exercise Price	231,777
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	(1,789)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	(1,463)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 652,786
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years
NTI 2012 LTIP [Member] \| Phantom Common Units, Performance Conditions Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	342,695
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	200.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years
NTI 2012 LTIP [Member] \| Phantom Common Units, Market-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Weighted Average Volatility Rate	29.80%	34.10%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	1.08%	0.84%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	310,091
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	181.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Term	3 years
NTI 2012 LTIP [Member] \| Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	842,572
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	544,600
Share-based Compensation Arrangement by Share-based Payment Award, Options, Number of Shares, Period Increase (Decrease)	231,777
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(237,335)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(1,986)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	1,379,628
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 24.00
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	30.27
Share-based Compensation Arrangements by Share-based Payment Award, Options, Other Share Increase (Decrease) in Period, Weighted Average Exercise Price	38.17
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	(24.05)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	(24.01)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 28.90
Minimum [Member] \| NTI 2012 LTIP [Member] \| Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Forfeiture Rate	0.00%
Minimum [Member] \| NTI 2012 LTIP [Member] \| Phantom Common Units, Service-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Forfeiture Rate	0.00%
Minimum [Member] \| NTI 2012 LTIP [Member] \| Phantom Common Units, Performance-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	0.00%
Maximum [Member] \| NTI 2012 LTIP [Member] \| Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Forfeiture Rate	0.00%
Maximum [Member] \| NTI 2012 LTIP [Member] \| Phantom Common Units, Service-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Forfeiture Rate	0.00%
Maximum [Member] \| NTI 2012 LTIP [Member] \| Phantom Common Units, Performance-Based [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Rights, Percentage	200.00%

Stock-Based Compensation (Stock-Based Compensation, WNRL) (Details) - WNRL 2013 LTIP [Member] - Phantom Share Units (PSUs) [Member] - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	4,111,322
Allocated Share-based Compensation Expense	$ 0.5	$ 0.4
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Weighted Average Grant Date Fair Value	7.9
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Intrinsic Value	6.9
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 7.4
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	3 years 1 month 13 days
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	279,787
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	75,919
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(60,705)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	295,001
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 28.06
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	22.53
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	26.80
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	0.00
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 26.64

Earnings per Share (Schedule of Earnings per Share, Basic) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Earnings Per Share, Basic [Abstract]
Net income attributable to Western Refining, Inc.	$ 30,538	$ 105,989
Distributed Earnings	35,601	28,638
Undistributed Earnings, Basic	$ (5,063)	$ 77,351
Weighted Average Number of Shares Outstanding, Basic	92,078	95,567
Earnings Per Share, Basic, Distributed	$ 0.39	$ 0.30
Earnings Per Share, Basic, Undistributed	(0.05)	0.81
Earnings Per Share, Basic	$ 0.34	$ 1.11

Earnings per Share (Schedule of Earnings per Share, Diluted) (Details) - $ / shares shares in Thousands	3 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Mar. 31, 2015
Earnings Per Share, Diluted [Abstract]
Weighted Average Number of Shares Outstanding, Diluted		92,144	95,682
Earnings Per Share, Diluted		$ 0.33	$ 1.11
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements		66	115
Subsequent Event [Member] \| Northern Tier Energy LP [Member] \| Common Stock [Member]
Weighted Average Number of Shares Outstanding Reconciliation [Abstract]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17,200

Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended
Cash Flows (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Mar. 31, 2015
Supplemental Cash Flow Elements [Abstract]
Income taxes paid	$ 11,215	$ 40,009
Interest paid, excluding amounts capitalized	20,676	8,959
Assets acquired through capital lease obligations	328	19,511
Accrued capital expenditures	46,045	12,741
Distributions receivable from equity method investee	0	3,740
Distributions accrued on unvested NTI equity awards	3,964	0
Transfer of capital spares from fixed assets to other assets	$ 699	$ 0

Leases and Other Commitments (Details) $ in Thousands	3 Months Ended
Leases and Other Commitments (Details) $ in Thousands	Mar. 31, 2016 USD ($)	Mar. 31, 2015 USD ($)	Dec. 31, 2015 USD ($)
Other Commitments [Line Items]
Capital Leased Assets, Number of Units	38
Description of Lessee Leasing Arrangements, Capital Leases	20
Capital Lease Obligations, Current	$ 1,100		$ 1,000
Lease financing obligations	53,190		53,232
Deferred Gain on Sale of Property	2,200
Capital Leases, Future Minimum Payments, Annual, Due in Next Five Years	5,200
Operating Leases, Rent Expense, Net	17,700	$ 15,900
Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Remaining 2016	3,859
2017	5,060
2018	5,084
2019	5,195
2020	5,386
2021 and thereafter	70,941
Total minimum lease payments	95,525
Less amount that represents interest	43,476		$ 44,100
Present value of net minimum capital lease payments	52,049
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Remaining 2016	43,908
2017	52,828
2018	49,495
2019	44,407
2020	40,218
2021 and thereafter	340,046
Operating Leases, Future Minimum Payments Due	$ 570,902
El Paso Office Building [Member]
Other Commitments [Line Items]
Description of Lessee Leasing Arrangements, Operating Leases	10
Office Building, Tempe [Member]
Other Commitments [Line Items]
Description of Lessee Leasing Arrangements, Operating Leases	11
Sulfuric Acid Regeneration Units [Member]
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Operating Leases, Future Minimum Payments Due	$ 15,700
Minimum [Member]
Other Commitments [Line Items]
Discount Rate, Capital Leases	3.24%
Maximum [Member]
Other Commitments [Line Items]
Discount Rate, Capital Leases	10.51%
Northern Tier Energy LP [Member]
Other Commitments [Line Items]
Capital Leased Assets, Number of Units	19
Capital Leases, Future Minimum Payments, Annual, Due in Next Five Years	$ 1,300
Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2021 and thereafter	$ 14,200
Retail Group [Member]
Other Commitments [Line Items]
Capital Leased Assets, Number of Units	19

Contingencies (Details) - USD ($)	1 Months Ended		3 Months Ended		12 Months Ended		33 Months Ended	60 Months Ended
Contingencies (Details) - USD ($)	May. 31, 2014	May. 31, 2000	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Jul. 31, 2012	Dec. 31, 2013
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies			$ 19,400,000		$ 18,300,000
Cost of products sold (exclusive of depreciation and amortization)			1,047,361,000	$ 1,741,310,000
Northern Tier Energy LP [Member] \| Environmental Issue [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies			8,500,000		8,600,000
Loss Contingency, Receivable			100,000		200,000
Accrual for Environmental Loss Contingencies, Discount			$ 2,500,000		2,600,000
Fair Value Assumptions, Expected Term			22 years
Effect on Future Cash Flows, Amount			$ 3,000,000
Accrual for Environmental Loss Contingencies, Discount Rate			2.27%
Renewable Identification Number [Member] \| Environmental Issue [Member]
Loss Contingencies [Line Items]
Cost of products sold (exclusive of depreciation and amortization)			$ 13,600,000	$ 6,200,000
Four Corners Refineries [Member] \| Four Corners 2005 Consent Agreements [Member] \| Environmental Issue [Member]
Loss Contingencies [Line Items]
Loss Contingency, Loss in Period			100,000		100,000	$ 1,900,000		$ 50,800,000
Litigation Settlement, Amount							$ 2,700,000
Four Corners Refineries [Member] \| Gallup 2014 Environmental Protection Division of NMED Settlement [Member] \| Environmental Issue [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount	$ 100,000
Environmental Costs Recognized, Capitalized in Period			0
St. Paul Park, Minnesota [Member] \| NTI MPCA Waste Water Permit [Member] \| Environmental Issue [Member] \| Maximum [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss					$ 6,000,000
St. Paul Park, Minnesota [Member] \| NTI MPCA Waste Water Permit [Member] \| Northern Tier Energy LP [Member] \| Environmental Issue [Member] \| Maximum [Member]
Loss Contingencies [Line Items]
Loss Contingency, Estimate of Possible Loss			6,000,000
Gain (Loss) Related to Litigation Settlement			3,500,000
El Paso Facility [Member] \| Texas Natural Resources Conservation Commision [Member] \| Environmental Issue [Member] \| Maximum [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies			$ 6,600,000
Loss Contingency, Third Party Obligation After Threshold, Percentage		60.00%
Loss Contingency, Estimated Recovery from Third Party After Threshold, Amount		$ 20,000,000

Related Party Transactions (Details) - USD ($)	3 Months Ended		9 Months Ended
Related Party Transactions (Details) - USD ($)	Mar. 31, 2016	Mar. 31, 2015	Sep. 30, 2014
El Paso Office Building [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	$ 200,000
Operating Leases, Rent Expense	60,000	$ 60,000
Capital Lease Obligations	0
Minnesota Pipe Line Company [Member] \| Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Shipping, Handling and Transportation Costs			$ 0
Gas Gathering, Transportation, Marketing and Processing Costs	$ 14,000,000	$ 12,700,000

Condensed Consolidating Financial Information (Consolidation Information) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Investment in subsidiaries	$ 0	$ 0
Equity - Western	$ 1,219,234	1,299,297
Western Refining Logistics GP, LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	66.40%
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	38.30%
Northern Tier Energy GP LLC [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Reportable Legal Entities [Member] \| Parent Company [Member]
Segment Reporting Information [Line Items]
Investment in subsidiaries	$ 3,994,766	3,964,578
Equity - Western	1,219,234	1,299,297
Reportable Legal Entities [Member] \| Guarantor Subsidiaries [Member]
Segment Reporting Information [Line Items]
Investment in subsidiaries	0	0
Equity - Western	$ 3,235,487	$ 3,194,986

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 593,101	$ 772,502	$ 463,074	$ 431,159	$ 431,159
Accounts receivable, trade, net of a reserve for doubtful accounts	337,077	359,237
Accounts receivable, affiliate	0	0
Inventories	683,593	547,538
Prepaid expenses	79,971	73,213
Other current assets	159,591	169,728
Total current assets	1,853,333	1,922,218
Assets, Noncurrent [Abstract]
Restricted cash	36,783	69,106
Equity method investment	102,971	97,513
Property, plant and equipment, net	2,324,591	2,305,171
Goodwill	1,289,443	1,289,443
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	85,275	84,945
Investment in subsidiaries	0	0
Due from affiliate	0	0
Other assets, net	61,366	64,997
Total assets	5,753,762	5,833,393	5,684,522
Current liabilities:
Accounts payable, trade	562,430	553,957
Accounts payable, affiliate	0	0
Accrued liabilities	218,752	248,395
Current portion of long-term debt	5,500	5,500
Total current liabilities	786,682	807,852
Long-term liabilities:
Long-term debt, less current portion	1,652,592	1,644,894
Due to affiliate	0	0
Lease financing obligations	53,190	53,232
Deferred income tax liability, net	341,475	312,914
Deficit in subsidiaries	0	0
Other long-term liabilities	69,023	68,595
Total long-term liabilities	2,116,280	2,079,635
Equity [Abstract]
Equity - Western	1,219,234	1,299,297
Non-controlling interests	1,631,566	1,646,609
Total equity	2,850,800	2,945,906	2,879,158	$ 2,787,644
Total liabilities and equity	5,753,762	5,833,393
Consolidation, Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0	0		0
Accounts receivable, trade, net of a reserve for doubtful accounts	0	0
Accounts receivable, affiliate	(71,563)	(59,055)
Inventories	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	(71,563)	(59,055)
Assets, Noncurrent [Abstract]
Restricted cash	0	0
Equity method investment	0	0
Property, plant and equipment, net	0	0
Goodwill	0	0
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	0	0
Investment in subsidiaries	(3,994,766)	(3,964,578)
Due from affiliate	(1,894,627)	(1,797,047)
Other assets, net	0	0
Total assets	(5,960,956)	(5,820,680)
Current liabilities:
Accounts payable, trade	0	0
Accounts payable, affiliate	(71,563)	(59,055)
Accrued liabilities	0	0
Current portion of long-term debt	0	0
Total current liabilities	(71,563)	(59,055)
Long-term liabilities:
Long-term debt, less current portion	0	0
Due to affiliate	(1,894,627)	(1,797,047)
Lease financing obligations	0	0
Deferred income tax liability, net	0	0
Deficit in subsidiaries	(399,553)	(395,774)
Other long-term liabilities	0	0
Total long-term liabilities	(2,294,180)	(2,192,821)
Equity [Abstract]
Equity - Western	(3,595,213)	(3,568,804)
Non-controlling interests	0	0
Total equity	(3,595,213)	(3,568,804)
Total liabilities and equity	(5,960,956)	(5,820,680)
Parent Company [Member] \| Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	21	21	21		21
Accounts receivable, trade, net of a reserve for doubtful accounts	0	0
Accounts receivable, affiliate	3,007	0
Inventories	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	3,028	21
Assets, Noncurrent [Abstract]
Restricted cash	0	0
Equity method investment	0	0
Property, plant and equipment, net	0	0
Goodwill	0	0
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	0	0
Investment in subsidiaries	3,994,766	3,964,578
Due from affiliate	0	0
Other assets, net	0	0
Total assets	3,997,794	3,964,599
Current liabilities:
Accounts payable, trade	10,938	0
Accounts payable, affiliate	0	920
Accrued liabilities	10,975	5,508
Current portion of long-term debt	5,500	5,500
Total current liabilities	27,413	11,928
Long-term liabilities:
Long-term debt, less current portion	856,520	856,327
Due to affiliate	1,894,627	1,797,047
Lease financing obligations	0	0
Deferred income tax liability, net	0	0
Deficit in subsidiaries	0	0
Other long-term liabilities	0	0
Total long-term liabilities	2,751,147	2,653,374
Equity [Abstract]
Equity - Western	1,219,234	1,299,297
Non-controlling interests	0	0
Total equity	1,219,234	1,299,297
Total liabilities and equity	3,997,794	3,964,599
Guarantor Subsidiaries [Member] \| Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	529,460	656,966	256,561		288,986
Accounts receivable, trade, net of a reserve for doubtful accounts	104,551	122,593
Accounts receivable, affiliate	66,012	55,550
Inventories	419,692	311,589
Prepaid expenses	61,472	55,699
Other current assets	118,778	135,139
Total current assets	1,299,965	1,337,536
Assets, Noncurrent [Abstract]
Restricted cash	36,783	69,106
Equity method investment	0	0
Property, plant and equipment, net	1,106,879	1,099,787
Goodwill	0	0
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	31,923	31,401
Investment in subsidiaries	0	0
Due from affiliate	1,894,627	1,797,047
Other assets, net	37,975	42,166
Total assets	4,408,152	4,377,043
Current liabilities:
Accounts payable, trade	251,898	262,550
Accounts payable, affiliate	0	0
Accrued liabilities	110,587	142,257
Current portion of long-term debt	0	0
Total current liabilities	362,485	404,807
Long-term liabilities:
Long-term debt, less current portion	0	0
Due to affiliate	0	0
Lease financing obligations	41,943	42,168
Deferred income tax liability, net	304,195	275,634
Deficit in subsidiaries	399,553	395,774
Other long-term liabilities	64,489	63,674
Total long-term liabilities	810,180	777,250
Equity [Abstract]
Equity - Western	3,235,487	3,194,986
Non-controlling interests	0	0
Total equity	3,235,487	3,194,986
Total liabilities and equity	4,408,152	4,377,043
Non-Guarantor Subsidiaries [Member] \| Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	63,620	115,515	$ 206,492		$ 142,152
Accounts receivable, trade, net of a reserve for doubtful accounts	232,526	236,644
Accounts receivable, affiliate	2,544	3,505
Inventories	263,901	235,949
Prepaid expenses	18,499	17,514
Other current assets	40,813	34,589
Total current assets	621,903	643,716
Assets, Noncurrent [Abstract]
Restricted cash	0	0
Equity method investment	102,971	97,513
Property, plant and equipment, net	1,217,712	1,205,384
Goodwill	1,289,443	1,289,443
Intangible assets, net (WNRL: $7,566 and $7,757, respectively)	53,352	53,544
Investment in subsidiaries	0	0
Due from affiliate	0	0
Other assets, net	23,391	22,831
Total assets	3,308,772	3,312,431
Current liabilities:
Accounts payable, trade	299,594	291,407
Accounts payable, affiliate	71,563	58,135
Accrued liabilities	97,190	100,630
Current portion of long-term debt	0	0
Total current liabilities	468,347	450,172
Long-term liabilities:
Long-term debt, less current portion	796,072	788,567
Due to affiliate	0	0
Lease financing obligations	11,247	11,064
Deferred income tax liability, net	37,280	37,280
Deficit in subsidiaries	0	0
Other long-term liabilities	4,534	4,921
Total long-term liabilities	849,133	841,832
Equity [Abstract]
Equity - Western	359,726	373,818
Non-controlling interests	1,631,566	1,646,609
Total equity	1,991,292	2,020,427
Total liabilities and equity	$ 3,308,772	$ 3,312,431

Condensed Consolidating Financial Information (Condensed Consolidating Income Statement) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Net sales	$ 1,455,504	$ 2,318,730
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	1,047,361	1,741,310
Direct operating expenses (exclusive of depreciation and amortization)	223,585	215,311
Selling, general and administrative expenses	53,285	55,803
Gain on disposal of assets, net	(130)	282
Maintenance turnaround expense	125	105
Depreciation and amortization	52,651	49,926
Total operating costs and expenses	1,376,877	2,062,737
Operating income	78,627	255,993
Income from equity method investment, net of dividends	0	0
Other income (expense):
Interest income	164	163
Interest and debt expense	(26,681)	(24,957)
Other, net	6,104	3,206
Income before income taxes	58,214	234,405
Provision for income taxes	(18,629)	(59,437)
Net income	39,585	174,968
Less net income attributable to non-controlling interests	9,047	68,979
Net income attributable to Western Refining, Inc.	30,538	105,989
Comprehensive income	30,538	105,997
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	(514,548)	(769,542)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	(514,548)	(769,542)
Direct operating expenses (exclusive of depreciation and amortization)	0	0
Selling, general and administrative expenses	0	0
Gain on disposal of assets, net	0	0
Maintenance turnaround expense	0	0
Depreciation and amortization	0	0
Total operating costs and expenses	(514,548)	(769,542)
Operating income	0	0
Income from equity method investment, net of dividends	(53,029)	(127,987)
Other income (expense):
Interest income	0	0
Interest and debt expense	0	0
Other, net	0	0
Income before income taxes	(53,029)	(127,987)
Provision for income taxes	0	0
Net income	(53,029)	(127,987)
Less net income attributable to non-controlling interests	0	0
Net income attributable to Western Refining, Inc.	(53,029)	(127,987)
Comprehensive income	(53,029)	(127,987)
Parent Company [Member] \| Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	0	0
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	0	0
Direct operating expenses (exclusive of depreciation and amortization)	0	0
Selling, general and administrative expenses	46	47
Gain on disposal of assets, net	0	0
Maintenance turnaround expense	0	0
Depreciation and amortization	0	0
Total operating costs and expenses	46	47
Operating income	(46)	(47)
Income from equity method investment, net of dividends	43,725	119,759
Other income (expense):
Interest income	0	0
Interest and debt expense	(13,141)	(13,723)
Other, net	0	0
Income before income taxes	30,538	105,989
Provision for income taxes	0	0
Net income	30,538	105,989
Less net income attributable to non-controlling interests	0	0
Net income attributable to Western Refining, Inc.	30,538	105,989
Comprehensive income	30,538	105,989
Guarantor Subsidiaries [Member] \| Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	1,004,540	1,783,100
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	798,548	1,488,688
Direct operating expenses (exclusive of depreciation and amortization)	106,540	109,235
Selling, general and administrative expenses	24,695	29,530
Gain on disposal of assets, net	(26)	381
Maintenance turnaround expense	125	105
Depreciation and amortization	25,538	24,669
Total operating costs and expenses	955,420	1,652,608
Operating income	49,120	130,492
Income from equity method investment, net of dividends	9,304	8,228
Other income (expense):
Interest income	114	97
Interest and debt expense	(738)	(507)
Other, net	1,069	45
Income before income taxes	58,869	138,355
Provision for income taxes	(18,368)	(59,234)
Net income	40,501	79,121
Less net income attributable to non-controlling interests	0	0
Net income attributable to Western Refining, Inc.	40,501	79,121
Comprehensive income	40,501	79,129
Non-Guarantor Subsidiaries [Member] \| Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	965,512	1,305,172
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	763,361	1,022,164
Direct operating expenses (exclusive of depreciation and amortization)	117,045	106,076
Selling, general and administrative expenses	28,544	26,226
Gain on disposal of assets, net	(104)	(99)
Maintenance turnaround expense	0	0
Depreciation and amortization	27,113	25,257
Total operating costs and expenses	935,959	1,179,624
Operating income	29,553	125,548
Income from equity method investment, net of dividends	0	0
Other income (expense):
Interest income	50	66
Interest and debt expense	(12,802)	(10,727)
Other, net	5,035	3,161
Income before income taxes	21,836	118,048
Provision for income taxes	(261)	(203)
Net income	21,575	117,845
Less net income attributable to non-controlling interests	9,047	68,979
Net income attributable to Western Refining, Inc.	12,528	48,866
Comprehensive income	$ 12,528	$ 48,866

Condensed Consolidating Financial Information (Condensed Consolidating Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	$ 1,104	$ 104,978
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	(79,029)	(53,195)
Return of capital from equity method investment	0
Use of restricted cash	32,323	43,400
Contributions to affiliate	0	0
Proceeds from the sale of assets	219	624
Net cash used in investing activities	(46,487)	(9,171)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt	0	300,000
Payments on long-term debt and capital lease obligations	(1,922)	(1,375)
Borrowings on revolving credit facility	70,000	0
Repayments on revolving credit facility	(62,500)	(269,000)
Distribution to affiliate	0	0
Deferred financing costs	0	(6,551)
Purchase of common stock for treasury	(75,000)	(25,000)
Distribution to non-controlling interest holders	28,995	33,665
Dividends paid	(35,601)	(28,638)
Contributions from affiliates	0	0
Excess tax benefit from stock-based compensation	0	337
Net cash used in financing activities	(134,018)	(63,892)
Net increase (decrease) in cash and cash equivalents	(179,401)	31,915
Cash and cash equivalents at beginning of period	772,502	431,159
Cash and cash equivalents at end of period	593,101	463,074
Reportable Legal Entities [Member] \| Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	4,786	12,172
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	0	0
Return of capital from equity method investment	13,537
Use of restricted cash	0	0
Contributions to affiliate	0	0
Proceeds from the sale of assets	0	0
Net cash used in investing activities	13,537	0
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt		0
Payments on long-term debt and capital lease obligations	(1,375)	(1,375)
Borrowings on revolving credit facility	0
Repayments on revolving credit facility	0	0
Distribution to affiliate	0	0
Deferred financing costs		0
Purchase of common stock for treasury	(75,000)	(25,000)
Distribution to non-controlling interest holders	0	0
Dividends paid	(35,601)	(28,638)
Contributions from affiliates	93,653	42,841
Excess tax benefit from stock-based compensation		0
Net cash used in financing activities	(18,323)	(12,172)
Net increase (decrease) in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	21
Cash and cash equivalents at end of period	21	21
Reportable Legal Entities [Member] \| Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(21,284)	4,907
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	(44,798)	(20,526)
Return of capital from equity method investment	0
Use of restricted cash	32,323	43,400
Contributions to affiliate	(93,653)	(61,636)
Proceeds from the sale of assets	100	1,093
Net cash used in investing activities	(106,028)	(37,669)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt		0
Payments on long-term debt and capital lease obligations	(194)	0
Borrowings on revolving credit facility	0
Repayments on revolving credit facility	0	0
Distribution to affiliate	0	0
Deferred financing costs		0
Purchase of common stock for treasury	0	0
Distribution to non-controlling interest holders	0	0
Dividends paid	0	0
Contributions from affiliates	0	0
Excess tax benefit from stock-based compensation		337
Net cash used in financing activities	(194)	337
Net increase (decrease) in cash and cash equivalents	(127,506)	(32,425)
Cash and cash equivalents at beginning of period	656,966
Cash and cash equivalents at end of period	529,460	256,561
Reportable Legal Entities [Member] \| Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	30,994	115,668
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	(34,231)	(33,317)
Return of capital from equity method investment	0
Use of restricted cash	0	0
Contributions to affiliate	0	0
Proceeds from the sale of assets	119	179
Net cash used in investing activities	(34,112)	(33,138)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt		300,000
Payments on long-term debt and capital lease obligations	(353)	0
Borrowings on revolving credit facility	70,000
Repayments on revolving credit facility	(62,500)	(269,000)
Distribution to affiliate	(26,929)	(27,769)
Deferred financing costs		(6,551)
Purchase of common stock for treasury	0	0
Distribution to non-controlling interest holders	28,995	33,665
Dividends paid	0	0
Contributions from affiliates	0	18,795
Excess tax benefit from stock-based compensation		0
Net cash used in financing activities	(48,777)	(18,190)
Net increase (decrease) in cash and cash equivalents	(51,895)	64,340
Cash and cash equivalents at beginning of period	115,515
Cash and cash equivalents at end of period	63,620	206,492
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities	(13,392)	(27,769)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	0	648
Return of capital from equity method investment	(13,537)
Use of restricted cash	0	0
Contributions to affiliate	93,653	61,636
Proceeds from the sale of assets	0	(648)
Net cash used in investing activities	80,116	61,636
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt		0
Payments on long-term debt and capital lease obligations	0	0
Borrowings on revolving credit facility	0
Repayments on revolving credit facility	0	0
Distribution to affiliate	26,929	27,769
Deferred financing costs		0
Purchase of common stock for treasury	0	0
Distribution to non-controlling interest holders	0	0
Dividends paid	0	0
Contributions from affiliates	(93,653)	(61,636)
Excess tax benefit from stock-based compensation		0
Net cash used in financing activities	(66,724)	(33,867)
Net increase (decrease) in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	0
Cash and cash equivalents at end of period	$ 0	$ 0

NTI (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Common Stock, Par or Stated Value Per Share		$ 0.01	$ 0.01
Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payments to Acquire Businesses, Gross	$ 862.3
Northern Tier Energy GP LLC [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		100.00%
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		38.30%
Western Acquisition Holdings, LLC [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		100.00%
MergerCo HoldCo [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		100.00%
Common Stock [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17.2
Minimum [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit	$ 15.00
Minimum [Member] \| Common Stock [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	0.2986
Maximum [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit	26.06
Maximum [Member] \| Common Stock [Member] \| Subsequent Event [Member] \| Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036

WNRL (Details) bbl in Millions	3 Months Ended
WNRL (Details) bbl in Millions	Mar. 31, 2016 mi bbl	Mar. 31, 2015
Western Refining Logistics, LP [Member]
Variable Interest Entity [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	66.40%
Western Refining Logistics GP, LLC [Member]
Variable Interest Entity [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	100.00%
Customer Concentration Risk [Member] \| Sales Revenue, Net [Member] \| Western Refining Logistics, LP [Member]
Variable Interest Entity [Line Items]
Concentration Risk, Percentage	31.90%	29.30%
Western Refining Logistics, LP [Member]
Variable Interest Entity [Line Items]
Pipeline, Miles \| mi	685
Active Storage Capacity \| bbl	8.2

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