Northern Tier Energy 10-Q 3 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	9 Months Ended
	Sep. 30, 2016	Oct. 28, 2016	Sep. 30, 2015
Document Information [Line Items]
Entity Registrant Name	Western Refining, Inc.
Entity Central Index Key	1,339,048
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
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		108,427,295
Northern Tier Energy LP [Member]
Document Information [Line Items]
Entity Registrant Name	Northern Tier Energy LP
Entity Central Index Key	1,533,454
Entity Filer Category	Large Accelerated Filer

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 266,096	$ 772,502
Restricted cash	195,000	0
Accounts receivable, trade, net of a reserve for doubtful accounts	447,327	359,237
Inventories	660,738	547,538
Prepaid expenses	129,138	73,213
Other current assets	121,581	169,728
Total current assets	1,819,880	1,922,218
Restricted cash	0	69,106
Equity method investment	98,185	97,513
Property, plant and equipment, net	2,357,291	2,305,171
Goodwill	1,289,443	1,289,443
Intangible assets, net	84,543	84,945
Other assets, net	65,783	64,997
Total assets	5,715,125	5,833,393
Current liabilities:
Accounts payable	634,716	553,957
Accrued liabilities	216,169	248,395
Current portion of long-term debt	10,500	5,500
Total current liabilities	861,385	807,852
Long-term liabilities:
Long-term debt, less current portion	2,045,180	1,644,894
Lease financing obligations	54,541	53,232
Deferred income tax liability, net	416,951	312,914
Other liabilities	69,622	68,595
Total long-term liabilities	2,586,294	2,079,635
Commitments and contingencies
Equity:
Common stock, par value $0.01, 240,000,000 shares authorized; 108,426,740 and 102,773,705 shares issued, respectively	1,085	1,028
Preferred stock, par value $0.01, 10,000,000 shares authorized; no shares issued or outstanding	0	0
Additional paid-in capital	550,876	492,848
Retained earnings	1,112,895	1,167,938
Accumulated other comprehensive loss, net of tax	599	651
Treasury stock, 9,089,623 shares at cost	0	363,168
Equity - Western	1,665,455	1,299,297
Non-controlling interests	601,991	1,646,609
Total equity	2,267,446	2,945,906
Total liabilities and equity	5,715,125	5,833,393
Northern Tier Energy LP [Member]
Current assets:
Cash and cash equivalents	14,600	70,900
Restricted cash	195,000	0
Accounts receivable, trade, net of a reserve for doubtful accounts	255,900	186,000
Inventories	290,500	241,200
Other current assets	31,100	21,300
Total current assets	787,100	519,400
Equity method investment	82,800	82,100
Property, plant and equipment, net	504,300	487,800
Intangible assets, net	33,800	33,800
Other assets, net	14,300	14,200
Total assets	1,422,300	1,137,300
Current liabilities:
Accounts payable	331,900	301,400
Accrued liabilities	74,700	61,800
Total current liabilities	406,600	363,200
Long-term liabilities:
Long-term debt, less current portion	395,500	342,000
Lease financing obligations	9,200	11,100
Other liabilities	25,700	27,900
Liabilities	837,000	744,200
Commitments and contingencies
Equity:
Limited Partners' Capital Account	585,300	392,900
Accumulated other comprehensive loss, net of tax	0	200
Equity - Western	585,300	393,100
Total liabilities and equity	$ 1,422,300	$ 1,137,300

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 266,096	$ 772,502
Accounts receivable, trade, net of a reserve for doubtful accounts	447,327	359,237
Reserve for doubtful accounts	246	169
Inventories	660,738	547,538
Prepaid expenses	129,138	73,213
Other current assets	121,581	169,728
Assets, Noncurrent [Abstract]
Property, plant and equipment, net	2,357,291	2,305,171
Intangible assets, net	84,543	84,945
Other assets, net	65,783	64,997
Current liabilities:
Accounts payable	634,716	553,957
Accrued liabilities	216,169	248,395
Long-term liabilities:
Long-term debt, less current portion	2,045,180	1,644,894
Other liabilities	$ 69,622	$ 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	108,426,740	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		9,089,623
Western Refining Logistics, LP [Member]
Current assets:
Cash and cash equivalents	$ 16,542	$ 44,605
Accounts receivable, trade, net of a reserve for doubtful accounts	57,065	55,053
Inventories	11,130	15,200
Prepaid expenses	5,523	4,133
Other current assets	6,066	5,943
Assets, Noncurrent [Abstract]
Property, plant and equipment, net	422,006	430,141
Intangible assets, net	6,813	7,757
Other assets, net	3,409	3,376
Current liabilities:
Accounts payable	9,171	10,501
Accrued liabilities	34,181	30,624
Long-term liabilities:
Long-term debt, less current portion	312,835	437,467
Other liabilities	9	9
Northern Tier Energy LP [Member]
Current assets:
Cash and cash equivalents	14,600	70,900
Accounts receivable, trade, net of a reserve for doubtful accounts	255,900	186,000
Inventories	290,500	241,200
Other current assets	31,100	21,300
Assets, Noncurrent [Abstract]
Property, plant and equipment, net	504,300	487,800
Intangible assets, net	33,800	33,800
Other assets, net	14,300	14,200
Current liabilities:
Accounts payable	331,900	301,400
Accrued liabilities	74,700	61,800
Long-term liabilities:
Long-term debt, less current portion	395,500	342,000
Other liabilities	$ 25,700	$ 27,900
Equity:
Limited Partners' Capital Account, Units Outstanding	92,947,533	92,833,486
Limited Partners' Capital Account, Units Issued	92,947,533	92,833,486

Condensed Consolidated Statemen

Condensed Consolidated Statement of Operations (Unaudited) Statement - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Net sales	$ 2,065,076	$ 2,569,090	$ 5,627,888	$ 7,716,712
Operating Costs and Expenses [Abstract]
Cost of products sold (exclusive of depreciation and amortization)	1,607,010	1,895,772	4,256,999	5,814,969
Direct operating expenses (exclusive of depreciation and amortization)	232,553	234,440	687,307	674,474
Selling, general and administrative expenses	57,320	54,465	166,657	169,808
Gain on disposal of assets, net	279	52	1,181	157
Maintenance turnaround expense	27,208	490	27,733	1,188
Depreciation and amortization	54,321	51,377	161,331	152,446
Total operating costs and expenses	1,978,133	2,236,492	5,298,846	6,812,728
Operating income	86,943	332,598	329,042	903,984
Other income (expense):
Income (Loss) from Equity Method Investments	0	0	0	0
Interest income	141	186	436	550
Interest and debt expense	(34,456)	(26,896)	(88,065)	(79,169)
Other, net	3,380	4,327	13,825	11,557
Income before income taxes	56,008	310,215	255,238	836,922
Provision for income taxes	(11,700)	(92,117)	(68,481)	(229,989)
Net income	44,308	218,098	186,757	606,933
Less net income attributable to non-controlling interests	5,733	64,795	52,229	213,722
Net income attributable to Western Refining, Inc.	38,575	153,303	134,528	393,211
Comprehensive income attributable to Western Refining, Inc.	$ 38,575	$ 153,311	$ 134,476	$ 393,276
Earnings Per Share [Abstract]
Earnings Per Share, Basic	$ 0.36	$ 1.61	$ 1.37	$ 4.12
Earnings Per Share, Diluted	$ 0.35	$ 1.61	$ 1.37	$ 4.12
Weighted Average Number of Shares Outstanding [Abstract]
Weighted Average Number of Shares Outstanding, Basic	108,424	94,826	97,802	95,308
Weighted Average Number of Shares Outstanding, Diluted	108,734	94,924	98,110	95,408
Dividends [Abstract]
Cash dividends declared per common share	$ 0.38	$ 0.34	$ 1.14	$ 0.98
Northern Tier Energy LP [Member]
Revenues	$ 732,300	$ 891,600	$ 2,149,000	$ 2,645,200
Operating Costs and Expenses [Abstract]
Cost of Goods Sold	584,700	666,600	1,685,000	1,957,700
Direct operating expenses	83,200	75,200	238,300	220,800
Selling, general and administrative expenses	20,500	20,500	66,200	62,900
Turnaround And Related Expenses	24,600	7,800	26,800	9,400
Depreciation and amortization	12,100	11,000	35,000	32,600
Merger-related expenses	1,500	0	2,600	0
Income from equity method investment	5,300	4,200	15,300	12,000
Depreciation and amortization	12,100	11,000	35,000	32,600
Other Operating Income	600	(100)	700	(400)
Operating income	11,600	114,600	111,100	373,400
Other income (expense):
Income (Loss) from Equity Method Investments			800	6,200
Interest and debt expense	(5,800)	(7,500)	(18,500)	(22,500)
Income before income taxes	5,800	107,100	92,600	350,900
Provision for income taxes	(2,200)	(3,600)	(3,700)	(7,300)
Net income attributable to Western Refining, Inc.	3,600	103,500	88,900	343,600
Other comprehensive income, net of tax, post-employment benefit plans gain (loss)	0	0	(200)	100
Comprehensive income attributable to Western Refining, Inc.	$ 3,600	$ 103,500	$ 88,700	$ 343,700
Dividends [Abstract]
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0	$ 1.19	$ 0.56	$ 2.76
Income Statement Related Disclosures [Abstract]
Excise and Sales Taxes	$ 104,600	$ 93,600	$ 323,500	$ 296,600

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Net income	$ 44,308	$ 218,098	$ 186,757	$ 606,933
Benefit plans:
Amortization of net prior service cost	0	0	(133)	107
Reclassification of loss to income	0	13	11	38
Other comprehensive income (loss) before tax	0	13	(122)	145
Income tax	0	(5)	0	(14)
Other comprehensive income (loss), net of tax	0	8	(122)	131
Comprehensive income	44,308	218,106	186,635	607,064
Less comprehensive income attributable to non-controlling interests	5,733	64,795	52,159	213,788
Comprehensive income attributable to Western Refining, Inc.	38,575	153,311	134,476	393,276
Northern Tier Energy LP [Member]
Benefit plans:
Comprehensive income attributable to Western Refining, Inc.	$ 3,600	$ 103,500	$ 88,700	$ 343,700

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows from operating activities:
Net income attributable to Western Refining, Inc.	$ 134,528	$ 393,211
Net income	186,757	606,933
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	161,331	152,446
Changes in fair value of commodity hedging instruments	54,698	42,073
Reserve for doubtful accounts	77	103
Share-based Compensation	17,490	12,576
Amortization of loan fees and original issue discount	5,948	4,801
Change in lower of cost or market inventory adjustment	(102,519)	(17,131)
Deferred income taxes	58,727	47
Excess tax benefit from stock-based compensation	(26)	(879)
Income (Loss) from Equity Method Investments	0	0
Income from equity method investment, net of dividends	850	12,029
Gain on disposal of assets, net	1,181	157
Changes in operating assets and liabilities:
Accounts receivable	(88,976)	54,738
Inventories	(10,681)	(5,479)
Prepaid expenses	(55,925)	(10,706)
Other assets	(7,768)	(43,093)
Accounts payable and accrued liabilities	69,572	(113,051)
Other long-term liabilities	(8,797)	(5,528)
Net cash provided by operating activities	277,877	665,664
Cash flows from investing activities:
Capital expenditures	235,097	195,976
Increase in restricted cash	(195,000)	0
Use of restricted cash	69,106	154,681
Return of capital from equity method investment	0	5,780
Proceeds from the sale of assets	3,912	1,061
Payments to Fund Long-term Loans to Related Parties	0	0
Net cash used in investing activities	(357,079)	(34,454)
Cash flows from financing activities:
Additions to long-term debt	500,000	300,000
Payments on long-term debt and capital lease obligations	(7,150)	(5,559)
Borrowings on revolving credit facility	393,900	0
Repayments on revolving credit facility	(466,600)	(269,000)
Payments for NTI units related to merger	(859,893)	0
Transaction costs for NTI merger	(11,741)	0
Proceeds from issuance of WNRL common units	(277,751)	0
Offering costs for issuance of WNRL common units	(417)	0
Deferred financing costs	12,410	6,820
Purchase of common stock for treasury	(75,000)	(105,000)
Distribution to non-controlling interest holders	(54,115)	(173,687)
Payments of Dividends	111,555	93,612
Excess tax benefit from stock-based compensation	26	879
Net cash used in financing activities	(427,204)	(352,799)
Net increase (decrease) in cash and cash equivalents	(506,406)	278,411
Cash and cash equivalents at beginning of period	772,502	431,159
Cash and cash equivalents at end of period	266,096	709,570
Northern Tier Energy LP [Member]
Cash flows from operating activities:
Net income attributable to Western Refining, Inc.	88,900	343,600
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	35,000	32,600
Depreciation and amortization	35,000	32,600
Unrealized Gain (Loss) on Derivatives	6,100	300
Other Noncash Income (Expense)	(1,500)	(1,500)
Share-based Compensation	11,000	7,900
Change in lower of cost or market inventory adjustment	(61,800)	(12,200)
Other	(500)	0
Deferred income taxes	(800)	0
Income (Loss) from Equity Method Investments	800	6,200
Changes in operating assets and liabilities:
Accounts receivable	(69,900)	54,100
Inventories	11,900	(20,200)
Other current assets	7,600	3,300
Accounts payable and accrued liabilities	46,200	(81,200)
Other, net	2,900	(1,000)
Net cash provided by operating activities	44,100	317,300
Cash flows from investing activities:
Capital expenditures	99,200	35,200
Increase in restricted cash	(195,000)	0
Net cash used in investing activities	(294,200)	(35,200)
Cash flows from financing activities:
Borrowings on revolving credit facility	339,500	0
Proceeds from (Repayments of) Lines of Credit	(287,500)	0
Proceeds from sale of assets to entity under common control	195,000	0
Payments of Capital Distribution	53,200	255,400
Net cash used in financing activities	193,800	(255,400)
Net increase (decrease) in cash and cash equivalents	(56,300)	26,700
Cash and cash equivalents at beginning of period	70,900	87,900
Cash and cash equivalents at end of period	$ 14,600	$ 114,600

Organization (Notes)

Organization (Notes)	9 Months Ended
	Sep. 30, 2016
Segment Reporting Information [Line Items]
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 our refineries in El Paso, Texas, Gallup, New Mexico and 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 545 company-owned and franchised retail sites in the United States. As of September 30, 2016 , we own 100% of the limited partner interest in Northern Tier Energy LP ("NTI") and 100% of its general partner. We entered into an Agreement and Plan of Merger dated as of December 21, 2015 (the “Merger Agreement”), with Western Acquisition Co, LLC (“MergerCo”) which is a wholly-owned subsidiary of Western, NTI and Northern Tier Energy GP LLC, to acquire all of NTI’s outstanding common units not already held by us (the “Merger”). On June 23, 2016, following the approval of the Merger Agreement by NTI common unitholders, all closing conditions to the Merger were satisfied, and the Merger was successfully completed. We incurred $500 million of additional secured indebtedness under our amended term loan credit agreement to partially fund the Merger consideration. See Note 9, Long-Term Debt , and Note 21, Acquisitions , for further discussion. At September 30, 2016 , we owned a 52.6% limited partner interest in Western Refining Logistics, LP ("WNRL" or the "Partnership") and the public held a 47.4% 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. On September 15, 2016 , we sold certain assets consisting of terminals, transportation and storage assets and the related land located on site at our St. Paul Park refinery and Cottage Grove tank farm to WNRL. These assets primarily receive, store and distribute crude oil, feedstock and refined products associated with the St. Paul Park refinery (the " St. Paul Park Logistics Assets "). WNRL acquired these assets from us in exchange for $195.0 million in cash and 628,224 common units representing limited partner interests in WNRL. We refer to this transaction as the " St. Paul Park Logistics Transaction ." On September 7, 2016 , WNRL entered into an underwriting agreement relating to the issuance and sale of 7,500,000 of its common units representing limited partner interests in the Partnership. The closing of the offering occurred on September 13, 2016. WNRL also granted the underwriter an option to purchase additional common units on the same terms which was exercised in full and closed on September 30, 2016 , for 1,125,000 additional common units. On May 16, 2016, WNRL entered into an underwriting agreement relating to the issuance and sale by WNRL of 3,750,000 common units representing limited partner interests in WNRL. The closing of the offering occurred on May 20, 2016. WNRL also granted the underwriter an option to purchase up to 562,500 additional WNRL common units on the same terms. The underwriter fully exercised the option on June 1, 2016. On October 30, 2015, we sold a 375 mile segment of the TexNew Mex Pipeline system to WNRL. This segment of the TexNew Mex Pipeline 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 St. Paul Park Logistics Transaction and the TexNew Mex Pipeline Transaction. The acquisitions from Western were 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 assets acquired, for periods prior to the effective date of the transactions. During the third quarter of 2016, we changed our reportable segments due to changes in our organization. Our operations include three business segments: refining, WNRL and retail. See Note 3, Segment Information , for further discussion of our business segments.
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Organization	. DESCRIPTION OF THE BUSINESS AND BASIS OF PRESENTATION Description of the Business Northern Tier Energy LP ("NTE LP", "NTI" "Northern Tier" or the "Company") is a wholly-owned subsidiary of Western Refining, Inc. ("Western") operating as a downstream energy company with refining, retail and logistics operations that serve the Petroleum Administration for Defense District II (“PADD II”) region of the United States. NTE LP holds 100% of the membership interest in Northern Tier Energy LLC (“NTE LLC”). NTE LP is a master limited partnership (“MLP”) for U.S. federal income tax purposes. NTE LP includes the operations of NTE LLC, St. Paul Park Refining Co. LLC (“SPPR”), Northern Tier Retail Holdings LLC (“NTRH”) and Northern Tier Oil Transport LLC (“NTOT”). NTRH is the parent company of Northern Tier Retail LLC (“NTR”) and Northern Tier Bakery LLC (“NTB”). NTR is the parent company of SuperAmerica Franchising LLC (“SAF”). SPPR owns a 17% interest in MPL Investments Inc. (“MPLI”) and a 17% interest in Minnesota Pipe Line Company, LLC (“MPL”). MPLI owns 100% of the preferred interest in MPL, which owns and operates a 465,000 barrel per day (“bpd”) crude oil pipeline in Minnesota (see Note 6 ). NTOT is a crude oil trucking business in North Dakota that collects crude oil directly from wellheads in the Bakken shale and transports it to regional pipeline and rail facilities. Western indirectly owns 100% of both Northern Tier Energy GP LLC ("NTE GP") and NTE LP. Western, through its subsidiary NT InterHold Co LLC, a Delaware limited liability company ("NT InterHold Co") as the owner of the general partner of NTE LP, has the ability to appoint all of the members of the NTE GP's board of directors. On December 21, 2015 , Western and NTE LP announced that they had entered into an Agreement and Plan of Merger dated as of December 21, 2015 ("the Merger Agreement"), with NTE GP and Western Acquisition Co, LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("MergerCo") whereby Western would acquire all of Northern Tier's outstanding common units not already owned by Western (the "Merger"). Based upon the consideration elections made by NTI common unitholders, this cash and Western common stock was allocated among NTI common unitholders as follows: • NTI common unitholders who made a valid “Mixed Election” (as defined in the Merger Agreement), or who made no election, received $15.00 in cash and 0.2986 of a share of Western common stock for each such NTI common unit held. • NTI common unitholders who made a valid “Cash Election” (as defined in the Merger Agreement) received $15.357 in cash and 0.28896 of a share of Western common stock as prorated in accordance with the Merger Agreement for each such NTI common unit held. • NTI common unitholders who made a valid “Stock Election” (as defined in the Merger Agreement) received 0.7036 of a share of Western common stock for each such NTI common unit held. On June 23, 2016, following the approval of the Merger by NTI common unitholders, all closing conditions to the Merger were satisfied, and the Merger was successfully completed. The transaction resulted in approximately 17.1 million additional shares of WNR common stock outstanding. Subsequent to this transaction, NTI continues to exist as a limited partnership and became an indirect wholly-owned subsidiary of Western (see Note 19 ). Refining Business As of September 30, 2016 , the St. Paul Park refinery owned by SPPR, which is located in St. Paul Park, Minnesota, had total crude oil throughput capacity of 98,000 barrels per stream day. Refining operations include crude fractionation, catalytic cracking, hydrotreating, reforming, alkylation, sulfur recovery and a hydrogen plant. The refinery processes predominately North Dakota and Canadian crude oils into products such as gasoline, diesel, jet fuel, kerosene, asphalt, propane, propylene and sulfur. The refined products are sold primarily in the Upper Great Plains of the United States. On September 7, 2016, SPPR entered into a Contribution, Conveyance and Assumption Agreement (the “Contribution Agreement”) by and among Western, SPPR, Western Refining Logistics, LP ("WNRL") and Western Refining Logistics GP, LLC, the general partner of WNRL. Pursuant to the terms of the Contribution Agreement, SPPR sold certain tank, terminal, rack, transportation facilities and other logistics assets to WNRL in exchange for $195 million cash and 628,224 common units representing limited partner interests in WNRL. Concurrent with the Contribution Agreement, SPPR and WNRL entered into a terminalling, transportation and storage services agreement with an initial term of ten years whereby SPPR will pay fees to WNRL for storage, product throughput and blending services. See Note 3 for further discussion of this transaction. Retail Business As of September 30, 2016 , NTR operated 170 convenience stores under the SuperAmerica brand and SAF supported 115 franchised stores which also utilize the SuperAmerica brand. These 285 SuperAmerica stores are primarily located in Minnesota and Wisconsin and sell gasoline, merchandise and, in some locations, diesel fuel. There is a wide range of merchandise sold at the stores including prepared foods, beverages and non-food items. The merchandise sold includes a significant number of proprietary items. NTB prepares and distributes food products under the SuperMom’s brand primarily to SuperAmerica branded retail outlets. Basis of Presentation The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”) for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation of the results for the periods reported have been included. Operating results for the nine months ended September 30, 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 of NTE LP 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 Company’s 2015 Annual Report on Form 10-K.

Basis of Presentation and Signi

Basis of Presentation and Significant Accounting Policies (Notes)	9 Months Ended
	Sep. 30, 2016
Segment Reporting Information [Line Items]
Basis of Presentation and Significant Accounting Policies [Text Block]	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 principles ("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 and nine months ended September 30, 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 100% of NTI's general partner and, subsequent to the Merger, we own 100% of the limited partner interest in NTI. We own a 52.6% limited partner interest in WNRL and 100% of WNRL's general partner. As the general partner of WNRL, we have the ability to direct the activities of WNRL that most significantly impact their respective economic performance. We have reported a non-controlling interest for WNRL as of September 30, 2016 , of $602.0 million and non-controlling interests for NTI and WNRL of $1,646.6 million as of December 31, 2015 , in our Condensed Consolidated Balance Sheets. All intercompany accounts and transactions have been eliminated for all periods presented. Investments in significant non-controlled entities over which we have the ability to exercise significant influence 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 results of operations or cash flows decline at our St. Paul Park refinery or SuperAmerica operating segments. 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, in accordance with GAAP, requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the respective 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, 2015 and continuing into 2016, 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 with regard 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, classification in the statement of cash flows and forfeiture rate calculations. 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. • Cash flow statement - the requirements address certain classification issues related to the statement of cash flows. These provisions are effective for annual periods beginning after December 15, 2017, 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. • 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.
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Basis of Presentation and Significant Accounting Policies [Text Block]	2 . SUMMARY OF PRINCIPAL ACCOUNTING POLICIES The significant accounting policies set forth in Note 2 to the consolidated financial statements in the Company's 2015 Annual Report on Form 10-K, appropriately represent, in all material respects, the current status of accounting policies and are incorporated herein by reference. Principles of Consolidation NTE LP is a Delaware limited partnership which consolidates all accounts of NTE LLC and its subsidiaries, including SPPR, NTRH and NTOT. All intercompany accounts have been eliminated in these condensed consolidated financial statements. The Company’s common equity interest in MPL and WNRL are accounted for using the equity method of accounting. Although SPPR owns only 1.0% of WNRL's common equity, its indirect parent company, Western, owns 52.6% . Because of Western’s controlling influence over WNRL, the investment provides the Company significant influence over WNRL and the Company accounts for its ownership interest in WNRL under the equity method. Equity income from MPL and WNRL represent the Company’s proportionate share of net income available to common equity owners generated by MPL and WNRL. See Note 3 for further discussion of the Company's ownership interests in MPL and WNRL. The equity method investments are assessed for impairment whenever changes in facts or circumstances indicate a loss in value has occurred. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value, and the amount of the write-down is included in operating income. See Note 6 for further information on the Company’s equity method investment. MPLI owns all of the preferred membership units of MPL. This investment in MPLI, which provides the Company no significant influence over MPLI, is accounted for as a cost method investment. The investment in MPLI is carried at a value of $6.8 million at both September 30, 2016 and December 31, 2015 , and is included in other noncurrent assets within the condensed consolidated balance sheets. Use of Estimates The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Actual results could differ from those estimates. Operating Segments The Company has two reportable operating segments; Refining and Retail (see Note 18 for further information on the Company’s operating segments). The Refining and Retail operating segments consist of the following: • Refining – operates the St. Paul Park, Minnesota refinery, terminal and related assets, NTOT and includes the Company’s interest in MPL and MPLI, and • Retail – comprised of 170 Company operated convenience stores and 115 franchisee operated convenience stores as of September 30, 2016 , primarily in Minnesota and Wisconsin. The retail segment also includes the operation of NTB. Inventories Crude oil, refined product and other feedstock and blendstock inventories are carried at the lower of cost or market ("LCM"). Cost is determined principally under the last-in, first-out (“LIFO”) valuation method to reflect a better matching of costs and revenues for refining inventories. Costs include both direct and indirect expenditures incurred in bringing an item or product to its existing condition and location. Ending inventory costs in excess of market value are written down to net realizable market values and charged to cost of sales in the period recorded. In subsequent periods, a new LCM determination is made based upon current circumstances relative to, and not to exceed, the original LCM reserve that was established in fourth quarter 2014. The Company has LIFO pools for crude oil and other feedstocks and for refined products in its Refining segment and a LIFO pool for refined products inventory held by the retail stores in its Retail segment. Retail merchandise inventory is valued using the average cost method. Property, Plant and Equipment Property, plant and equipment is recorded at cost and depreciated on a straight-line basis over the estimated useful lives of the assets. Such assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the expected undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset. When property, plant and equipment depreciated on an individual basis is sold or otherwise disposed of, any gains or losses are reported in the condensed consolidated statements of operations and comprehensive income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of sale. If a loss on disposal is expected, such losses are generally recognized when the assets are classified as held for sale. Expenditures for routine maintenance and repair costs are expensed when incurred. Refinery process units require periodic major maintenance and repairs that are commonly referred to as “turnarounds.” Turnaround cycles vary from unit to unit but can be as short as one year for catalyst changes to as long as six years. Turnaround costs are expensed as incurred. Derivative Financial Instruments The Company is exposed to earnings and cash flow volatility due to fluctuations in crude oil, refined products, and natural gas prices. The timing of certain commodity purchases and sales also subject the Company to earnings and cash flow volatility. To manage these risks, the Company may use derivative instruments associated with the purchase or sale of crude oil, refined products, and natural gas to hedge volatility in our refining and operating margins. The Company may use futures, options, and swaps contracts to manage price risks associated with inventory quantities above or below target levels. Crack spread and crude differential futures and swaps contracts may also be used to hedge the volatility of refining margins. All derivative instruments, except for those that meet the normal purchases and normal sales exception, are recorded in the condensed consolidated balance sheets at fair value and are classified depending on the maturity date of the underlying contracts. Changes in the fair value of the Company's contracts are accounted for by marking them to market and recognizing any resulting gains or losses in the condensed consolidated statements of operations and comprehensive income. Gains and losses from derivative activity specific to managing price risk on inventory quantities both above and below target levels are included within cost of sales. Derivative gains and losses are reported as operating activities within the condensed consolidated statements of cash flows. The Company enters into crude oil forward contracts to facilitate the supply of crude oil to the refinery. These contracts may qualify for the normal purchases and normal sales exception because the Company physically receives and delivers the crude oil under the contracts and when the Company enters into these contracts, the quantities are expected to be used or sold over a reasonable period of time in the normal course of business. These transactions are reflected in the period that delivery of the crude oil takes place. When forward contracts do not qualify for the normal purchases and sales exception, the contracts are marked to market each period through the settlement date, which is generally no longer than one to three months. Renewable Identification Numbers The Company is subject to obligations to generate or purchase Renewable Identification Numbers ("RINs") required to comply with the Renewable Fuels Standard. The Company's overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by the Environmental Protection Agency ("EPA"). To the degree the Company is unable to blend the required amount of biofuels to satisfy its RINs obligation, RINs must be purchased on the open market to avoid penalties and fines. The Company records its RINs obligation on a net basis in accrued liabilities when its RINs liability is greater than the amount of RINs earned and purchased in a given period and in other current assets when the amount of RINs earned and purchased is greater than the RINs liability. In 2010 and 2011, the EPA issued partial waivers with conditions allowing a maximum of 15% ethanol to be used in certain vehicles. Future changes to existing laws and regulations could increase the minimum volumes of renewable fuels that must be blended with refined petroleum fuels. Because the Company does not produce renewable fuels, increasing the volume of renewable fuels that must be blended into its products could displace an increasing volume of the Company's refineries' product pool, potentially resulting in lower earnings and materially adversely affecting our ability to issue dividends to the Company's unitholders. The purchase price for RINs is volatile and may vary significantly from period to period. Historically, the cost of purchased RINs has not had a significant impact upon the Company's operating results. The Company anticipates 2016 will be consistent with this history. Revenue Recognition Revenues are recognized when products are shipped or services are provided to customers, title is transferred, the sales price is fixed or determinable and collectability is reasonably assured. Revenues are recorded net of discounts granted to customers. Shipping and other transportation costs billed to customers are presented on a gross basis in revenues and cost of sales. Nonmonetary product exchanges and certain buy/sell crude oil transactions, which are entered into in contemplation one with another, are included on a net cost basis in cost of sales. The Company also enters into agreements to purchase and sell crude oil to third parties and certain of these activities are recorded on a gross basis. Cost of Sales Cost of sales in the condensed consolidated statements of operations and comprehensive income excludes depreciation and amortization of refinery assets and the direct labor and overhead costs related to the operation of the refinery. These costs are included in the condensed consolidated statements of operations and comprehensive income in the depreciation and amortization and direct operating expenses line items, respectively. Excise Taxes The Company is required by various governmental authorities, including federal and state, to collect and remit taxes on certain products. Such taxes are presented on a gross basis in revenue and cost of sales in the condensed consolidated statements of operations and comprehensive income. These taxes totaled $104.6 million and $93.6 million for the three months ended September 30, 2016 and 2015 , respectively, and $323.5 million and $296.6 million for the nine months ended September 30, 2016 and 2015 , respectively. Accounting Developments In May 2014, the FASB issued ASU No. 2014-09 “Revenue from Contracts with Customers,” which provides guidance for revenue recognition. The 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. In August 2014, the FASB issued ASU No. 2015-14 which deferred the effective date of ASU 2014-09. This guidance will now be effective for the Company's financial statements in the annual period beginning after December 15, 2017. The Company is evaluating the effect of adopting this new accounting guidance and does not expect adoption will have a material impact on NTE's results of operations, cash flows or financial position. In February 2016, the FASB issued ASU No. 2016-02 “Leases,” which replaces the existing guidance in Accounting Standards Codification (“ASC”) 840. This new guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2018 with early adoption permitted. The guidance requires a dual approach for lessee accounting under which a lessee would account for leases as finance leases or operating leases. Both finance leases and operating leases will result in the lessee recognizing a right-of-use ("ROU") asset and a corresponding lease liability. For finance leases the lessee would recognize interest expense and amortization of the ROU asset and for operating leases the lessee would recognize a straight-line total lease expense. The Company is currently assessing the impact that adoption of this guidance will have on its consolidated financial statements and footnote disclosures. In March 2016, the FASB issued ASU No. 2016-04 "Liabilities – Extinguishment of Liabilities (Subtopic 405-20): Recognition of Breakage for Certain Prepaid Stored-Value Products," which aligns recognition of the financial liabilities related to prepaid stored-value products (for example, prepaid gift cards), with Topic 606, Revenues from Contracts with Customers, for non-financial liabilities. In general, 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. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements and footnote disclosures. In March 2016, the FASB issued ASU No. 2016-06 "Derivatives and Hedging (Topic 815) – Contingent Put and Call Options in Debt Instruments" which will reduce diversity of practice in identifying embedded derivatives in debt instruments. ASU 2016-06 clarifies that 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. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements and footnote disclosures. In March 2016, the FASB issued ASU No. 2016-08 "Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)," which clarifies the implementation guidance on principal versus agent considerations. The guidance includes indicators to assist an entity in determining whether it controls a specified good or service before it is transferred to the customers. The effective date and transition requirements for the amendments in this Update are the same as the effective date and transition requirements of ASU 2014-09. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements and footnote disclosures. In March 2016, the FASB issued ASU No. 2016-09 "Compensation – Stock Compensation," which identifies areas for simplification involving several aspects of accounting for equity-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, an option to recognize gross stock compensation expense with actual forfeitures recognized as they occur, as well as certain classifications on the statement of cash flows. 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. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements and footnote disclosures. In August 2016, the FASB issued ASU No. 2016-15 "Classification of Certain Cash Receipts and Cash Payments," which provides guidance on presentation in the statement of cash flows on eight subject areas where there current GAAP either is unclear or does not include specific guidance, resulting in diversity in practice. 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. The Company is currently assessing the impact that adopting this new accounting standard will have on its consolidated financial statements and footnote disclosures.

Segment Information (Notes)

Segment Information (Notes)	9 Months Ended
	Sep. 30, 2016
Segment Reporting Information [Line Items]
Segment Information	3. Segment Information We have organized our operations into three segments, refining, WNRL and retail, based on manufacturing and marketing processes, the nature of our products and services and each segment's respective customer base. Prior to the Merger on June 23, 2016, we also reported NTI as a separate reportable segment. Following the completion of the Merger, NTI became a wholly-owned subsidiary of Western and, as a result, we have moved its assets and operations into our other reportable segments. Beginning on July 1, 2016, our management team, led by our chief operating decision maker, began monitoring our business and allocating resources based on these three reportable segments. The St. Paul Park refinery and related operations are now included in the refining segment and the SuperAmerica retail and bakery assets and operations are now included in the retail segment. We have retrospectively adjusted the historical segment financial data for the periods presented to reflect our revised segment presentation. We treated the St. Paul Park Logistics Assets and the TexNew Mex Pipeline System that we sold to WNRL 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. We moved the St. Paul Park Logistics Assets and the TexNew Mex Pipeline System from the refining segment to the WNRL segment. Business Segments and Principal Products Refining . Our refining segment includes the operations of three refineries. The El Paso refinery in El Paso, Texas, has a throughput capacity of 131,000 barrels per day ("bpd"), the Gallup refinery, near Gallup, New Mexico has a 25,000 bpd capacity and the St. Paul Park refinery, in St. Paul Park, Minnesota has a 98,000 bpd capacity. Our refineries produce 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 third-party suppliers. We also acquire refined products through exchange agreements and from 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, through 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 $4.0 million and $1.8 million in assets at September 30, 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 $6.1 million and $23.3 million in net hedging gains for the three months ended September 30, 2016 and 2015 , respectively, and gains of $32.1 million and $39.3 million for the nine months ended September 30, 2016 and 2015 , respectively. This supply agreement is due to expire at the end of 2016. WNRL. WNRL owns and operates pipeline and gathering, terminalling, storage and transportation assets that provide logistics services to our refining segment in the Southwest and Upper Great Plains regions, including 692 miles of pipelines and 12.4 million barrels of active storage capacity. The majority of WNRL's logistics assets are integral to the operations of the El Paso, Gallup and St. Paul Park 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, asphalt 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 retail segment operates retail networks located in the Southwest region (" Southwest Retail ") and the Upper Great Plains region of the U.S. (" SuperAmerica "). Each of our retail networks sell various grades of gasoline, diesel fuel, convenience store merchandise and beverage and food products to the general public through retail convenience stores. Southwest Retail obtains the majority of its gasoline and diesel fuel supply from WNRL and purchases general merchandise and beverage and food products from various third-party suppliers. At September 30, 2016 , Southwest Retail operated 260 service stations and convenience stores located in Arizona, Colorado, New Mexico and Texas compared to 261 service stations and convenience stores at September 30, 2015 . In addition to its service stations and convenience stores, Southwest Retail sells various grades of gasoline and diesel fuel to commercial vehicle fleets through unmanned fleet fueling sites ("cardlocks"). At September 30, 2016 and 2015 , respectively, Southwest Retail operated 51 and 52 cardlocks located in Arizona, California, Colorado, New Mexico and Texas. As of September 30, 2016 , SuperAmerica operated 170 retail convenience stores and supported the operations of 115 franchised retail convenience stores primarily in Minnesota and Wisconsin, compared to 165 and 102 at September 30, 2015 . SuperAmerica obtains the majority of its gasoline and diesel for its Minnesota and Wisconsin retail convenience stores from the St. Paul Park refinery. 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 segment also includes 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 three 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 three operating segments. We do not allocate certain items of other income and expense, including income taxes, to the individual segments. 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 and nine months ended September 30, 2016 and 2015 , are presented below: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Operating Results: Refining (2) Net sales $ 1,835,327 $ 2,318,048 $ 5,012,283 $ 6,958,443 Intersegment eliminations 736,020 843,674 2,075,758 2,403,438 Net refining sales to external customers 1,099,307 1,474,374 2,936,525 4,555,005 WNRL (2) Net sales 569,261 680,670 1,615,902 2,023,970 Intersegment eliminations 183,154 216,959 513,101 607,249 Net WNRL sales to external customers 386,107 463,711 1,102,801 1,416,721 Retail Net sales 597,621 633,793 1,610,033 1,753,503 Intersegment eliminations 17,959 2,788 21,471 8,517 Net retail sales to external customers 579,662 631,005 1,588,562 1,744,986 Consolidated net sales to external customers $ 2,065,076 $ 2,569,090 $ 5,627,888 $ 7,716,712 Operating income (loss) Refining (1) (2) $ 89,158 $ 312,602 $ 338,803 $ 900,405 WNRL (2) 13,271 18,424 43,056 41,454 Retail 11,832 24,937 21,193 36,356 Other (27,318 ) (23,365 ) (74,010 ) (74,231 ) Operating income from segments 86,943 332,598 329,042 903,984 Other income (expense), net (30,935 ) (22,383 ) (73,804 ) (67,062 ) Consolidated income before income taxes $ 56,008 $ 310,215 $ 255,238 $ 836,922 Depreciation and amortization Refining (2) $ 37,265 $ 35,400 $ 111,601 $ 105,916 WNRL (2) 10,579 8,963 29,470 25,816 Retail 5,710 5,846 17,622 17,257 Other 767 1,168 2,638 3,457 Consolidated depreciation and amortization $ 54,321 $ 51,377 $ 161,331 $ 152,446 Capital expenditures Refining (2) $ 65,909 $ 61,399 $ 200,681 $ 127,914 Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) WNRL (2) 8,530 10,648 24,378 52,150 Retail 3,593 3,903 8,528 13,175 Other 305 481 1,510 2,737 Consolidated capital expenditures $ 78,337 $ 76,431 $ 235,097 $ 195,976 Total assets Refining (2) (including $1,267,455 of goodwill) $ 4,394,967 $ 3,574,746 WNRL (2) 528,554 601,215 Retail (including $21,988 of goodwill) 430,363 430,147 Other 361,241 1,234,285 Consolidated total assets $ 5,715,125 $ 5,840,393 (1) The effect of our economic hedging activity is included within the operating income of our refining segment as a component of cost of products sold. The cost of products sold within our refining segment included $0.1 million in net realized and unrealized economic hedging gains for the three months ended September 30, 2016 , $8.6 million in net realized and unrealized economic hedging losses for the nine months ended September 30, 2016 , respectively, and $27.2 million and $10.3 million in net realized and unrealized economic hedging gains for the three and nine months ended September 30, 2015 , respectively. Also included within cost of products sold for our refining segment is the net effect of non-cash LCM recoveries of $15.2 million and $102.5 million for the three and nine months ended September 30, 2016 , respectively, charges of $36.8 million for the three months ended September 30, 2015 and recoveries of $17.1 million for the nine months ended September 30, 2015 . (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 and nine months ended September 30, 2015 . The information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the St. Paul Park Logistics Assets and the TexNew Mex Pipeline System .
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Segment Information	. SEGMENT INFORMATION The Company has two reportable operating segments: Refining and Retail. Each of these segments is organized and managed based upon the nature of the products and services they offer. The segment disclosures reflect management’s current organizational structure. • Refining – operates the St. Paul Park, Minnesota refinery, terminal, NTOT and related assets, and includes the Company’s interest in MPL and MPLI, and • Retail – operates 170 convenience stores primarily in Minnesota and Wisconsin. The retail segment also includes the operations of NTB and SAF. Operating results for the Company’s operating segments are as follows: Three Months Ended September 30, 2016 (in millions) Refining Retail Other Total Revenues Customer $ 452.7 $ 279.6 $ — $ 732.3 Intersegment 154.1 — — 154.1 Segment revenues 606.8 279.6 — 886.4 Elimination of intersegment revenues — — (154.1 ) (154.1 ) Total revenues $ 606.8 $ 279.6 $ (154.1 ) $ 732.3 Income (loss) from operations $ 14.4 $ 4.4 $ (7.2 ) $ 11.6 Income from equity method investment $ 5.3 $ — $ — $ 5.3 Depreciation and amortization $ 9.7 $ 2.2 $ 0.2 $ 12.1 Capital expenditures $ 42.8 $ 1.6 $ 0.1 $ 44.5 Three Months Ended September 30, 2015 (in millions) Refining Retail Other Total Revenues Customer $ 584.0 $ 307.6 $ — $ 891.6 Intersegment 178.3 — — 178.3 Segment revenues 762.3 307.6 — 1,069.9 Elimination of intersegment revenues — — (178.3 ) (178.3 ) Total revenues $ 762.3 $ 307.6 $ (178.3 ) $ 891.6 Income (loss) from operations $ 111.1 $ 8.6 $ (5.1 ) $ 114.6 Income from equity method investment $ 4.2 $ — $ — $ 4.2 Depreciation and amortization $ 8.8 $ 2.0 $ 0.2 $ 11.0 Capital expenditures $ 16.4 $ 1.1 $ — $ 17.5 Nine Months Ended September 30, 2016 (in millions) Refining Retail Other Total Revenues Customer $ 1,373.3 $ 775.7 $ — $ 2,149.0 Intersegment 419.0 — — 419.0 Segment revenues 1,792.3 775.7 — 2,568.0 Elimination of intersegment revenues — — (419.0 ) (419.0 ) Total revenues $ 1,792.3 $ 775.7 $ (419.0 ) $ 2,149.0 Income (loss) from operations $ 124.6 $ 9.2 $ (22.7 ) $ 111.1 Income from equity method investment $ 15.3 $ — $ — $ 15.3 Depreciation and amortization $ 27.9 $ 6.5 $ 0.6 $ 35.0 Capital expenditures $ 95.7 $ 3.2 $ 0.3 $ 99.2 Nine Months Ended September 30, 2015 (in millions) Refining Retail Other Total Revenues Customer $ 1,789.7 $ 855.5 $ — $ 2,645.2 Intersegment 502.0 — — 502.0 Segment revenues 2,291.7 855.5 — 3,147.2 Elimination of intersegment revenues — — (502.0 ) (502.0 ) Total revenues $ 2,291.7 $ 855.5 $ (502.0 ) $ 2,645.2 Income (loss) from operations $ 374.7 $ 16.9 $ (18.2 ) $ 373.4 Income from equity method investment $ 12.0 $ — $ — $ 12.0 Depreciation and amortization $ 26.3 $ 5.7 $ 0.6 $ 32.6 Capital expenditures $ 30.7 $ 4.2 $ 0.3 $ 35.2 Intersegment sales from the refining segment to the retail segment consist primarily of sales of refined products which are recorded based on contractual prices that are market-based. Revenues from external customers are nearly all in the United States. Total assets by segment were as follows: (in millions) Refining Retail Other Total At September 30, 2016 $ 1,266.8 $ 132.0 $ 23.5 $ 1,422.3 At December 31, 2015 $ 917.4 $ 138.7 $ 81.2 $ 1,137.3 Total assets for the refining and retail segments exclude all intercompany balances. All cash and cash equivalents are included in Other. All property, plant and equipment are located in the United States.

Fair Value Measurement (Notes)

Fair Value Measurement (Notes)	9 Months Ended
	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurement	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. 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 September 30, 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 $0.02 million and $70.1 million consisting of short-term money market deposits and commercial paper were included in the Condensed Consolidated Balance Sheets as of September 30, 2016 and December 31, 2015 , respectively. 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 September 30, 2016 and December 31, 2015 , and the basis for that measurement: Carrying Value at September 30, 2016 Fair Value Measurement Using Netting Adjustments Recorded Value at September 30, 2016 Level 1 Level 2 Level 3 (In thousands) Gross financial assets: Other current assets $ 34,060 $ — $ 34,060 $ — $ (7,303 ) $ 26,757 Other assets 4,455 — 4,455 — (1,604 ) 2,851 Gross financial liabilities: Accrued liabilities (10,449 ) — (9,688 ) (761 ) 5,992 (4,457 ) Other long-term liabilities (3,068 ) — (3,068 ) — 2,915 (153 ) $ 24,998 $ — $ 25,759 $ (761 ) $ — $ 24,998 Carrying Value at December 31, 2015 Fair Value Measurement Using Netting Adjustments Recorded Value at December 31, 2015 Level 1 Level 2 Level 3 (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. 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 and nine months ended September 30, 2016 and 2015 . Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Asset (liability) balance at beginning of period $ (1,951 ) $ 1,614 $ (5,756 ) $ 330 Change in fair value 237 (2,505 ) 537 — Fair value of trades entered into during the period — — — (1,262 ) Fair value reclassification from Level 3 to Level 2 953 (288 ) 4,458 (247 ) Liability balance at end of period $ (761 ) $ (1,179 ) $ (761 ) $ (1,179 ) A hypothetical change of 10% to the estimated future cash flows attributable to our Level 3 commodity price swaps would result in a $0.1 million change in the estimated fair value at September 30, 2016 . As of September 30, 2016 and December 31, 2015 , the carrying amount and estimated fair value of our debt was as follows: September 30, December 31, (In thousands) Western obligations: Carrying amount $ 1,383,625 $ 889,000 Fair value 1,380,125 867,178 NTI obligations: Carrying amount $ 402,000 $ 350,000 Fair value 412,500 360,500 WNRL obligations: Carrying amount $ 320,300 $ 445,000 Fair value 330,800 439,000 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).
Northern Tier Energy LP [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurement	. FAIR VALUE MEASUREMENTS As defined in GAAP, fair value is the price that would be received for the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP describes three approaches to measuring the fair value of assets and liabilities: the market approach, the income approach and the cost approach, each of which includes multiple valuation techniques. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. The income approach uses valuation techniques to measure fair value by converting future amounts, such as cash flows or earnings, into a single present value amount using current market expectations about those future amounts. The cost approach is based on the amount that would currently be required to replace the service capacity of an asset. This is often referred to as current replacement cost. The cost approach assumes that the fair value would not exceed what it would cost a market participant to acquire or construct a substitute asset of comparable utility, adjusted for obsolescence. Accounting guidance does not prescribe which valuation technique should be used when measuring fair value and does not prioritize among the techniques. Accounting guidance establishes a fair value hierarchy that prioritizes the inputs used in applying the various valuation techniques. Inputs broadly refer to the assumptions that market participants use to make pricing decisions, including assumptions about risk. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The three levels of the fair value hierarchy are as follows: • Level 1 – Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 – Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. • Level 3 – Unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value. The Company uses a market or income approach for recurring fair value measurements and endeavors to use the best information available. Accordingly, valuation techniques that maximize the use of observable inputs are favored. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. The Company’s current asset and liability accounts contain certain financial instruments, the most significant of which are trade accounts receivables and trade payables. The Company believes the carrying values of its current assets and liabilities approximate fair value. The Company’s fair value assessment incorporates a variety of considerations, including the short-term duration of the instruments, the Company’s historical incurrence of insignificant bad debt expense and the Company’s expectation of future insignificant bad debt expense, which includes an evaluation of counterparty credit risk. The following table provides the assets and liabilities carried at fair value measured on a recurring basis at September 30, 2016 and December 31, 2015 : Balance at Quoted prices in active markets Significant other observable inputs Unobservable inputs (in millions) September 30, 2016 (Level 1) (Level 2) (Level 3) ASSETS Cash and cash equivalents $ 14.6 $ 14.6 $ — $ — Restricted cash 195.0 195.0 — — Other current assets Derivative asset - current 4.1 — 4.1 — Other assets Derivative asset - long-term 0.6 — 0.6 — $ 214.3 $ 209.6 $ 4.7 $ — LIABILITIES Accrued liabilities Derivative liability - current $ 6.1 $ — $ 6.1 $ — $ 6.1 $ — $ 6.1 $ — Balance at Quoted prices in active markets Significant other observable inputs Unobservable inputs (in millions) December 31, 2015 (Level 1) (Level 2) (Level 3) ASSETS Cash and cash equivalents $ 70.9 $ 70.9 $ — $ — Other current assets Derivative asset - current 1.9 — 1.9 — $ 72.8 $ 70.9 $ 1.9 $ — LIABILITIES Accrued liabilities Derivative liability - current $ 9.4 $ — $ 9.4 $ — $ 9.4 $ — $ 9.4 $ — As of both September 30, 2016 and December 31, 2015 , the Company had no Level 3 fair value assets or liabilities. The Company’s policy is to recognize transfers in and transfers out as of the actual date of the event or of the change in circumstances that caused the transfer. For the nine months ended September 30, 2016 and 2015 , there were no transfers in or out of Levels 1, 2 or 3. Assets not recorded at fair value on a recurring basis, such as property, plant and equipment, intangible assets and cost method investments, are recognized at fair value when they are impaired. During the nine months ended September 30, 2016 and 2015 , there were no impairments of such assets. The carrying value of debt, which is reported on the Company’s condensed consolidated balance sheets, reflects the cash proceeds received upon issuance, net of subsequent repayments. The fair value of the 2020 Secured Notes disclosed below was determined based on quoted prices in active markets (Level 1). September 30, 2016 December 31, 2015 (in millions) Carrying Amount Fair Value Carrying Amount Fair Value 2020 Secured Notes $ 350.0 $ 360.5 $ 350.0 $ 360.5 Outstanding borrowings on ABL Facility 52.0 52.0 — — Total $ 402.0 $ 412.5 $ 350.0 $ 360.5

Inventories (Notes)

Inventories (Notes)	9 Months Ended
	Sep. 30, 2016
Inventory [Line Items]
Inventory Disclosure [Text Block]	5. Inventories Inventories were as follows: September 30, December 31, (In thousands) Refined products (1) $ 259,125 $ 201,928 Crude oil and other raw materials 348,109 288,403 Lubricants 11,118 14,996 Retail store merchandise 42,386 42,211 Inventories $ 660,738 $ 547,538 (1) Includes $15.8 million and $14.5 million of refined products inventory valued using the first-in, first-out ("FIFO") valuation method at September 30, 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 in Southwest Retail, 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. In our retail segment, refined product inventory is valued using the FIFO inventory valuation method for Southwest Retail and the LIFO inventory valuation method for SuperAmerica. Retail merchandise inventory is valued using the retail inventory method. As of September 30, 2016 and December 31, 2015 , refined products valued under the LIFO method and crude oil and other raw materials totaled 10.4 million barrels and 10.0 million barrels, respectively. At September 30, 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 $193.3 million and $198.4 million , respectively. During the three months ended September 30, 2016 and 2015 , cost of products sold included net non-cash recoveries of $79.5 million and $105.0 million , respectively, from changes in our LIFO reserves. During the nine months ended September 30, 2016 and 2015 , cost of products sold included net non-cash charges of $5.1 million and net non-cash recoveries of $129.0 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 $72.6 million and $175.1 million at September 30, 2016 and December 31, 2015 , respectively. These non-cash LCM recoveries decreased cost of products sold by $15.2 million and $102.5 million for the three and nine months ended September 30, 2016 , respectively, and by $17.1 million for the nine months ended September 30, 2015 . The non-cash LCM charge for the three months ended September 30, 2015 , increased cost of products sold by $36.8 million . Average LIFO cost per barrel of our refined products and crude oil and other raw materials inventories as of September 30, 2016 and December 31, 2015 , were as follows: September 30, 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 4,033 $ 279,917 $ 69.41 3,536 $ 259,722 $ 73.45 Crude oil and other 6,348 384,067 60.50 6,490 391,237 60.28 10,381 $ 663,984 63.96 10,026 $ 650,959 64.93
Northern Tier Energy LP [Member]
Inventory [Line Items]
Inventory Disclosure [Text Block]	. INVENTORIES September 30, December 31, (in millions) 2016 2015 Crude oil and refinery feedstocks $ 158.8 $ 171.8 Refined products 161.6 162.0 Merchandise 22.6 22.8 Supplies and sundry items 20.1 19.0 363.1 375.6 Lower of cost or market inventory reserve (72.6 ) (134.4 ) Total $ 290.5 $ 241.2 Inventories accounted for under the LIFO method comprised 88% and 89% of the total inventory value at September 30, 2016 and December 31, 2015 , respectively, prior to the application of the lower of cost or market reserve. In order to state the Company's inventories at market values that were lower than its LIFO costs, the Company reduced the carrying values of its inventory through LCM reserves of $72.6 million and $134.4 million at September 30, 2016 and December 31, 2015 , respectively.

Equity Method Investment (Notes

Equity Method Investment (Notes)	9 Months Ended
	Sep. 30, 2016
Schedule of Equity Method Investments [Line Items]
Equity Method Investment [Text Block]	6. Equity Method Investment We own a 17% common equity interest in Minnesota Pipe Line Company, LLC ("MPL"). The carrying value of this equity method investment was $98.2 million and $97.5 million at September 30, 2016 and December 31, 2015 , respectively. As of September 30, 2016 and December 31, 2015 , the carrying amount of the equity method investment was $21.2 million and $21.3 million , respectively, 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 distributions from MPL during the three and nine months ended September 30, 2016 and 2015 , of $10.2 million , $14.5 million , $4.2 million and $10.0 million , respectively. Equity income from MPL for the three and nine months ended September 30, 2016 and 2015 , was $5.3 million , $15.3 million , $4.2 million and $12.0 million , respectively. Equity income has been included in other, net in the accompanying Condensed Consolidated Statements of Operations.
Northern Tier Energy LP [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment [Text Block]	. EQUITY METHOD INVESTMENTS The Company has a 17% common equity interest in MPL. Additionally, in the third quarter of 2016, the Company received a 1.0% common equity interest in WNRL in connection with the Contribution Agreement (see Note 3 ), which was recorded at its historical cost given the transaction was treated as a transfer of assets under common control. The carrying value of these equity method investments was $82.8 million and $82.1 million at September 30, 2016 and December 31, 2015 , respectively. As of September 30, 2016 and December 31, 2015 , the carrying amount of the equity method investment in MPL was $5.8 million and $5.9 million higher, respectively, than the underlying net assets of the investee, respectively. The Company is amortizing this difference over the remaining life of MPL’s primary asset (the fixed asset life of the pipeline). The Company recorded $10.2 million and $4.2 million in distributions from its equity method investments in the three months ended September 30, 2016 and 2015 , respectively, and $14.5 million and $10.0 million , respectively, for the nine months ended September 30, 2016 and 2015 . At September 30, 2015, $4.2 million of these distributions were declared but unpaid. Equity income from the Company's equity method investments was $5.3 million and $4.2 million for the three months ended September 30, 2016 and 2015 , respectively, and $15.3 million and $12.0 million for the nine months ended September 30, 2016 and 2015 , respectively.

Property, Plant and Equipment,

Property, Plant and Equipment, Net (Notes)	9 Months Ended
	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Property, Plant, and Equipment, Net	7. Property, Plant and Equipment, Net Property, plant and equipment, net was as follows: September 30, December 31, (In thousands) Refinery facilities and related equipment $ 2,198,560 $ 2,113,650 Pipelines, terminals and transportation equipment 553,402 427,854 Retail facilities and related equipment 327,898 324,686 Wholesale facilities and related equipment 53,190 59,875 Corporate 52,105 50,607 3,185,155 2,976,672 Accumulated depreciation (1,070,501 ) (923,415 ) 2,114,654 2,053,257 Construction in progress 242,637 251,914 Property, plant and equipment, net $ 2,357,291 $ 2,305,171 Depreciation expense was $53.3 million and $158.1 million for the three and nine months ended September 30, 2016 , respectively, and $50.4 million and $149.3 million for the three and nine months ended September 30, 2015 , respectively.
Northern Tier Energy LP [Member]
Property, Plant and Equipment [Line Items]
Property, Plant, and Equipment, Net	. PROPERTY, PLANT AND EQUIPMENT Major classes of property, plant and equipment (“PP&E”) consisted of the following: Estimated September 30, December 31, (in millions) Useful Lives 2016 2015 Land $ 7.1 $ 9.0 Retail stores and equipment 2 - 22 years 76.6 72.3 Refinery and equipment 5 - 24 years 431.6 457.2 Buildings and building improvements 25 years 13.0 11.7 Software 5 years 18.9 18.9 Vehicles 5 years 5.8 5.6 Other equipment 2 - 7 years 12.0 10.4 Precious metals 10.4 10.2 Assets under construction 119.1 73.3 694.5 668.6 Less: Accumulated depreciation (190.2 ) (180.8 ) Property, plant and equipment, net $ 504.3 $ 487.8 PP&E includes gross assets acquired under capital leases of $10.8 million and $13.3 million at September 30, 2016 and December 31, 2015 , respectively, with related accumulated depreciation of $2.1 million and $2.0 million , respectively. The Company had depreciation expense related to capitalized software of $0.8 million and $0.9 million for the three months ended September 30, 2016 and 2015 , respectively, and $2.8 million for both the nine months ended September 30, 2016 and 2015 . The Company capitalized interest expense related to capital projects within the refining segment of $2.0 million and zero for the three months ended September 30, 2016 and 2015 , respectively, and $4.9 million and zero for the nine months ended September 30, 2016 and 2015 .

Intangible Assets, Net (Notes)

Intangible Assets, Net (Notes)	9 Months Ended
	Sep. 30, 2016
Indefinite-lived Intangible Assets [Line Items]
Intangible Assets, Net	8. Intangible Assets, Net Intangible assets, net was as follows: September 30, 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 (In thousands) Amortizable assets: Licenses and permits $ 20,427 $ (14,913 ) $ 5,514 $ 20,427 $ (13,729 ) $ 6,698 3.5 Customer relationships 7,172 (4,102 ) 3,070 7,551 (3,921 ) 3,630 5.8 Rights-of-way and other 7,889 (2,388 ) 5,501 6,839 (1,797 ) 5,042 5.5 35,488 (21,403 ) 14,085 34,817 (19,447 ) 15,370 Unamortizable assets: Franchise rights and trademarks 50,500 — 50,500 50,500 — 50,500 Liquor licenses 19,958 — 19,958 19,075 — 19,075 Intangible assets, net $ 105,946 $ (21,403 ) $ 84,543 $ 104,392 $ (19,447 ) $ 84,945 Intangible asset amortization expense for the three and nine months ended September 30, 2016 , was $0.7 million and $2.2 million , respectively, based on estimated useful lives ranging from 1 to 35 years. Intangible asset amortization expense for the three and nine months ended September 30, 2015 , was $0.7 million and $2.1 million , respectively, 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 $ 720 2017 2,880 2018 2,880 2019 2,212 2020 1,268 2021 980
Northern Tier Energy LP [Member]
Indefinite-lived Intangible Assets [Line Items]
Intangible Assets, Net	. INTANGIBLE ASSETS Intangible assets are comprised of franchise rights and trade names amounting to $33.8 million at both September 30, 2016 and December 31, 2015 . At both September 30, 2016 and December 31, 2015 , the franchise rights and trade name intangible asset values were $12.4 million and $21.4 million , respectively. These assets have an indefinite life and are not amortized, but rather are tested for impairment annually or when events or changes in circumstances indicate that the fair value of the intangible asset has been reduced below carrying value. Based on the testing performed as of June 30, 2016, the Company noted no indications of impairment.

Long-Term Debt (Notes)

Long-Term Debt (Notes)	9 Months Ended
	Sep. 30, 2016
Debt Instrument [Line Items]
Long-Term Debt	9. Long-Term Debt Long-term debt was as follows: September 30, December 31, (In thousands) Western obligations: Revolving Credit Facility due 2019 $ — $ — Term Loan - 5.25% Credit Facility due 2020 534,875 539,000 6.25% Senior Unsecured Notes due 2021 350,000 350,000 Term Loan - 5.50% Credit Facility due 2023 498,750 — Total Western obligations 1,383,625 889,000 NTI obligations: Revolving Credit Facility due 2019 52,000 — 7.125% Senior Secured Notes due 2020 350,000 350,000 Total NTI obligations 402,000 350,000 WNRL obligations: Revolving Credit Facility due 2018 20,300 145,000 7.5% Senior Notes due 2023 300,000 300,000 Total WNRL obligations 320,300 445,000 Less unamortized discount, premium and debt issuance costs 50,245 33,606 Long-term debt 2,055,680 1,650,394 Current portion of long-term debt (10,500 ) (5,500 ) Long-term debt, net of current portion $ 2,045,180 $ 1,644,894 As of September 30, 2016 , annual maturities of long-term debt for the remainder of 2016 are $2.6 million . For 2017, 2018, 2019 and 2020, long-term debt maturities are $10.5 million , $30.8 million , $62.5 million and $872.0 million , respectively. Thereafter, total long-term debt maturities are $1,127.5 million . Interest and debt expense were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Contractual interest: Western obligations $ 20,475 $ 12,150 $ 45,606 $ 36,250 NTI obligations 6,918 6,970 20,707 20,173 WNRL obligations 6,039 5,854 19,144 15,481 33,432 24,974 85,457 71,904 Amortization of loan fees 2,479 1,932 6,395 5,630 Amortization of original issuance discount 381 — 410 — Other interest expense 1,287 747 3,727 2,973 Capitalized interest (3,123 ) (757 ) (7,924 ) (1,338 ) Interest and debt expense $ 34,456 $ 26,896 $ 88,065 $ 79,169 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. Western Obligations Revolving Credit Facility On May 27, 2016, we entered into the Second Amendment to the Third Amended and Restated Revolving Credit Agreement (the "Western 2019 Revolving Credit Facility"). The Revolving Credit Amendment amended the Western 2019 Revolving Credit Facility by, among other things, (i) permitting us to incur up to $500.0 million of additional secured indebtedness secured on a pari passu basis with the loans under the Western 2020 Term Loan Credit Facility (in the form of incremental term loans or bonds secured on a pari passu basis with the term loans) beyond what was permitted under the Western 2019 Revolving Credit Facility and (ii) modifying several triggers and thresholds based on borrowing availability under the Western 2019 Revolving Credit Facility. On October 2, 2014, we entered into the Third Amended and Restated Revolving Credit Agreement. 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 nine month period ended September 30, 2016 , we had no direct borrowings under the Western 2019 Revolving Credit Facility, with availability of $257.0 million at September 30, 2016 . This availability is net of $100.1 million in outstanding letters of credit. Term Loan Credit Agreement - 5.25% 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. On May 27, 2016, the Company entered into a third amendment of the Western 2020 Term Loan Credit Facility. The revised terms under the amendment provide for additional capacity to make restricted payments including dividends and repurchase of the Company’s outstanding common stock, inclusion of equity interests of master limited partnership subsidiaries as “replacement assets” for purposes of asset sale mandatory prepayment and changes to the use of proceeds of the incremental term loan available under the Term Loan. The third amendment also increased the incremental availability under the Western 2020 Term Loan Credit Facility from $200.0 million , prior to the amendment, to $700.0 million . Following the third amendment, 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 LIBOR Rate (as defined in the Western 2020 Term Loan Credit Facility) plus 4.25% (subject to a LIBOR Rate floor of 1.00% ). The current interest rate based on these criteria is 5.25% . Our effective rate of interest, including contractual interest and amortization of loan fees, for the Western 2020 Term Loan Credit Facility was 5.80% as of September 30, 2016 . The Western 2020 Term Loan Credit Facility is secured by the El Paso and Gallup refineries and the equity of NT InterHoldCo LLC, a wholly-owned subsidiary of Western, and is fully and unconditionally guaranteed on a joint and several basis by certain 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 certain 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, including contractual interest and amortization of loan fees, for the Western 2021 Senior Unsecured Notes was 6.52% as of September 30, 2016 . See Note 20, Condensed Consolidating Financial Information for further discussion. Term Loan Credit Agreement - 5.50% On June 23, 2016, as an incremental supplement to the Western 2020 Term Loan Credit Facility, we incurred $500.0 million in new term debt that matures on June 23, 2023 (the " Western 2023 Term Loan Credit Facility "). The proceeds from the Western 2023 Term Loan Credit Facility were net of original issue discount and other fees totaling $17.0 million . We used these proceeds to partially fund the cash portion of the Merger consideration. The Western 2023 Term Loan Credit Facility provides for quarterly principal payments of $1.3 million payable on the last business day of each March, June, September and December, with the remaining principal amount due on June 23, 2023. The Western 2023 Term Loan Credit Facility is secured by both the El Paso and Gallup refineries and by the equity of NT InterHoldCo LLC and is fully and unconditionally guaranteed on a joint and several basis by certain of Western's material wholly-owned subsidiaries. The Western 2023 Term Loan Credit Facility bears interest at a rate based either on the base rate plus 3.50% or the LIBOR Rate plus 4.50% (subject to a LIBOR Rate floor of 1.00% ). The effective rate of interest, including contractual interest and amortization of original issue discount and other loan fees, for the Western 2023 Term Loan Credit Facility was 5.99% as of September 30, 2016 . 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 its general partner, Northern Tier Energy GP LLC ("NTI LLC"), and certain of its subsidiaries that are borrowers thereunder 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. At September 30, 2016 , the availability under the NTI Revolving Credit Facility was $205.7 million . This availability is net of $52.0 million in direct borrowings and $47.6 million in outstanding letters of credit. The effective rate of interest, including contractual interest and amortization of loan fees, for the NTI Revolving Credit Facility was 5.91% as of September 30, 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 "). On October 17, 2016, NTI commenced a tender offer to repurchase for cash up to $195.0 million aggregate principal amount of the NTI 2020 Secured Notes . The tender offer expires on November 15, 2016. 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 . The issuance premium will be amortized to interest expense over the remaining life of the notes. The effective rate of interest, including contractual interest and amortization of debt premium and of loan fees, for the NTI 2020 Secured Notes was 6.91% as of September 30, 2016 . The obligations under the NTI 2020 Secured Notes are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by NTI 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"). On September 15, 2016, in connection with the St. Paul Park Logistics Transaction , WNRL entered into an agreement to increase the total commitment of the WNRL Revolving Credit Facility (the "Amendment") to $500.0 million . WNRL has the ability to increase the total commitment of the WNRL Revolving Credit Facility by up to $150.0 million for a total facility size of up to $650.0 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. In addition to the increased facility size, the Amendment amended the WNRL Revolving Credit Facility by, among other things, (a) adding an anti-cash hoarding provision and (b) permitting WNRL to increase the total leverage ratio permitted thereunder from 4.50 : 1.00 to 5.00 : 1.00 following any material permitted acquisition through the last day of the second full fiscal quarter following such acquisition. The incremental commitments established by the Amendment benefit from the same covenants, events of default, guarantees and security as the existing commitments under the WNRL Revolving Credit Facility. 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 and WNRL repaid its outstanding direct borrowings under the WNRL Revolving Credit Facility on February 11, 2015, 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. During the nine months ended September 30, 2016 , WNRL repaid $179.1 million of its outstanding direct borrowings under the WNRL Revolving Credit Facility using the proceeds generated through our equity issuances during the period. On September 15, 2016 , to partially fund the purchase of the St. Paul Park Logistics Assets , WNRL borrowed $20.3 million 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 September 30, 2016 , the availability under the WNRL Revolving Credit Facility was $479.0 million , net of $20.3 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 September 30, 2016 . The interest rate for the borrowings under the WNRL Revolving Credit Facility was 4.50% as of September 30, 2016 . The effective rate of interest, including contractual interest and amortization of loan fees, for the WNRL Revolving Credit Facility was 3.34% as of September 30, 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, including contractual interest and amortization of loan fees, for the 7.5% Senior Notes was 7.78% as of September 30, 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 7.5% Senior Notes to be due and payable immediately.
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Long-Term Debt	. DEBT ABL Facility On September 29, 2014, NTE LLC and its subsidiaries entered into an amended and restated asset-based ABL Facility with JPMorgan Chase Bank, N.A., as administrative agent for the lenders and as collateral agent for the other secured parties (the "ABL Facility"). The borrowers under the ABL Facility are SPPR, NTB, NTR and SAF, each of which is a wholly owned subsidiary of NTE LLC. Lenders under the ABL Facility hold commitments totaling $500 million , which is subject to a borrowing base comprised of eligible accounts receivable and inventory. The ABL 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). The ABL Facility matures on September 29, 2019. The Company incurred financing costs associated with the new ABL Facility of $3.0 million which will be amortized to Interest expense, net through the date of maturity. The ABL Facility is guaranteed, on a joint and several basis, by NTE LLC and its subsidiaries and will be guaranteed by any newly acquired or formed subsidiaries, subject to certain limited exceptions. The ABL Facility and such guarantees are secured on a first priority basis by substantially all of NTE LLC's and such subsidiaries’ cash and cash equivalents, accounts receivable and inventory and on a second priority basis by NTE LLC's and such subsidiaries’ fixed assets (other than real property). 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 ABL 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 September 30, 2016 , the borrowing base under the ABL Facility was $305.3 million and availability under the ABL Facility was $205.7 million . This availability is net of $52.0 million in direct borrowings and $47.6 million in outstanding letters of credit. The borrowers under the ABL Facility had $52.0 million in borrowings under the ABL Facility at September 30, 2016 , located in Long-term debt on the condensed consolidated balance sheet. 2020 Secured Notes As of September 30, 2016 and December 31, 2015 , the Company had $350.0 million of outstanding aggregate principal of our 7.125% senior secured notes due 2020 (the “2020 Secured Notes”). A portion of these notes were issued with an offering premium of $4.2 million , which is being amortized to Interest expense, net over the remaining term of the notes. Additionally, professional service costs were incurred in both the issuance of the 2020 Secured Notes and the establishment of the ABL Facility which are presented within Long-term debt in the condensed consolidated balance sheets. The carrying value of these costs at September 30, 2016 and December 31, 2015 , was $9.5 million and $11.6 million , respectively. The 2020 Secured Notes are guaranteed, jointly and severally, on a senior secured basis by all of the Company’s existing and future 100% direct and indirect subsidiaries on a full and unconditional basis; however, there are certain obligations not guaranteed on a full and unconditional basis as a result of subsidiaries being released as guarantors. A subsidiary guarantee can be released under customary circumstances, including (a) the sale of the subsidiary, (b) the subsidiary being declared “unrestricted,” (c) the legal or covenant defeasance or satisfaction and discharge of the indenture, or (d) liquidation or dissolution of the subsidiary. Separate condensed consolidated financial information is not included as the guarantor company, NTE LP, does not have independent assets or operations. The 2020 Secured Notes and the subsidiary note guarantees are secured on a pari passu basis with certain hedging agreements by a first-priority security interest in substantially all present and hereinafter acquired tangible and intangible assets of NTE LLC and each of the subsidiary guarantors and by a second-priority security interest in the inventory, accounts receivable, investment property, general intangibles, deposit accounts and cash and cash equivalents collateralized by a $500 million secured asset-based ABL Facility with a maturity date of September 29, 2019 . Additionally, the 2020 Secured Notes are fully and unconditionally guaranteed on a senior unsecured basis by NTE LP. NTE LP's creditors have no recourse to the assets of Western and its subsidiaries. Western's creditors have no recourse to the assets of NTE LP and its subsidiaries. The Company is required to make interest payments on May 15 and November 15 of each year, which commenced on May 15, 2013. There are no scheduled principal payments required prior to the 2020 Secured Notes maturing on November 15, 2020. The outstanding $350.0 million in 2020 Secured Notes are registered with SEC through two separate registrations occurring in October 2013 and January 2015. At any time prior to the maturity date of the notes, the Company may, at its option, redeem all or any portion of the notes for the outstanding principal amount plus unpaid interest and a make-whole premium as defined in the indenture. If the Company experiences a change in control or makes certain asset dispositions, as defined under the indenture, the Company may be required to repurchase all or part of the notes plus unpaid interest and, in certain cases, pay a redemption premium. The 2020 Secured Notes contain certain covenants that, among other things, limit the ability, subject to certain exceptions, of the Company to incur additional debt or issue preferred equity interests, to purchase, redeem or otherwise acquire or retire its equity interests, to make certain investments, loans and advances, to sell, lease or transfer any of its property or assets, to merge, consolidate, lease or sell substantially all of the Company’s assets, to suffer a change of control or to enter into new lines of business.

Equity (Notes)

Equity (Notes)	9 Months Ended
	Sep. 30, 2016
Class of Stock [Line Items]
Stockholders' Equity Note Disclosure [Text Block]	10. Equity Changes to equity during the nine months ended September 30, 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 134,528 52,229 186,757 Other comprehensive loss, net of tax (52 ) (70 ) (122 ) Dividends (111,555 ) — (111,555 ) Stock-based compensation 6,264 5,203 11,467 Tax deficiency from stock-based compensation (434 ) — (434 ) Distributions to non-controlling interests — (49,906 ) (49,906 ) NTI merger (14,020 ) (1,329,348 ) (1,343,368 ) Transaction costs for NTI merger (11,741 ) — (11,741 ) Issuance of WNRL common units — 277,751 277,751 Offering costs for issuance of WNRL common units — (477 ) (477 ) Treasury stock issuance 438,168 — 438,168 Treasury stock purchases (75,000 ) — (75,000 ) Balance at September 30, 2016 $ 1,665,455 $ 601,991 $ 2,267,446 Changes to equity during the nine months ended September 30, 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 393,211 213,722 606,933 Other comprehensive income, net of tax 65 66 131 Dividends (93,612 ) — (93,612 ) Stock-based compensation 3,216 8,814 12,030 Excess tax benefit from stock-based compensation 879 — 879 Distributions to non-controlling interests — (176,289 ) (176,289 ) Treasury stock purchases (105,000 ) — (105,000 ) Other — (221 ) (221 ) Balance at September 30, 2015 $ 1,318,467 $ 1,714,028 $ 3,032,495 Share Issuance Pursuant to the Merger Agreement, we issued 17.1 million shares of Western common stock including 11.6 million treasury shares on June 23, 2016. See Note 21, Acquisitions , for further discussion of the Merger. 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 Shares purchased during Q2, 2016 — — Shares purchased at June 30, 2016 2,462,350 75,000 Shares purchased during Q3, 2016 — — Shares purchased at September 30, 2016 2,462,350 $ 75,000 As of September 30, 2016 , we had $125.0 million remaining in authorized purchases 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 April 8 April 18 May 2 0.38 34,685 Third quarter July 15 July 25 August 9 0.38 41,202 Fourth quarter (1) October 13 October 24 November 8 0.38 — Total $ 111,488 (1) The fourth quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $41.2 million . NTI Distributions The table below summarizes NTI's 2016 quarterly distribution declarations and payments: Declaration Date Record Date Payment Date Distribution per Unit February 3, 2016 February 12, 2016 February 19, 2016 $ 0.38 June 13, 2016 June 23, 2016 June 23, 2016 0.18 Total $ 0.56 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 July 26, 2016 August 12, 2016 August 26, 2016 0.4125 October 24, 2016 November 7, 2016 November 23, 2016 0.4225 Total $ 1.6300 In addition to its quarterly distributions, WNRL paid incentive distributions of $1.2 million , $2.9 million , $0.3 million and $0.5 million for the three and nine months ended September 30, 2016 and 2015 , respectively, to Western as its general partner and holder of its incentive distribution rights.
Northern Tier Energy LP [Member]
Class of Stock [Line Items]
Stockholders' Equity Note Disclosure [Text Block]	. EQUITY Western indirectly owns 100% of Northern Tier Energy GP LLC and 100.0% of the limited partnership interest in NTE LP. Merger with Western On December 21, 2015 , Western and NTE LP announced that they had entered into an Agreement and Plan of Merger dated as of December 21, 2015 ("the Merger Agreement"), with NTE GP and Western Acquisition Co, LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("MergerCo") whereby Western would acquire all of Northern Tier's outstanding common units not already owned by Western (the "Merger"). Based upon the consideration elections made by NTI common unitholders, this cash and Western common stock was allocated among NTI common unitholders as follows: • NTI common unitholders who made a valid “Mixed Election” (as defined in the Merger Agreement), or who made no election, received $15.00 in cash and 0.2986 of a share of Western common stock for each such NTI common unit held. • NTI common unitholders who made a valid “Cash Election” (as defined in the Merger Agreement) received $15.357 in cash and 0.28896 of a share of Western common stock as prorated in accordance with the Merger Agreement for each such NTI common unit held. • NTI common unitholders who made a valid “Stock Election” (as defined in the Merger Agreement) received 0.7036 of a share of Western common stock for each such NTI common unit held. On June 23, 2016, following the approval of the Merger by NTI common unitholders, all closing conditions to the Merger were satisfied, and the Merger was successfully completed. The transaction resulted in approximately 17.1 million additional shares of WNR common stock outstanding. Subsequent to this transaction, NTI continues to exist as a limited partnership and became an indirect wholly-owned subsidiary of Western (see Note 19 ). Distribution Policy Prior to our merger with Western, the Company generally made distributions, if any, within 60 days after the end of each quarter, to unitholders of record as of the applicable record date. The board of directors of the Company's general partner adopted a policy pursuant to which distributions for each quarter, if any, would equal the amount of available cash the Company generated in such quarter, if any. Distributions on the Company's units were in cash. Available cash for each quarter, if any, was determined by the board of directors of the Company's general partner following the end of such quarter. Distributions were expected to be based on the amount of available cash generated in such quarter. Available cash for each quarter was generally equal to the Company's cash flow from operations for the quarter, excluding working capital changes, less cash required for maintenance and regulatory capital expenditures, reimbursement of expenses incurred by the Company's general partner and its affiliates, debt service and other contractual obligations and reserves for future operating or capital needs that the board of directors of our general partner deemed necessary or appropriate, including reserves for turnaround and related expenses, working capital, and organic growth projects. Pursuant to the terms of the Merger Agreement, the Company declared and paid a prorated quarterly distribution for the period April 1, 2016, to June 13, 2016, which was paid on June 23, 2016, to unitholders of record as of immediately prior to the Effective Time of the Merger (as defined in the Merger Agreement). Subsequent to the merger with Western, Northern Tier changed its distribution policy to distribute cash to entities controlled directly or indirectly by Western on a discretionary basis with respect to timing and amount, subject to the restricted payments tests in the 2020 Secured Notes and ABL Facility, maintaining cash reserves sufficient to cover expected working capital needs, turnaround and capital spending needs, debt service, hedging net losses, and certain other contractual obligations deemed necessary or appropriate by the board of directors of our general partner. The following table details the quarterly distributions paid to common unitholders for each of the quarters in the year ended December 31, 2015 and the nine months ended September 30, 2016 : Date Declared Date Paid Common Units and equivalents at record date (in millions) Distribution per common unit and equivalent Total Distribution (in millions) 2015 Distributions: February 5, 2015 February 27, 2015 93.7 $ 0.49 $ 45.9 May 5, 2015 May 29, 2015 93.7 1.08 100.8 August 4, 2015 August 28, 2015 93.7 1.19 111.3 November 3, 2015 November 25, 2015 93.7 1.04 97.3 Total distributions paid during 2015 $ 3.80 $ 355.3 2016 Distributions: February 3, 2016 February 19, 2016 94.2 $ 0.38 $ 36.0 June 13, 2016 June 23, 2016 93.0 0.18 16.7 Total distributions paid during 2016 $ 0.56 $ 52.7 Changes in Partners' Equity (in millions) Partners' Capital Accumulated Other Comprehensive Income Total Partners' Equity Balance at December 31, 2015 $ 392.9 $ 0.2 $ 393.1 Net income 88.9 — 88.9 Asset sale to entity under common control 146.1 — 146.1 Distributions (52.7 ) — (52.7 ) Equity-based compensation expense 10.4 — 10.4 Other (0.3 ) — (0.3 ) Amortization of net prior service cost and deferred loss on defined benefit plans — (0.2 ) (0.2 ) Balance at September 30, 2016 $ 585.3 $ — $ 585.3 From the beginning of the year to immediately prior to our merger with Western on June 23, 2016 , the Company's common units issued and outstanding increased by 114,047 , which was primarily attributable to the conversion of phantom units into common units upon vesting (see Note 14 ). Upon our merger with Western, 100% of our limited common units were indirectly owned by Western.

Income Taxes (Notes)

Income Taxes (Notes)	9 Months Ended
	Sep. 30, 2016
Income Tax Contingency [Line Items]
Income Taxes	11. Income Taxes Compared to the federal statutory rate of 35% , our effective tax rates for the three and nine months ended September 30, 2016 and 2015 , were 20.9% , 26.8% , 29.7% and 27.5% , respectively. The effective tax rates for the three and nine months ended September 30, 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. In addition, we released reserves related to uncertain tax positions during the third quarter of 2016. As of June 23, 2016, all of NTI's taxable income became subject to income taxes at the Western consolidated level. We are subject to examination by the Internal Revenue Service for tax years ended December 31, 2013, or after and by various state and local taxing jurisdictions for tax years ended December 31, 2012, 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 September 30, 2016 . There was no change in the valuation allowance for the Yorktown NOL carryforwards from December 31, 2015 . As of September 30, 2016 , we have recorded a liability of $34.5 million for unrecognized tax benefits, of which $18.7 million would affect our effective tax rate if recognized. There was a decrease of $6.7 million and $5.7 million , respectively, in our unrecognized tax benefits for the three and nine months ended September 30, 2016 . We believe that it is reasonably possible that a decrease of up to $5.6 million in unrecognized tax benefits, resulting from the expiration of statutes of limitations in various tax jurisdictions, may be necessary within the coming year. We also recognized $0.4 million , $0.9 million , $0.1 million and $0.3 million in interest and penalties for three and nine months ended September 30, 2016 and 2015 , respectively.
Northern Tier Energy LP [Member]
Income Tax Contingency [Line Items]
Income Taxes	. INCOME TAXES NTE LP is treated as a partnership for federal and state income tax purposes. However, NTRH, the parent company of NTR and NTB, is taxed as a corporation for federal and state income tax purposes. No provision for income tax is calculated on the earnings of the Company or its subsidiaries, other than NTRH, as these entities are pass-through entities for tax purposes. The Company’s effective tax rate for the three months ended September 30, 2016 and 2015 , was 37.9% and 3.4% , respectively. For the nine months ended September 30, 2016 and 2015 , the effective tax rate was 4.0% and 2.1% , respectively. For the nine months ended September 30, 2016 and 2015 , the Company's consolidated federal and state expected statutory tax rates were 40.4% and 40.9% , respectively. The Company's effective tax rate for the nine months ended September 30, 2016 and 2015 , was lower than the statutory rate primarily due to the fact that only the retail operations of the Company are taxable entities.

Retirement Plans (Notes)

Retirement Plans (Notes)	9 Months Ended
	Sep. 30, 2016
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Retirement Plans	12. Retirement Plans We fully recognize the obligations associated with our retiree healthcare and other postretirement plans and single-employer defined benefit cash balance plan in our financial statements. Pensions The net periodic benefit cost associated with our cash balance plan for both the three and nine months ended September 30, 2016 and 2015 , was $0.6 million , $1.8 million , $0.7 million and $1.9 million , respectively. Postretirement Obligations The net periodic benefit cost associated with our postretirement medical benefit plans for the three and nine months ended September 30, 2016 and 2015 , was $0.03 million , $0.1 million , $0.2 million and $0.7 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. 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 Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Beginning of period balance $ 599 $ (1,234 ) $ 651 $ (1,291 ) Amortization of net prior service cost — — (63 ) 41 Reclassification of loss to income — 13 11 38 Income tax — (5 ) — (14 ) End of period balance $ 599 $ (1,226 ) $ 599 $ (1,226 ) Defined Contribution Plan Western sponsors defined contribution plans under which Western, NTI and WNRL participants may contribute a percentage of their eligible compensation to various investment choices offered by these plans. For the three and nine months ended September 30, 2016 and 2015 , we expensed $4.5 million , $13.6 million , $4.2 million and $12.8 million , respectively, in connection with these plans.
Northern Tier Energy LP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Retirement Plans	. EMPLOYEE BENEFIT PLANS Defined Contribution Plans The Company sponsors one qualified defined contribution plan for eligible employees. Eligibility is based upon a minimum age requirement and a minimum level of service. Participants may make contributions of a percentage of their annual compensation subject to Internal Revenue Service limits. In 2016 , the Company provides a non-matching contribution of 3.0% of eligible compensation and a matching contribution at the rate of 100% of a participant’s contribution up to 6.0% . Total Company contributions to the Retirement Savings Plans were $1.8 million and $1.6 million for the three months ended September 30, 2016 and 2015 , respectively, and $6.0 million and $5.6 million for the nine months ended September 30, 2016 and 2015 , respectively. Cash Balance Plan The Company sponsors a defined benefit cash balance pension plan (the “Cash Balance Plan”) for eligible employees. Company contributions are made to the cash account of the participants equal to 5.0% of eligible compensation. Participants’ cash accounts also receive interest credits each year based upon the average thirty -year United States Treasury bond rate published in September preceding the respective plan year. Participants become fully-vested in their accounts after three years of service. The net periodic benefit cost related to the Cash Balance Plan for both the three months ended September 30, 2016 and 2015 , was $0.6 million and for the nine months ended September 30, 2016 and 2015 , was $1.8 million and $1.9 million , respectively, related primarily to current period service costs.

Crude Oil and Refined Product R

Crude Oil and Refined Product Risk Management (Notes)	9 Months Ended
	Sep. 30, 2016
Derivative [Line Items]
Crude Oil and Refined Product Risk Management	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 nine months ended September 30, 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, refined products and natural gas futures, swap contracts or options to mitigate the change in value for a portion of our LIFO inventory and refinery fuel gas 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 and nine months ended September 30, 2016 and 2015 , and open commodity hedging positions as of September 30, 2016 and December 31, 2015 : Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Economic hedging results Realized hedging gain, net $ 27,757 $ 26,949 $ 46,110 $ 52,325 Unrealized hedging gain (loss), net (27,616 ) 271 (54,698 ) (42,073 ) Total hedging gain (loss), net $ 141 $ 27,220 $ (8,588 ) $ 10,252 September 30, December 31, (In thousands) Open commodity hedging instruments (barrels) Crude oil differential swaps, net long positions 5,622 5,155 Crude oil futures, net short positions (687 ) (562 ) Refined product price and crack spread swaps, net short positions (3,902 ) (5,645 ) Total open commodity hedging instruments, net long (short) positions 1,033 (1,052 ) Fair value of outstanding contracts, net Other current assets $ 26,757 $ 78,125 Other assets 2,851 11,881 Accrued liabilities (4,457 ) (10,273 ) Other long-term liabilities (153 ) — Fair value of outstanding contracts - unrealized gain, net $ 24,998 $ 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 September 30, 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 September 30, 2016 (In thousands) Financial assets: Current assets $ 34,060 $ (7,303 ) $ 26,757 Other assets 4,455 (1,604 ) 2,851 Financial liabilities: Accrued liabilities (10,449 ) 5,992 (4,457 ) Other long-term liabilities (3,068 ) 2,915 (153 ) $ 24,998 $ — $ 24,998 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 (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 September 30, 2016 , we had the following outstanding crude oil and refined product hedging instruments that were entered into as economic hedges. Settlement prices for our distillate crack spread swaps range from $13.72 to $16.86 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 Inventory positions (futures and swaps): Crude oil differential swaps, net long positions 3,042 2,580 Crude oil futures, net short positions (687 ) — Distillate - net short positions (137 ) — Refined products - net short positions (315 ) (875 ) Natural gas futures - net long positions 151 329 Refined product positions (crack spread swaps): Distillate - net short positions (850 ) (1,680 ) Unleaded gasoline - net short positions (525 ) —
Northern Tier Energy LP [Member]
Derivative [Line Items]
Crude Oil and Refined Product Risk Management	. DERIVATIVES The Company is exposed to market risks related to the volatility in the price of crude oil, refined products (primarily gasoline and distillate), and natural gas used in its operations. To reduce the impact of price volatility on its results of operations and cash flows, the Company uses commodity derivative instruments, including forwards, futures, swaps, and options. The Company uses the futures markets for the available liquidity, which provides greater flexibility in transacting in these instruments. The Company uses swaps primarily to manage its price and margin exposure. The positions in commodity derivative instruments are monitored and managed on a daily basis by a risk control group to ensure compliance with the Company's stated commercial risk management policy. The Company considers these transactions economic hedges of market risk but has elected not to designate these instruments as hedges for financial reporting purposes. The Company recognizes all derivative instruments, except for those that qualify for the normal purchase and normal sales exception, as either assets or liabilities at fair value on the condensed consolidated balance sheets and any related net gain or loss is recorded as a gain or loss in the condensed consolidated statements of operations and comprehensive income. Observable quoted prices for similar assets or liabilities in active markets (Level 2 as described in Note 12 ) are considered to determine the fair values for the purpose of marking to market the derivative instruments at each period end. Risk Management Activities by Type of Risk The Company periodically uses futures and swaps contracts to manage price risks associated with inventory quantities both above and below target levels. The Company also periodically uses crack spread and crude differential futures and swaps contracts to manage refining margins. Under the Company's risk mitigation strategy, it may buy or sell an amount equal to a fixed price times a certain number of barrels, and to buy or sell in return an amount equal to a specified variable price times the same amount of barrels. Physical volumes are not exchanged and these contracts are net settled with cash. The objective of the Company's economic hedges pertaining to crude oil and refined products is to hedge price volatility in certain refining inventories and firm commitments to purchase crude oil inventories. The level of activity for the Company's economic hedges is based on the level of operating inventories, and generally represents the amount by which inventories differ from established target inventory levels. The objective of the Company's economic hedges pertaining to natural gas is to lock in the price for a portion of the Company's forecasted natural gas requirements at existing market prices that are deemed favorable. At September 30, 2016 and December 31, 2015 , the Company had open commodity derivative instruments as follows: September 30, 2016 December 31, 2015 Crude oil and refined products (thousands of barrels): Futures - long — 90 Futures - short 869 933 Swaps - long 4,438 5,155 Swaps - short 750 525 Forwards - long 3,747 4,445 Forwards - short 2,863 2,572 Natural gas (thousands of MMBTUs): Swaps 1,598 1,554 The information below presents the notional volume of outstanding contracts by type of instrument and year of maturity at September 30, 2016 : Notional Contract Volumes by Year of Maturity 2016 2017 Crude oil and refined products (thousands of barrels): Futures - short 869 — Swaps - long 2,159 2,279 Swaps - short 750 — Forwards - long 3,747 — Forwards - short 2,863 — Natural gas (thousands of MMBTUs): Swaps 321 1,277 Fair Value of Derivative Instruments The following tables provide information about the fair values of the Company's derivative instruments as of September 30, 2016 and December 31, 2015 and the line items in the condensed consolidated balance sheets in which the fair values are reflected. See Note 12 for additional information related to the fair values of derivative instruments. The Company is required to post margin collateral with a counterparty in support of our hedging activities. Funds posted as collateral were $7.5 million and $6.0 million as of September 30, 2016 and December 31, 2015 , respectively. The margin collateral posted is required by counterparties and cannot be offset against the fair value of open contracts except in the event of default. The Company nets fair value amounts recognized for multiple similar derivative contracts executed with the same counterparty under master netting arrangements, including cash collateral assets and obligations. The tables below, however, are presented on a gross asset and gross liability basis. September 30, 2016 (in millions) Balance Sheet Location Assets Liabilities Commodity instruments: Swaps Other current assets $ 4.0 $ 2.2 Swaps Accrued liabilities 0.5 0.9 Swaps Other assets 1.3 0.8 Futures Accrued liabilities — 2.8 Forwards Other current assets 2.4 — Forwards Accrued liabilities — 2.9 Total $ 8.2 $ 9.6 December 31, 2015 (in millions) Balance Sheet Location Assets Liabilities Commodity instruments: Swaps Accrued liabilities $ — $ 7.9 Futures Other current assets 0.4 — Forwards Other current assets 1.5 — Forwards Accrued liabilities — 1.5 Total $ 1.9 $ 9.4 Effect of Hedging Instruments on Income All derivative contracts are marked to market at period end and the resulting gains and losses are recognized in earnings. The following tables provide information about the gain or loss recognized in income on the Company's derivative instruments and the line items in the financial statements in which such gains and losses are reflected. Recognized gains and losses on derivatives were as follows: Three Months Ended Nine Months Ended (in millions) September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Gain (loss) on the change in fair value of outstanding derivatives $ (3.8 ) $ (1.3 ) $ 6.1 $ 0.3 Settled derivative gains (losses) (0.8 ) 3.9 (13.6 ) 1.1 Total recognized gain (loss) $ (4.6 ) $ 2.6 $ (7.5 ) $ 1.4 Gain (loss) recognized in cost of sales $ (4.4 ) $ 3.4 $ (8.2 ) $ 3.3 Gain (loss) recognized in operating expenses (0.2 ) (0.8 ) 0.7 (1.9 ) Total recognized net gain (loss) on derivatives $ (4.6 ) $ 2.6 $ (7.5 ) $ 1.4 Market and Counterparty Risk The Company is exposed to credit risk in the event of nonperformance by counterparties on its risk mitigating arrangements. The counterparties are large financial institutions with long-term credit ratings of at least BBB+ by Standard and Poor’s and A3 by Moody’s. In the event of default, the Company may be subject to losses on a derivative instrument’s mark-to-market gains. The Company does not expect nonperformance of the counterparties involved in its risk mitigation arrangements.

Asset Retirement Obligations (N

Asset Retirement Obligations (Notes)	9 Months Ended
	Sep. 30, 2016
Northern Tier Energy LP [Member]
Guarantor Obligations [Line Items]
Asset Retirement Obligation Disclosure [Text Block]	. ASSET RETIREMENT OBLIGATIONS The following table summarizes the changes in asset retirement obligations: Nine Months Ended (in millions) September 30, 2016 September 30, 2015 Asset retirement obligation balance at beginning of period $ 2.4 $ 2.4 Costs incurred to remediate (0.2 ) (0.3 ) Accretion expense 0.2 0.2 Asset retirement obligation balance at end of period $ 2.4 $ 2.3

Stock-Based Compensation (Notes

Stock-Based Compensation (Notes)	9 Months Ended
	Sep. 30, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-Based Compensation	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 September 30, 2016 , there were 19,856 and 2,391,711 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 September 30, 2016 , there were 658,506 unvested RSUs outstanding. We recorded stock compensation of $1.8 million , $4.5 million , $1.1 million and $3.2 million for the three and nine months ended September 30, 2016 and 2015 , respectively, which is included in selling, general and administrative expenses. As of September 30, 2016 , the aggregate grant date fair value of outstanding RSUs was $21.2 million . The aggregate intrinsic value of outstanding RSUs was $17.4 million . The unrecognized compensation cost of unvested RSUs was $16.6 million . Unrecognized compensation costs for RSUs will be recognized over a weighted-average period of 2.63 years. The tax deficiency related to the RSUs that vested during the nine months ended September 30, 2016 , was $0.4 million using a statutory blended rate of 38.1% . There was no RSU vesting activity during the three months ended September 30, 2016 . The aggregate grant date fair value of the RSUs that vested during the nine months ended September 30, 2016 , was $4.1 million . The related aggregate intrinsic value of these RSUs was $3.0 million at the vesting date. The excess tax benefit related to the RSUs that vested during the three and nine months ended September 30, 2015 , was $0.03 million and $0.9 million , respectively, using a statutory blended rate of 38.1% . The aggregate grant date fair value of the RSUs that vested during the three and nine months ended September 30, 2015 , was $0.1 million and $3.7 million , respectively. The related aggregate intrinsic value of these RSUs was $0.2 million and $6.0 million , respectively, at the vesting date. The following table summarizes our RSU activity for the nine months ended September 30, 2016 : Number of Units Weighted Average Grant Date Fair Value Not vested at December 31, 2015 399,214 $ 37.43 Awards granted 375,774 28.52 Awards vested (109,634 ) 37.63 Awards forfeited (6,848 ) 43.81 Not vested at September 30, 2016 658,506 32.25 Amended and Restated Northern Tier Energy LP 2012 Long-Term Incentive Plan Effective upon the closing of the Merger, Western adopted and assumed NTI's equity compensation plan and amended and renamed the plan as the Amended and Restated Northern Tier Energy LP 2012 Long-Term Incentive Plan ("NTI LTIP"). Modifications to the NTI LTIP include, among other things, a change to the unit of equity from an NTI common unit to a share of Western common stock. The amendment changes the administrator of the NTI LTIP from the board of directors of NTI's general partner to Western's board of directors or its applicable committee. Consistent with the terms of the Merger Agreement, all unvested equity awards at the time of the Merger were exchanged for Western phantom stock awards and performance cash awards under the NTI LTIP. We incurred equity-based compensation expense of $3.0 million , $11.0 million , $2.4 million and $7.9 million for the three and nine months ended September 30, 2016 and 2015 , respectively. The NTI LTIP provides, among other awards, for grants of stock options, restricted stock, phantom stock, dividend equivalent rights, stock appreciation rights and other awards that derive their value from the market price of Western's common stock. As of September 30, 2016 , there was 255,560 common share equivalents reserved for future grants under the NTI LTIP. We determined the fair value of the phantom stock based on the closing price of Western common stock on the grant date. We amortize the estimated fair value of the phantom stock on a straight-line basis over the scheduled vesting periods of individual awards. The aggregate grant date fair value of non-vested phantom stock outstanding as of September 30, 2016 , was $16.7 million . The aggregate intrinsic value of such phantom stock was $21.8 million . Total unrecognized compensation cost related to unvested phantom stock totaled $11.4 million as of September 30, 2016 , that is expected to be recognized over a weighted-average period of 1.5 years . The excess tax benefit related to the phantom stock that vested during the three and nine months ended September 30, 2016 , was $0.01 million using a statutory blended rate of 38.1% . The aggregate grant date fair value of the phantom stock that vested during the three and nine months ended September 30, 2016 , was $0.3 million . The related aggregate intrinsic value of the vested phantom stock was $0.3 million at the vesting date. A summary of our phantom stock award activity under the NTI LTIP for the nine months ended September 30, 2016 , is set forth below: Number of Phantom Stock Weighted Average Not vested at December 31, 2015 — $ — Awards granted 848,267 20.25 Awards vested (13,817 ) 20.25 Awards forfeited (12,132 ) 20.25 Not vested at September 30, 2016 822,318 20.25 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 September 30, 2016 , there were 4,098,368 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 $0.7 million , $2.0 million , $0.6 million and $1.5 million for the three and nine months ended September 30, 2016 and 2015 , respectively. The aggregate grant date fair value of non-vested phantom units outstanding as of September 30, 2016 , was $7.5 million . The aggregate intrinsic value of such phantom units was $6.6 million . Total unrecognized compensation cost related to unvested phantom units totaled $6.2 million as of September 30, 2016 , that is expected to be recognized over a weighted-average period of 2.60 years. A summary of WNRL's common and phantom unit award activity for the nine months ended September 30, 2016 , is set forth below: Number of Phantom Units Weighted Average Not vested at December 31, 2015 279,787 $ 28.06 Awards granted 101,955 22.69 Awards vested (86,406 ) 25.80 Awards forfeited (10,181 ) 31.87 Not vested at September 30, 2016 285,155 26.42
Northern Tier Energy LP [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-Based Compensation	. EQUITY-BASED COMPENSATION Prior to Northern Tier's merger with Western, the Company maintained the 2012 Long-Term Incentive Plan ("LTIP"). Effective upon the closing of the Merger, Western's board of directors adopted and assumed the LTIP and amended and renamed the LTIP to the Northern Tier Energy LP Amended and Restated 2012 Long-Term Incentive Plan ("Amended LTIP"). The Amended LTIP changed, among other things, the unit of equity from a unit of NTI common partnership interest to a share of Western common stock and the administrator of the plan was changed from the board of directors of the NTE GP to the board of directors of Western or its applicable committee. All unvested equity awards at the time of the Merger with Western were exchanged for new awards under the Amended LTIP consistent with the terms of the Merger Agreement. The Company recognized equity-based compensation expense of $3.0 million and $2.4 million for the three months ended September 30, 2016 , and 2015 , respectively and $11.0 million and $7.9 million for the nine months ended September 30, 2016 , and 2015 , respectively, related to these plans. This expense is included in selling, general and administrative expenses in the condensed consolidated statements of operations and comprehensive income. AMENDED LTIP Approximately 0.2 million Western common share equivalents are reserved for issuance under the Amended LTIP as of September 30, 2016 . The Amended LTIP permits the award of stock options, restricted stock, phantom stock, dividend equivalent rights, stock appreciation rights and other awards that derive their value from the market price of Western's common stock. As of September 30, 2016 , approximately 0.8 million shares of equity denominated awards and approximately $9.0 million in cash denominated awards were outstanding under the Amended LTIP. The Company recognized the expense on all LTIP awards ratably from the grant date until all units vested. Service-based awards generally vested ratably over a three -year period beginning on the award's first anniversary date and performance-based awards generally vested following the end of the measurement period which, for the performance-based phantom awards, had traditionally been three years after the commencement of the measurement period. Compensation expense related to service-based phantom awards was 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. Compensation expense related to performance-based phantom awards was based on the grant date fair value as determined by either the closing price on the grant date and management's estimates on the number of units that ultimately vested in the case of awards with company performance based criteria or by third-party valuation experts in the case of awards with market based criteria. For awards to employees, the Company estimated a forfeiture rate which was subject to revision depending on the actual forfeiture experience. As of September 30, 2016 , the total unrecognized compensation cost for stock and cash awards under the Amended LTIP was $11.4 million . Restricted Common Units Legacy NTI Service-based Restricted Common Unit Awards As of September 30, 2016 , the Company had no restricted common units outstanding as all restricted common units were exchanged upon the Merger with Western. As a replacement for these awards, for every one unvested outstanding restricted common unit, 1.0323 shares of Western phantom stock were issued to the participant with all vesting dates remaining unchanged. A summary of the service-based restricted common unit activity is set forth below: Number of Weighted Weighted restricted common units Average Grant Average Term (in thousands) Date Value Until Maturity Nonvested at December 31, 2015 191.5 $ 24.75 1.0 Forfeited (12.3 ) $ 25.57 — Vested (34.5 ) $ 26.83 — Exchanged due to merger (144.7 ) $ 24.18 0.5 Nonvested at September 30, 2016 — $ — — Phantom Common Units Legacy NTI Service-based Phantom Common Unit Awards As of September 30, 2016 , the Company had no service-based phantom common units outstanding as all service-based phantom common units were exchanged in accordance with the Merger. For every one unvested service-based phantom common units outstanding, 1.0323 shares of Western phantom stock were issued to the participant with all vesting dates remaining unchanged. A summary of the service-based phantom common unit activity is set forth below: Number of phantom common units Weighted Weighted (in thousands) Average Grant Average Term Service-Based Performance-Based Total Date Value Until Maturity Nonvested at December 31, 2015 581.9 260.7 842.6 $ 24.00 1.5 Awarded 381.0 163.6 544.6 $ 25.87 2.5 Incremental performance units — 231.8 231.8 $ 27.82 2.0 Forfeited (16.5 ) (19.1 ) (35.6 ) $ 25.36 — Vested (269.2 ) (1.8 ) (271.0 ) $ 24.10 — Exchanged due to merger (677.2 ) (635.2 ) (1,312.4 ) $ 25.45 2.0 Nonvested at September 30, 2016 — — — $ — — Western Service-based Phantom Stock Awards As a result of the Merger, both the previously outstanding service-based restricted and phantom common unit awards were exchanged with 0.8 million service based awards of Western phantom stock. Upon vesting, Western may settle these awards in common stock, cash or a combination of both, in the discretion of the board of directors of Western or its applicable committee. The new Western phantom stock awards participate in dividends on an equal basis with Western's common shareholders. However, dividends for phantom stock awards are paid in cash only upon vesting. In the event that unvested phantom stock awards are forfeited or canceled, any unpaid dividends on the underlying awards are also forfeited by the grantee. For phantom stock awards outstanding at September 30, 2016 , the forfeiture rates ranged from zero to 30% , depending on the employee pay grade classification. Legacy NTI Performance-based Phantom Common Awards As of September 30, 2016 , the Company had no performance-based phantom common units outstanding as all performance-based phantom common units were exchanged in accordance with the Merger. Western issued (a) fixed-value cash denominated awards for the pre-merger time period pertaining to the legacy NTI performance-based phantom common unit awards based upon the performance multiples achieved through March 31, 2016 (the most recently completed quarter prior to the Merger date) and (b) variable-value cash denominated awards for the post-merger time period pertaining to the legacy NTI performance-based phantom common unit awards. Both the fixed value and variable value awards were converted to cash denominated awards at a rate of $21.1049 in cash for every one unvested outstanding performance-based phantom common unit prior to the Merger. Pre-Merger Period Service-Based Cash Denominated Awards As of September 30, 2016 , Western had $4.4 million in unvested fixed value, cash denominated awards applicable to the Company's pre-merger period ("Legacy Performance Awards"). The vesting dates of the Legacy Performance Awards remained unchanged and are now subject only to service conditions. These awards have a weighted average term until maturity of 1.3 years. The related expense is amortized over the remaining service period using the straight-line method and recognized in selling, general and administrative expenses. In the event that unvested Legacy Performance Awards are forfeited or canceled, all dividend rights associated with the grant are also forfeited by the grantee. The forfeiture rates on the Legacy Performance Awards range from 5% to 20% , depending on the employee's pay grade classification. Post-Merger Period Performance-Based Cash Denominated Awards As of September 30, 2016 , the Western had $4.6 million in unvested variable value, cash denominated awards applicable to the Company's post-merger period (the "Performance Cash Award"). Assuming a threshold EBITDA is achieved and the participant meets the service conditions throughout the vesting term, participants are entitled to a payout under the Performance Cash Award based on the Company’s achievement of two criteria compared to the performance peer group selected by the compensation committee of Western's board of directors over the performance period: (a) return on capital employed, referred to as a performance condition, and (b) total shareholder return, referred to as a market condition. The average of these two conditions is then multiplied by a third condition relating to Western's average safety rate over the performance period relative to the comparable average safety rate of the refining industry as published by the Bureau of Labor Statistics, and can range between 85% for relatively poor safety performance to 115% for relatively superior safety performance. The Company accounts for the performance and market conditions in each Performance Cash Award as separate liability awards and remeasures the expected liability each period.

Earnings per Share (Notes)

Earnings per Share (Notes)	9 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
Earnings Per Share [Text Block]	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 and phantom stock. 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 or phantom stock in the two-class method when calculating earnings per share. The computation of basic and diluted earnings per share under the two-class method is presented as follows: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands, except per share data) Basic earnings per common share: Allocation of earnings: Net income attributable to Western Refining, Inc. $ 38,575 $ 153,303 $ 134,528 $ 393,211 Distributed earnings (41,269 ) (32,498 ) (111,555 ) (93,612 ) Undistributed income (loss) attributable to Western Refining, Inc. $ (2,694 ) $ 120,805 $ 22,973 $ 299,599 Weighted-average number of common shares outstanding 108,424 94,826 97,802 95,308 Basic earnings per common share: Distributed earnings per share $ 0.38 $ 0.34 $ 1.14 $ 0.98 Undistributed earnings (loss) per share (0.02 ) 1.27 0.23 3.14 Basic earnings per common share $ 0.36 $ 1.61 $ 1.37 $ 4.12 Diluted earnings per common share: Net income attributable to Western Refining, Inc. $ 38,575 $ 153,303 $ 134,528 $ 393,211 Weighted-average diluted common shares outstanding 108,734 94,924 98,110 95,408 Diluted earnings per common share $ 0.35 $ 1.61 $ 1.37 $ 4.12 The computation of the weighted average number of diluted shares outstanding is presented below: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Weighted-average number of common shares outstanding 108,424 94,826 97,802 95,308 Restricted share units and phantom stock 310 98 308 100 Weighted-average number of diluted shares outstanding 108,734 94,924 98,110 95,408 A shareholder's interest in our common stock could become diluted as a result of vestings of RSUs and phantom stock. In calculating our fully diluted earnings per common share, we consider the impact of RSUs and phantom stock that have not vested. We include unvested awards 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.

Cash Flows (Notes)

Cash Flows (Notes)	9 Months Ended
	Sep. 30, 2016
Other Significant Noncash Transactions [Line Items]
Cash Flows	16. Cash Flows Restricted Cash Restricted cash reported in our Condensed Consolidated Balance Sheet at September 30, 2016 , related to net proceeds from the sale of the St. Paul Park Logistics Assets to WNRL. This cash is restricted until the earlier of a) use of the cash to invest in capital assets to replace the collateral assets that were sold, b) acceptance by holders of the NTI 2020 Secured Notes of an offer to repurchase such notes at par or c) expiration of an offer to repurchase the NTI 2020 Secured Notes . NTI commenced a tender offer to repurchase for cash up to $195.0 million aggregate principal amount the NTI 2020 Secured Notes on October 17, 2016, and such offer expires on November 15, 2016. Any cash remaining after the offer to repurchase expires will become unrestricted and available for general corporate purposes. Restricted cash reported in our Condensed Consolidated Balance Sheet at December 31, 2015 , related to net proceeds from the sale of Western's TexNew Mex Pipeline System to WNRL. This cash was used to invest in capital assets. Supplemental Cash Flow Information Supplemental disclosures of cash flow information were as follows: Nine Months Ended September 30, 2016 2015 (In thousands) Non-cash operating activities were as follows: Income taxes paid $ 40,562 $ 210,656 Interest paid, excluding amounts capitalized 83,156 62,216 Non-cash investing activities were as follows: Assets acquired through capital lease obligations $ 4,644 $ 24,578 Accrued capital expenditures 33,111 31,744 PP&E derecognized from sale leaseback continuing involvement release 2,799 1,773 Transfer of capital spares from fixed asset to inventory — 1,490 Transfer of capital spares from fixed assets to other assets 699 — Transfer of capital spares from other assets to fixed assets 161 — Non-cash financing activities were as follows: Reduction of long-term debt proceeds from original issuance discount $ 10,250 $ — Treasury stock issuance 438,168 — Distributions accrued on unvested equity awards — 2,602 Distributions receivable from equity method investee — 4,250 Accrued offering costs for issuance of WNRL common units 60 —
Northern Tier Energy LP [Member]
Other Significant Noncash Transactions [Line Items]
Cash Flows	. SUPPLEMENTAL CASH FLOW INFORMATION Supplemental cash flow information is as follows: Nine Months Ended (in millions) September 30, 2016 September 30, 2015 Net cash from operating activities included: Interest paid $ 15.2 $ 15.6 Income taxes paid 0.1 2.7 Noncash investing activities included: Capital expenditures included in accounts payable $ 15.6 $ 9.6 PP&E derecognized from sale leaseback continuing involvement release 2.8 1.8 Book value of tank and terminal related assets sold to WNRL 48.9 — Common equity investment in WNRL 14.0 — PP&E additions resulting from a capital lease 0.3 — Noncash financing activities included: Distributions accrued on unvested equity awards $ — $ 2.6 Increase in equity due to proceeds received exceeding book value of assets sold to WNRL 146.1 — We reported the cash proceeds from the sale of the SPPR Logistics Assets to WNRL as restricted cash in our Condensed Consolidated Balance Sheet at September 30, 2016 . This cash is restricted until the earlier of a) use of the cash to invest in capital projects to replace the collateral assets that we sold, b) acceptance by holders of our 2020 Secured Notes of an offer to repurchase such notes at par or c) expiration of an offer to repurchase for cash up to $195.0 million aggregate principal amount the 2020 Secured Notes. The Company commenced a tender offer to repurchase the 2020 Secured Notes on October 17, 2016, and such offer expires on November 15, 2016. Any cash remaining after the offer to repurchase expires will become unrestricted and available for general corporate purposes.

Leases and Other Commitments (N

Leases and Other Commitments (Notes)	9 Months Ended
	Sep. 30, 2016
Leases [Abstract]
Leases and Other Commitments	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 Veolia North America, Inc. (“Veolia”), Veolia owns and operates two sulfuric acid regeneration units on property we lease to Veolia 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 $1.3 million and $1.0 million is included in accrued liabilities and the non-current portion of $54.5 million and $53.2 million is included in lease financing obligations in the accompanying Condensed Consolidated Balance Sheets as of September 30, 2016 and December 31, 2015 , respectively. The capital lease obligations include a deferred gain of $0.3 million . These capital leases were discounted using annual rates from 3.24% to 10.51% . Total remaining interest related to these leases was $41.0 million and $44.1 million at September 30, 2016 and December 31, 2015 , respectively. Average annual payments, including interest, for the next five years are $5.5 million with the remaining $73.0 million due through 2036 . 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 September 30, 2016 : Operating Capital Remaining 2016 $ 14,021 $ 1,380 2017 54,078 5,419 2018 50,739 5,444 2019 45,648 5,553 2020 41,467 5,744 2021 and thereafter 346,889 73,027 Total minimum lease payments $ 552,842 96,567 Less amount that represents interest 40,951 Present value of net minimum capital lease payments $ 55,616 Total rental expense was $17.9 million , $53.9 million , $16.2 million and $47.8 million for the three and nine months ended September 30, 2016 and September 30, 2015 , respectively. Contingent rentals and subleases were not significant in any period.

Contingencies (Notes)

Contingencies (Notes)	9 Months Ended
	Sep. 30, 2016
Loss Contingencies [Line Items]
Contingencies	18. Commitments and 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 September 30, 2016 and December 31, 2015 , we had consolidated environmental accruals of $18.0 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 $6.5 million remained as of September 30, 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. During the first quarter of 2016, we 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 for the nine months ended September 30, 2016 , to implement an FCC emission offset project. We paid penalties between 2009 and 2012 totaling $2.7 million . For 2017, we have budgeted capital projects specifically designed to address our compliance with the 2005 NMED Amended Agreement regarding air emissions from waste handling at our Gallup refinery. 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 operations 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. St. Paul Park Refinery At September 30, 2016 and December 31, 2015 , liabilities for remediation and closure obligations and related operations at the St. Paul Park refinery totaled $7.6 million and $8.6 million , respectively, of which $2.4 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 21 years. At September 30, 2016 , the estimated future cash flows to settle these discounted liabilities totaled $2.9 million and are discounted at a rate of 2.03% . 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 September 30, 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 the review of the test results and additional discussions with MPCA, we plan to close the remaining lagoon. At September 30, 2016 and December 31, 2015 , we estimated the remediation and closure costs to be $5.2 million and $6.0 million , respectively. In connection with NTI's December 2010 acquisition of the St. Paul Park refinery, among other assets, from the Marathon Petroleum Company LP ("Marathon"), we 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, we entered into a settlement and release agreement with Marathon and received $3.5 million pursuant to this settlement that we recorded as a reduction of direct operating expenses. Legal Matters On August 24, 2016, an alleged NTI unitholder (“Plaintiff”) filed a purported class action lawsuit against Western, NTI, NTI GP, members of the NTI GP board of directors at the time of the Merger, Evercore Group, L.L.C. (“Evercore”), and MergerCo (collectively, “Defendants”) (the “Merger Litigation”). The Merger Litigation appears to challenge the adequacy of disclosures made in connection with the Merger. Plaintiff seeks monetary damages and attorneys’ fees. The Merger Litigation is in the earliest stages of litigation. Western believes the Merger Litigation is without merit and intends to vigorously defend against it. Other Matters The EPA has issued Renewable Fuels Standards ("RFS"), that require refiners to blend renewable fuels into the refined products produced at their 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 ("RIN"). 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 $15.8 million , $51.9 million , $13.1 million and $25.8 million for the three and nine months ended September 30, 2016 and 2015 , respectively. The supply and demand environment for RINs is uncertain and we cannot predict the impact of RIN 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 have purchased RINs that the EPA determined were 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.
Northern Tier Energy LP [Member]
Loss Contingencies [Line Items]
Contingencies	. COMMITMENTS AND CONTINGENCIES The Company is the subject of, or party to, contingencies and commitments involving a variety of matters. Certain of these matters are discussed below. While the results of these commitments and contingencies cannot be predicted with certainty, the Company believes that the final resolution of the foregoing would not, individually or in the aggregate, have a material adverse effect on the Company’s consolidated financial statements as a whole. Legal Matters On February 20, 2015, a customer served a complaint in the United States District Court for the District of Minnesota alleging violations of the Telephone Consumer Protection Act. The plaintiff purports to bring the action also on behalf of others similarly situated and seeks statutory penalties, injunctive relief, and other remedies. The Company is vigorously defending itself. On August 24, 2016, an alleged NTI unitholder (“Plaintiff”) filed a purported class action lawsuit against Western, NTI, NTI GP, members of the NTI GP board of directors at the time of the Merger, Evercore Group, L.L.C. (“Evercore”), and MergerCo (collectively, “Defendants”) (the “Merger Litigation”). The Merger Litigation appears to challenge the adequacy of disclosures made in connection with the Merger. Plaintiff seeks monetary damages and attorneys’ fees. The Merger Litigation is in the earliest stages of litigation. The Company believes the Merger Litigation is without merit and intends to vigorously defend against it. Environmental Matters The Company is subject to federal, state, local and foreign laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites. Penalties may be imposed for noncompliance. At September 30, 2016 and December 31, 2015 , accruals for remediation and closure obligations totaled $7.6 million and $8.6 million , respectively. Of the $7.6 million and $8.6 million accrued, $2.4 million and $2.6 million are recorded on a discounted basis at September 30, 2016 and December 31, 2015 , respectively. These discounted liabilities are expected to be settled over at least the next 21 years. At September 30, 2016 , the estimated future cash flows to settle these discounted liabilities totaled $2.9 million , and are discounted at a rate of 2.03% . 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 September 30, 2016 and December 31, 2015 , respectively. Costs associated with environmental remediation are recorded in direct operating expenses in the statement of operations. On June 3, 2014, SPPR 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 and following the Company's review of the test results and additional discussions with the MPCA, the Company plans to close the remaining lagoon. The MPCA accepted the Company's remediation plan in the fourth quarter of 2015. At September 30, 2016 and December 31, 2015 , the Company estimates the remaining remediation costs to be approximately $5.2 million and $6.0 million , respectively. In connection with the Company's December 2010 acquisition of the St. Paul Park refinery, among other assets, from Marathon Petroleum Company LP ("Marathon"), the Company entered into an agreement with Marathon which required Marathon to share in the future remediation costs of this Lagoon, should they be required. During the three months ended September 30, 2015, the Company entered into a settlement and release agreement with Marathon and received $3.5 million pursuant to this settlement which was recorded as a reduction of direct operating expenses. Franchise Agreements In the normal course of its business, SAF enters into ten -year license agreements with the operators of franchised SuperAmerica brand retail outlets. These agreements obligate SAF or its affiliates to provide certain services including information technology support, maintenance, credit card processing and signage for specified monthly fees.

Related Party Transactions (Not

Related Party Transactions (Notes)	9 Months Ended
	Sep. 30, 2016
Related Party Transaction [Line Items]
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 a member of our board of directors who is also an officer. The lease agreement expires in May 2017. Under the terms of the lease, we make annual payments of $0.2 million . For the three and nine months ended September 30, 2016 and 2015 , we made rental payments under this lease to the related party of $0.06 million , $0.18 million , $0.06 million and $0.18 million . We have no amounts due as of September 30, 2016 , related to this lease agreement. Beginning on September 30, 2014, we began paying MPL for transportation services at published tariff rates. During the three and nine months ended September 30, 2016 and 2015 , we paid $12.3 million , $41.1 million , $13.9 million and $41.3 million , respectively, in crude transportation costs with MPL. Western's President and Chief Operating Officer is a member of MPL's board of managers.
Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Related Party Transactions Disclosure [Text Block]	. RELATED PARTY TRANSACTIONS As of September 30, 2016 , Western indirectly owns 100% of both Northern Tier Energy GP LLC ("NTE GP") and NTE LP. On December 21, 2015 , Western and NTE LP announced that they had entered into the Merger Agreement with MergerCo and NTE GP whereby Western will acquire all of NTE LP's outstanding common units not already owned by Western (see Note 19 ). The transaction closed on June 23, 2016 (see Note 19 ). On September 15, 2016, Western executed the Contribution Agreement by and among Western, SPPR, WNRL and Western Refining Logistics GP, LLC, the general partner of WNRL. Pursuant to the terms of the Contribution Agreement, SPPR has agreed to sell to WNRL approximately four million barrels of refined product and crude oil storage tanks, a light products terminal, a heavy products loading rack, certain rail and barge facilities, certain other related logistics assets, and two crude oil pipeline segments and one pipeline segment not currently in service, each of which is approximately 2.5 miles and extends from SPPR’s refinery in St. Paul Park, Minnesota to SPPR’s tank farm in Cottage Grove, Minnesota, in exchange for $195 million in cash and 628,224 of common units representing limited partner interests in WNRL. The Company's book value on the date of sale of the property, plant and equipment, certain assets under construction and additive inventory used in the terminal operations amounted to $48.9 million . The proceeds from this transaction, reduced by the book value of the assets sold was $146.1 million . The Company treated the transaction as a transfer of assets between entities under common control and, as such, accounted for the transfer at the historical book value of the assets as required by GAAP. We recognized the difference between the proceeds and the book value of the assets as an increase in equity. In connection with the closing of the Contribution Agreement, SPPR entered into a terminalling, transportation and storage services agreement (the “Terminalling Agreement”) with Western Refining Terminals, LLC (“WRT”), an indirect, wholly-owned subsidiary of WNRL. Pursuant to the Terminalling Agreement, WRT has agreed to provide product storage services, product throughput services and product additive and blending services at the terminal facilities located at or near SPPR’s refinery in St. Paul Park, Minnesota. In exchange for such services, SPPR has agreed to certain minimum volume commitments and to pay certain fees. The Terminalling Agreement will have an initial term of ten years, which may be extended for up to two renewal terms of five years each upon the mutual agreement of the parties. The Company has engaged in several types of transactions with Western and its subsidiaries including crude and feedstock purchases, asphalt purchases, finished product purchases, railcar leases and tank and terminal service fees. Additionally, the Company is party to a shared services agreement with Western and WNRL whereby the Company both receives and provides administrative support services. The shared services agreement was entered into with Western as of September 1, 2014, and was approved by the Conflicts Committee of the board of directors of NTE GP. On May 4, 2015, WNRL joined as a party to this agreement. The services covered by the shared services agreement include assistance with treasury, risk management and commercial operations, environmental compliance, information technology support, internal audit and legal. MPL is also a related party of the Company. Prior to September 30, 2014, the Company had a crude oil supply and logistics agreement with a third party and therefore had no direct supply transactions with MPL prior to that date. Beginning on September 30, 2014, the Company began paying MPL for transportation services at published tariff rates. Additionally, the Company owns a 17% interest in MPL (see Note 6 ) and generally receives quarterly cash distributions related to this investment. In addition to the Contribution Agreement, the Company engaged in the following related party transactions with unconsolidated affiliates for the three and nine months ended September 30, 2016 and 2015 : Three Months Ended Nine Months Ended (in millions) Location in Statement of Operations and Comprehensive Income September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Western Refining: Asphalt sales Revenue $ 8.9 $ 7.5 $ 28.0 $ 35.3 Feedstock sales Revenue — 0.1 — 0.6 Railcar rental Revenue 0.1 — 0.2 0.2 Refined product purchases Cost of sales — 1.5 — 1.5 Tank and terminal service fees Cost of sales 1.9 — 1.9 — Shared services purchases Selling, general and administrative expenses 0.8 1.0 2.5 2.6 Minnesota Pipe Line Company: Pipeline transportation purchases Cost of sales 12.3 13.9 41.1 41.3 The Company had the following outstanding receivables and payables with non-consolidated related parties at September 30, 2016 and December 31, 2015 : (in millions) Balance Sheet Location September 30, 2016 December 31, 2015 Net receivable (payable) with related party: Western Refining, Inc. Accounts receivable, net $ 1.9 $ 2.8 Western Refining Logistics, LP Accounts payable (1.2 ) — Minnesota Pipe Line Company Accounts payable (1.2 ) (2.7 )

Condensed Consolidating Financi

Condensed Consolidating Financial Information (Notes)	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Condensed Financial Statements [Text Block]	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 September 30, 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 St. Paul Park Logistics Transaction and the TexNew Mex Pipeline Transaction, we have made corresponding retrospective adjustments to the condensed consolidating financial information for all periods presented. See Note 1, Organization , for additional information on this transaction. As of September 30, 2016 , we owned a 100% limited partnership interest in NTI and a 52.6% 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 WNRL through our 100% ownership of its general partner. Accordingly, NTI and WNRL are consolidated with the other accounts of Western. NTI's long-term debt is comprised of the 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; for transporting crude oil and asphalt through its 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 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. 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. CONDENSED CONSOLIDATING BALANCE SHEETS As of September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 21 $ 234,970 $ 31,105 $ — $ 266,096 Restricted cash — — 195,000 — 195,000 Accounts receivable, trade, net of a reserve for doubtful accounts — 137,775 309,552 — 447,327 Accounts receivable, affiliate 15,778 71,656 3,378 (90,812 ) — Inventories — 380,161 280,577 — 660,738 Prepaid expenses — 104,195 24,943 — 129,138 Other current assets — 83,042 38,539 — 121,581 Total current assets 15,799 1,011,799 883,094 (90,812 ) 1,819,880 Equity method investment — — 98,185 — 98,185 Property, plant and equipment, net — 1,114,593 1,242,698 — 2,357,291 Goodwill — — 1,289,443 — 1,289,443 Intangible assets, net — 31,947 52,596 — 84,543 Investment in subsidiaries 5,462,120 — — (5,462,120 ) — Due from affiliate — 2,460,977 — (2,460,977 ) — Other assets, net — 32,195 33,588 — 65,783 Total assets $ 5,477,919 $ 4,651,511 $ 3,599,604 $ (8,013,909 ) $ 5,715,125 LIABILITIES AND EQUITY Current liabilities: Accounts payable, trade $ — $ 306,033 $ 328,683 $ — $ 634,716 Accounts payable, affiliate — — 90,812 (90,812 ) — Accrued liabilities 10,960 107,907 97,302 — 216,169 Current portion of long-term debt 10,500 — — — 10,500 Total current liabilities 21,460 413,940 516,797 (90,812 ) 861,385 Long-term liabilities: Long-term debt, less current portion 1,330,027 — 715,153 — 2,045,180 Due to affiliate 2,460,977 — — (2,460,977 ) — Lease financing obligations — 45,333 9,208 — 54,541 Deferred income tax liability, net — 380,508 36,443 — 416,951 Deficit in subsidiaries — 497,548 — (497,548 ) — Other liabilities — 59,349 10,273 — 69,622 Total long-term liabilities 3,791,004 982,738 771,077 (2,958,525 ) 2,586,294 Equity: Equity - Western 1,665,455 3,254,833 1,709,739 (4,964,572 ) 1,665,455 Equity - Non-controlling interests — — 601,991 — 601,991 Total equity 1,665,455 3,254,833 2,311,730 (4,964,572 ) 2,267,446 Total liabilities and equity $ 5,477,919 $ 4,651,511 $ 3,599,604 $ (8,013,909 ) $ 5,715,125 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 3,791,084 — — (3,791,084 ) — Due from affiliate — 1,623,553 — (1,623,553 ) — Other assets, net — 42,166 22,831 — 64,997 Total assets $ 3,791,105 $ 4,203,549 $ 3,312,431 $ (5,473,692 ) $ 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 1,623,553 — — (1,623,553 ) — Lease financing obligations — 42,168 11,064 — 53,232 Deferred income tax liability, net — 275,634 37,280 — 312,914 Deficit in subsidiaries — 287,761 — (287,761 ) — Other liabilities — 63,674 4,921 — 68,595 Total long-term liabilities 2,479,880 669,237 841,832 (1,911,314 ) 2,079,635 Equity: Equity - Western 1,299,297 3,129,505 373,818 (3,503,323 ) 1,299,297 Equity - Non-controlling interests — — 1,646,609 — 1,646,609 Total equity 1,299,297 3,129,505 2,020,427 (3,503,323 ) 2,945,906 Total liabilities and equity $ 3,791,105 $ 4,203,549 $ 3,312,431 $ (5,473,692 ) $ 5,833,393 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Three Months Ended September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 1,970,512 $ 1,637,091 $ (1,542,527 ) $ 2,065,076 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 1,733,544 1,415,993 (1,542,527 ) 1,607,010 Direct operating expenses (exclusive of depreciation and amortization) — 113,416 119,137 — 232,553 Selling, general and administrative expenses 46 29,887 27,387 — 57,320 Gain on disposal of assets, net — (217 ) (62 ) — (279 ) Maintenance turnaround expense — 366 26,842 — 27,208 Depreciation and amortization — 27,286 27,035 — 54,321 Total operating costs and expenses 46 1,904,282 1,616,332 (1,542,527 ) 1,978,133 Operating income (loss) (46 ) 66,230 20,759 — 86,943 Other income (expense): Equity in earnings of subsidiaries 61,069 1,125 — (62,194 ) — Interest income — 100 41 — 141 Interest and debt expense (22,448 ) (788 ) (11,220 ) — (34,456 ) Other, net — (1,301 ) 4,681 — 3,380 Income (loss) before income taxes 38,575 65,366 14,261 (62,194 ) 56,008 Provision for income taxes — (11,418 ) (282 ) — (11,700 ) Net income (loss) 38,575 53,948 13,979 (62,194 ) 44,308 Less net income attributable to non-controlling interests — — 5,733 — 5,733 Net income (loss) attributable to Western Refining, Inc. $ 38,575 $ 53,948 $ 8,246 $ (62,194 ) $ 38,575 Comprehensive income attributable to Western Refining, Inc. $ 38,575 $ 53,948 $ 8,246 $ (62,194 ) $ 38,575 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Nine Months Ended September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 4,466,234 $ 3,881,556 $ (2,719,902 ) $ 5,627,888 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 3,780,557 3,196,344 (2,719,902 ) 4,256,999 Direct operating expenses (exclusive of depreciation and amortization) — 333,556 353,751 — 687,307 Selling, general and administrative expenses 139 82,283 84,235 — 166,657 Gain on disposal of assets, net — (208 ) (973 ) — (1,181 ) Maintenance turnaround expense — 891 26,842 — 27,733 Depreciation and amortization — 79,620 81,711 — 161,331 Total operating costs and expenses 139 4,276,699 3,741,910 (2,719,902 ) 5,298,846 Operating income (loss) (139 ) 189,535 139,646 — 329,042 Other income (expense): Equity in earnings of subsidiaries 184,428 5,689 — (190,117 ) — Interest income — 317 119 — 436 Interest and debt expense (49,761 ) (2,284 ) (36,020 ) — (88,065 ) Other, net — (208 ) 14,033 — 13,825 Income (loss) before income taxes 134,528 193,049 117,778 (190,117 ) 255,238 Provision for income taxes — (67,721 ) (760 ) — (68,481 ) Net income (loss) 134,528 125,328 117,018 (190,117 ) 186,757 Less net income attributable to non-controlling interests — — 52,229 — 52,229 Net income (loss) attributable to Western Refining, Inc. $ 134,528 $ 125,328 $ 64,789 $ (190,117 ) $ 134,528 Comprehensive income attributable to Western Refining, Inc. $ 134,528 $ 125,328 $ 64,737 $ (190,117 ) $ 134,476 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Three Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 1,846,297 $ 1,478,695 $ (755,902 ) $ 2,569,090 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 1,476,431 1,175,243 (755,902 ) 1,895,772 Direct operating expenses (exclusive of depreciation and amortization) — 111,871 122,569 — 234,440 Selling, general and administrative expenses 48 28,061 26,356 — 54,465 Gain on disposal of assets, net — (6 ) (46 ) — (52 ) Maintenance turnaround expense — 490 — — 490 Depreciation and amortization — 24,830 26,547 — 51,377 Total operating costs and expenses 48 1,641,677 1,350,669 (755,902 ) 2,236,492 Operating income (loss) (48 ) 204,620 128,026 — 332,598 Other income (expense): Equity in earnings of subsidiaries 166,608 6,647 — (173,255 ) — Interest income — 106 80 — 186 Interest and debt expense (13,257 ) (703 ) (12,936 ) — (26,896 ) Other, net — (6 ) 4,333 — 4,327 Income (loss) before income taxes 153,303 210,664 119,503 (173,255 ) 310,215 Provision for income taxes — (92,114 ) (3 ) — (92,117 ) Net income (loss) 153,303 118,550 119,500 (173,255 ) 218,098 Less net income attributable to non-controlling interests — — 64,795 — 64,795 Net income (loss) attributable to Western Refining, Inc. $ 153,303 $ 118,550 $ 54,705 $ (173,255 ) $ 153,303 Comprehensive income attributable to Western Refining, Inc. $ 153,303 $ 118,558 $ 54,705 $ (173,255 ) $ 153,311 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Nine Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 5,611,815 $ 4,372,591 $ (2,267,694 ) $ 7,716,712 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 4,612,431 3,470,232 (2,267,694 ) 5,814,969 Direct operating expenses (exclusive of depreciation and amortization) — 331,423 343,051 — 674,474 Selling, general and administrative expenses 142 87,486 82,180 — 169,808 Loss (gain) on disposal of assets, net — 444 (601 ) — (157 ) Maintenance turnaround expense — 1,188 — — 1,188 Depreciation and amortization — 74,457 77,989 — 152,446 Total operating costs and expenses 142 5,107,429 3,972,851 (2,267,694 ) 6,812,728 Operating income (loss) (142 ) 504,386 399,740 — 903,984 Other income (expense): Equity in earnings of subsidiaries 433,921 8,576 — (442,497 ) — Interest income — 308 242 — 550 Interest and debt expense (40,568 ) (1,943 ) (36,658 ) — (79,169 ) Other, net — (519 ) 12,076 — 11,557 Income (loss) before income taxes 393,211 510,808 375,400 (442,497 ) 836,922 Provision for income taxes — (229,635 ) (354 ) — (229,989 ) Net income (loss) 393,211 281,173 375,046 (442,497 ) 606,933 Less net income attributable to non-controlling interests — — 213,722 — 213,722 Net income (loss) attributable to Western Refining, Inc. $ 393,211 $ 281,173 $ 161,324 $ (442,497 ) $ 393,211 Comprehensive income attributable to Western Refining, Inc. $ 393,211 $ 281,197 $ 161,365 $ (442,497 ) $ 393,276 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS Nine Months Ended September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Cash flows from operating activities: Net cash provided by (used in) operating activities $ (42,552 ) $ 226,792 $ 141,120 $ (47,483 ) $ 277,877 Cash flows from investing activities: Capital expenditures — (113,533 ) (121,804 ) 240 (235,097 ) Return of capital from equity method investment 13,537 — — (13,537 ) — Increase in restricted cash — — (195,000 ) — (195,000 ) Use of restricted cash — 69,106 — — 69,106 Contributions to affiliate — (603,987 ) (20,286 ) 624,273 — Proceeds from the sale of assets — 348 3,804 (240 ) 3,912 Net cash provided by (used in) investing activities 13,537 (648,066 ) (333,286 ) 610,736 (357,079 ) Cash flows from financing activities: Additions to long-term debt 500,000 — — — 500,000 Payments on long-term debt and capital lease obligations (5,375 ) (748 ) (1,027 ) — (7,150 ) Borrowings on revolving credit facility — — 393,900 — 393,900 Repayments on revolving credit facility — — (466,600 ) — (466,600 ) Payments for NTI units related to merger (859,893 ) — — — (859,893 ) Transaction costs for NTI merger (11,741 ) — — — (11,741 ) Proceeds from issuance of WNRL common units — — 277,751 — 277,751 Offering costs for issuance of WNRL common units — — (417 ) — (417 ) Deferred financing costs (11,408 ) — (1,002 ) — (12,410 ) Distribution to affiliate — — (61,020 ) 61,020 — Purchases of common stock for treasury (75,000 ) — — — (75,000 ) Distribution to non-controlling interest holders — — (54,115 ) — (54,115 ) Dividends paid (111,555 ) — — — (111,555 ) Contributions from affiliates 603,987 — 20,286 (624,273 ) — Distribution to Western Refining, Inc. — — — — — Excess tax benefit from stock-based compensation — 26 — — 26 Net cash provided by (used in) financing activities 29,015 (722 ) 107,756 (563,253 ) (427,204 ) Net decrease in cash and cash equivalents — (421,996 ) (84,410 ) — (506,406 ) Cash and cash equivalents at beginning of year 21 656,966 115,515 — 772,502 Cash and cash equivalents at end of year $ 21 $ 234,970 $ 31,105 $ — $ 266,096 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS Nine Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Cash flows from operating activities: Net cash provided by (used in) operating activities $ 67,772 $ 345,293 $ 383,762 $ (131,163 ) $ 665,664 Cash flows from investing activities: Capital expenditures — (108,988 ) (88,545 ) 1,557 (195,976 ) Use of restricted cash — 154,681 — — 154,681 Return of capital from equity method investment — — 5,780 — 5,780 Contributions to affiliate — (158,652 ) (18,457 ) 177,109 — Proceeds from the sale of assets — 2,028 590 (1,557 ) 1,061 Net cash provided by (used in) investing activities — (110,931 ) (100,632 ) 177,109 (34,454 ) Cash flows from financing activities: Additions to long-term debt — — 300,000 — 300,000 Payments on long-term debt and capital lease obligations (4,125 ) (658 ) (776 ) — (5,559 ) Repayments on revolving credit facility — — (269,000 ) — (269,000 ) Distribution to affiliate — — (131,163 ) 131,163 — Deferred financing costs — — (6,820 ) — (6,820 ) Purchases of common stock for treasury (105,000 ) — — — (105,000 ) Distribution to non-controlling interest holders — — (173,687 ) — (173,687 ) Dividends paid (93,612 ) — — — (93,612 ) Contributions from affiliates 134,965 — 42,144 (177,109 ) — Excess tax benefit from stock-based compensation — 879 — — 879 Net cash provided by (used in) financing activities (67,772 ) 221 (239,302 ) (45,946 ) (352,799 ) Net increase in cash and cash equivalents — 234,583 43,828 — 278,411 Cash and cash equivalents at beginning of year 21 288,986 142,152 — 431,159 Cash and cash equivalents at end of year $ 21 $ 523,569 $ 185,980 $ — $ 709,570

Acquisitions (Notes)

Acquisitions (Notes)	9 Months Ended
	Sep. 30, 2016
Business Acquisition [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	21. Acquisitions Description of the Transaction 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”). On June 23, 2016, following the approval of the Merger by NTI common unitholders, all closing conditions to the Merger were satisfied, and the Merger was successfully completed. Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo merged with and into NTI, the separate limited liability company existence of MergerCo ceased and NTI continued to exist as a limited partnership under Delaware law and as an indirect wholly-owned subsidiary of Western and as the surviving entity in the Merger. Prior to the Merger, NT InterHoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("NT InterHoldCo"), owned 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 owned 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 remained the sole general partner of NTI, the NTI Common Units held by Western and its subsidiaries were unchanged and remained issued and outstanding, and, by virtue of the Merger, all of the membership interests in MergerCo automatically 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. Consequently, NT InterHoldCo and its wholly-owned subsidiary, MergerCo HoldCo, became the sole limited partners of NTI. Pursuant to the Merger Agreement, we paid $859.9 million in cash and issued 17.1 million shares of Western common stock adjusted slightly for cash paid in lieu of fractional shares. We incurred transaction costs related to the Merger of $11.7 million . The Merger involved a change in WNR’s ownership interest in its subsidiary, NTI, due to the purchase of the remaining ownership interests not already owned by WNR and was accounted for under Accounting Standards Codification 810-10-45-23, Consolidation , which indicates that increases in a parent’s ownership interest while the parent retains its controlling financial interest in its subsidiary shall be accounted for as an equity transaction. Therefore, no gain or loss was realized as a result of the Merger. Any difference between the consideration paid and the amount by which the non-controlling interest is adjusted was recognized in Western shareholders' equity. NTI common unitholders made consideration elections that resulted in the following allocation of cash and Western common stock among NTI common unitholders. • NTI common unitholders who made a valid “Mixed Election” (as defined in the Merger Agreement), or who made no election, received $15.00 in cash and 0.2986 of a share of Western common stock for each such NTI common unit held. • NTI common unitholders who made a valid “Cash Election” (as defined in the Merger Agreement) received $15.357 in cash and 0.28896 of a share of Western common stock as prorated in accordance with the Merger Agreement for each such NTI common unit held. • NTI common unitholders who made a valid “Stock Election” (as defined in the Merger Agreement) received 0.7036 of a share of Western common stock for each such NTI common unit held. The consolidated statements of operations include the results of the Merger beginning on June 23, 2016. The following unaudited pro forma information assumes that (i) the Merger occurred on January 1, 2015; (ii) $500.0 million was borrowed to fund the Merger consideration on January 1, 2015, resulting in increased interest and debt expense of $17.0 million for the nine months ended September 30, 2016 and $9.1 million and $27.1 million for the three and nine months ended September 30, 2015 , respectively; and (iii) income tax expense increased as a result of the increased net income attributable to Western Refining, Inc. offset by increased interest and debt expense of $7.0 million for the nine months ended September 30, 2016 and $19.1 million and $64.9 million , for the three and nine months ended September 30, 2015 , respectively. Unaudited Pro Forma for the Three Months Ended Nine Months Ended September 30, September 30, 2015 2016 2015 (In thousands) Net sales $ 2,569,090 $ 5,627,888 $ 7,716,712 Operating income 332,598 329,042 903,984 Net income 189,905 162,768 514,874 Net income attributable to Western Refining, Inc. 184,319 145,862 498,715 Basic earnings per share $ 1.65 $ 1.35 $ 4.43 Diluted earnings per share 1.65 1.34 4.43 Merger and Reorganization Expenses We incurred professional service fees in connection with the Merger transaction. Additionally, we incurred costs associated with initiating a plan of reorganization for various positions during the third quarter of 2016. In relation to this reorganization plan, it was determined that certain employees would be terminated during 2016 and 2017. We recognized $2.8 million and $4.0 million of expense during the three and nine months ended September 30, 2016 , respectively, which included compensation related to the severance of employment and retention bonuses for selected employees. These costs have been included in Other, net in the accompanying Condensed Consolidated Statements of Operations. All reorganization and related costs are recognized in the Other category. We recognize these costs ratably from September 1, 2016, the effective date of the agreements, through the remaining service period, which varies for each employee, but in no case is later than September 1, 2017. As of September 30, 2016 , we anticipate that these costs will continue to be recognized through the third quarter of 2017 and for the expenses to be completely paid out by December 31, 2017. The following table summarizes the expense activity related to the Merger and Reorganization for the three and nine months ended September 30, 2016 : Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Beginning liability for merger and reorganization costs $ 452 $ 470 $ 189 $ 808 Third-party professional service fees 178 — 1,321 — Reorganization and related personnel costs incurred during period 2,666 — 2,666 — Cash payments to third-party professional service providers (442 ) — (1,133 ) — Cash payments made to severed employees (1,487 ) (112 ) (1,676 ) (450 ) Ending liability for merger and reorganization costs $ 1,367 $ 358 $ 1,367 $ 358
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Mergers, Acquisitions and Dispositions Disclosures [Text Block]	. MERGER TRANSACTION Description of the Transaction 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”). On June 23, 2016, following the approval of the Merger by NTI common unitholders, all closing conditions to the Merger were satisfied, and the Merger was successfully completed. Upon the terms and subject to the conditions set forth in the Merger Agreement, MergerCo merged with and into NTI, the separate limited liability company existence of MergerCo ceased and NTI continued 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. Prior to the Merger, NT InterHoldCo LLC, a Delaware limited liability company and wholly-owned subsidiary of Western ("NT InterHoldCo"), owned 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 owned 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 remained the sole general partner of NTI, the NTI Common Units held by Western and its subsidiaries were unchanged and remained issued and outstanding, and, by virtue of the Merger, all of the membership interests in MergerCo automatically 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. Consequently, NT InterHoldCo and its wholly-owned subsidiary, MergerCo HoldCo, became the sole limited partners of NTI. Pursuant to the Merger Agreement, Western paid $859.9 million in cash and issued 17.1 million shares of Western Common Stock adjusted slightly for cash paid in lieu of fractional shares. NTI common unitholders made consideration elections that resulted in the following allocation of cash and Western common stock among NTI common unitholders. • NTI common unitholders who made a valid “Mixed Election” (as defined in the Merger Agreement), or who made no election, received $15.00 in cash and 0.2986 of a share of Western Common Stock for each such NTI common unit held. • NTI common unitholders who made a valid “Cash Election” (as defined in the Merger Agreement) received $15.357 in cash and 0.28896 of a share of Western Common Stock, prorated in accordance with the Merger Agreement for each such NTI common unit held. • NTI common unitholders who made a valid “Stock Election” (as defined in the Merger Agreement) received 0.7036 of a share of Western Common Stock for each such NTI common unit held. Merger and Reorganization expenses The Company incurred professional service fees in connection with the Merger transaction. Additionally, the Company incurred costs associated with initiating a plan of reorganization for various positions in the third quarter of 2016. In relation to this reorganization plan, it was determined that certain employees would be terminated during 2016 and 2017. The Company recognized $1.5 million and $2.6 million of expense during the three and nine months ended September 30, 2016 , respectively, which included compensation related to the severance of employment and retention bonuses for selected employees. These costs are recognized in the merger-related expenses line within the consolidated statements of operations and comprehensive income. All reorganization and related costs are recognized in the Other segment. The Company recognizes these costs ratably from September 1, 2016, the effective date of the agreements, through the remaining service period, which varies for each employee, but in no case is later than September 1, 2017. As of September 30, 2016 , the Company anticipates that these costs will continue to be recognized through the third quarter of 2017 and for the expenses to be completely paid out by December 31, 2017. The following table summarizes the merger-related expense activity for the three and nine months ended September 30, 2016 : Three Months Ended Nine Months Ended (in millions) September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Beginning liability for merger and reorganization costs $ 0.4 $ 0.5 $ 0.2 $ 0.8 Third-party professional service fees 0.2 — 1.3 — Reorganization and related personnel costs incurred during period 1.3 — 1.3 — Cash payments to third-party professional service providers (0.4 ) — (1.1 ) — Cash payments made to severed employees (0.4 ) (0.1 ) (0.6 ) (0.4 ) Ending liability for merger and reorganization costs $ 1.1 $ 0.4 $ 1.1 $ 0.4

WNRL (Notes)

WNRL (Notes)	9 Months Ended
	Sep. 30, 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, including 692 miles of pipelines and 12.4 million barrels of active storage capacity. The majority of WNRL's logistics assets are integral to the operations of the El Paso, Gallup and St. Paul Park 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, asphalt, 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 September 30, 2016 , we owned a 52.6% 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 and fees 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 32.2% , 31.8% , 31.9% and 30.0% of WNRL’s total revenues for the three and nine month periods ended September 30, 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. 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 Sig30

Basis of Presentation and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2016
Segment Reporting Information [Line Items]
Consolidation, Policy [Policy Text Block]	Principles of Consolidation The accompanying condensed consolidated financial statements include the accounts of Western and our subsidiaries. We own 100% of NTI's general partner and, subsequent to the Merger, we own 100% of the limited partner interest in NTI. We own a 52.6% limited partner interest in WNRL and 100% of WNRL's general partner. As the general partner of WNRL, we have the ability to direct the activities of WNRL that most significantly impact their respective economic performance. We have reported a non-controlling interest for WNRL as of September 30, 2016 , of $602.0 million and non-controlling interests for NTI and WNRL of $1,646.6 million as of December 31, 2015 , in our Condensed Consolidated Balance Sheets.
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, in accordance with GAAP, requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the respective 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, 2015 and continuing into 2016, 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 in Southwest Retail, 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. In our retail segment, refined product inventory is valued using the FIFO inventory valuation method for Southwest Retail and the LIFO inventory valuation method for SuperAmerica. Retail merchandise inventory is valued using the retail inventory method.
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition Revenues are recognized when products are shipped or services are provided to customers, title is transferred, the sales price is fixed or determinable and collectability is reasonably assured. Revenues are recorded net of discounts granted to customers. Shipping and other transportation costs billed to customers are presented on a gross basis in revenues and cost of sales. Nonmonetary product exchanges and certain buy/sell crude oil transactions, which are entered into in contemplation one with another, are included on a net cost basis in cost of sales. The Company also enters into agreements to purchase and sell crude oil to third parties and certain of these activities are recorded on a gross basis.
Derivatives, Policy [Policy Text Block]	Derivative Financial Instruments The Company is exposed to earnings and cash flow volatility due to fluctuations in crude oil, refined products, and natural gas prices. The timing of certain commodity purchases and sales also subject the Company to earnings and cash flow volatility. To manage these risks, the Company may use derivative instruments associated with the purchase or sale of crude oil, refined products, and natural gas to hedge volatility in our refining and operating margins. The Company may use futures, options, and swaps contracts to manage price risks associated with inventory quantities above or below target levels. Crack spread and crude differential futures and swaps contracts may also be used to hedge the volatility of refining margins. All derivative instruments, except for those that meet the normal purchases and normal sales exception, are recorded in the condensed consolidated balance sheets at fair value and are classified depending on the maturity date of the underlying contracts. Changes in the fair value of the Company's contracts are accounted for by marking them to market and recognizing any resulting gains or losses in the condensed consolidated statements of operations and comprehensive income. Gains and losses from derivative activity specific to managing price risk on inventory quantities both above and below target levels are included within cost of sales. Derivative gains and losses are reported as operating activities within the condensed consolidated statements of cash flows. The Company enters into crude oil forward contracts to facilitate the supply of crude oil to the refinery. These contracts may qualify for the normal purchases and normal sales exception because the Company physically receives and delivers the crude oil under the contracts and when the Company enters into these contracts, the quantities are expected to be used or sold over a reasonable period of time in the normal course of business. These transactions are reflected in the period that delivery of the crude oil takes place. When forward contracts do not qualify for the normal purchases and sales exception, the contracts are marked to market each period through the settlement date, which is generally no longer than one to three months.
Consolidation, Policy [Policy Text Block]	Principles of Consolidation NTE LP is a Delaware limited partnership which consolidates all accounts of NTE LLC and its subsidiaries, including SPPR, NTRH and NTOT. All intercompany accounts have been eliminated in these condensed consolidated financial statements. The Company’s common equity interest in MPL and WNRL are accounted for using the equity method of accounting. Although SPPR owns only 1.0% of WNRL's common equity, its indirect parent company, Western, owns 52.6% . Because of Western’s controlling influence over WNRL, the investment provides the Company significant influence over WNRL and the Company accounts for its ownership interest in WNRL under the equity method. Equity income from MPL and WNRL represent the Company’s proportionate share of net income available to common equity owners generated by MPL and WNRL. See Note 3 for further discussion of the Company's ownership interests in MPL and WNRL. The equity method investments are assessed for impairment whenever changes in facts or circumstances indicate a loss in value has occurred. When the loss is deemed to be other than temporary, the carrying value of the equity method investment is written down to fair value, and the amount of the write-down is included in operating income. See Note 6 for further information on the Company’s equity method investment. MPLI owns all of the preferred membership units of MPL. This investment in MPLI, which provides the Company no significant influence over MPLI, is accounted for as a cost method investment. The investment in MPLI is carried at a value of $6.8 million at both September 30, 2016 and December 31, 2015 , and is included in other noncurrent assets within the condensed consolidated balance sheets.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities as of the date of the condensed consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Actual results could differ from those estimates.
Inventory, Policy [Policy Text Block]	Inventories Crude oil, refined product and other feedstock and blendstock inventories are carried at the lower of cost or market ("LCM"). Cost is determined principally under the last-in, first-out (“LIFO”) valuation method to reflect a better matching of costs and revenues for refining inventories. Costs include both direct and indirect expenditures incurred in bringing an item or product to its existing condition and location. Ending inventory costs in excess of market value are written down to net realizable market values and charged to cost of sales in the period recorded. In subsequent periods, a new LCM determination is made based upon current circumstances relative to, and not to exceed, the original LCM reserve that was established in fourth quarter 2014. The Company has LIFO pools for crude oil and other feedstocks and for refined products in its Refining segment and a LIFO pool for refined products inventory held by the retail stores in its Retail segment. Retail merchandise inventory is valued using the average cost method.
Segment Reporting, Policy [Policy Text Block]	Operating Segments The Company has two reportable operating segments; Refining and Retail (see Note 18 for further information on the Company’s operating segments). The Refining and Retail operating segments consist of the following: • Refining – operates the St. Paul Park, Minnesota refinery, terminal and related assets, NTOT and includes the Company’s interest in MPL and MPLI, and • Retail – comprised of 170 Company operated convenience stores and 115 franchisee operated convenience stores as of September 30, 2016 , primarily in Minnesota and Wisconsin. The retail segment also includes the operation of NTB.
Property, Plant and Equipment, Policy [Policy Text Block]	Property, Plant and Equipment Property, plant and equipment is recorded at cost and depreciated on a straight-line basis over the estimated useful lives of the assets. Such assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. If the sum of the expected undiscounted future cash flows from the use of the asset and its eventual disposition is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset. When property, plant and equipment depreciated on an individual basis is sold or otherwise disposed of, any gains or losses are reported in the condensed consolidated statements of operations and comprehensive income. Gains on the disposal of property, plant and equipment are recognized when earned, which is generally at the time of sale. If a loss on disposal is expected, such losses are generally recognized when the assets are classified as held for sale. Expenditures for routine maintenance and repair costs are expensed when incurred. Refinery process units require periodic major maintenance and repairs that are commonly referred to as “turnarounds.” Turnaround cycles vary from unit to unit but can be as short as one year for catalyst changes to as long as six years. Turnaround costs are expensed as incurred.
Regulatory Environmental Costs, Policy [Policy Text Block]	Renewable Identification Numbers The Company is subject to obligations to generate or purchase Renewable Identification Numbers ("RINs") required to comply with the Renewable Fuels Standard. The Company's overall RINs obligation is based on a percentage of domestic shipments of on-road fuels as established by the Environmental Protection Agency ("EPA"). To the degree the Company is unable to blend the required amount of biofuels to satisfy its RINs obligation, RINs must be purchased on the open market to avoid penalties and fines. The Company records its RINs obligation on a net basis in accrued liabilities when its RINs liability is greater than the amount of RINs earned and purchased in a given period and in other current assets when the amount of RINs earned and purchased is greater than the RINs liability. In 2010 and 2011, the EPA issued partial waivers with conditions allowing a maximum of 15% ethanol to be used in certain vehicles. Future changes to existing laws and regulations could increase the minimum volumes of renewable fuels that must be blended with refined petroleum fuels. Because the Company does not produce renewable fuels, increasing the volume of renewable fuels that must be blended into its products could displace an increasing volume of the Company's refineries' product pool, potentially resulting in lower earnings and materially adversely affecting our ability to issue dividends to the Company's unitholders. The purchase price for RINs is volatile and may vary significantly from period to period. Historically, the cost of purchased RINs has not had a significant impact upon the Company's operating results. The Company anticipates 2016 will be consistent with this history.
Cost of Sales, Policy [Policy Text Block]	Cost of Sales Cost of sales in the condensed consolidated statements of operations and comprehensive income excludes depreciation and amortization of refinery assets and the direct labor and overhead costs related to the operation of the refinery. These costs are included in the condensed consolidated statements of operations and comprehensive income in the depreciation and amortization and direct operating expenses line items, respectively.
Income Tax, Policy [Policy Text Block]	Excise Taxes The Company is required by various governmental authorities, including federal and state, to collect and remit taxes on certain products. Such taxes are presented on a gross basis in revenue and cost of sales in the condensed consolidated statements of operations and comprehensive income. These taxes totaled $104.6 million and $93.6 million for the three months ended September 30, 2016 and 2015 , respectively, and $323.5 million and $296.6 million for the nine months ended September 30, 2016 and 2015 , respectively.

Segment Information (Tables)

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Disclosures regarding our reportable segments with reconciliations to consolidated totals for the three and nine months ended September 30, 2016 and 2015 , are presented below: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Operating Results: Refining (2) Net sales $ 1,835,327 $ 2,318,048 $ 5,012,283 $ 6,958,443 Intersegment eliminations 736,020 843,674 2,075,758 2,403,438 Net refining sales to external customers 1,099,307 1,474,374 2,936,525 4,555,005 WNRL (2) Net sales 569,261 680,670 1,615,902 2,023,970 Intersegment eliminations 183,154 216,959 513,101 607,249 Net WNRL sales to external customers 386,107 463,711 1,102,801 1,416,721 Retail Net sales 597,621 633,793 1,610,033 1,753,503 Intersegment eliminations 17,959 2,788 21,471 8,517 Net retail sales to external customers 579,662 631,005 1,588,562 1,744,986 Consolidated net sales to external customers $ 2,065,076 $ 2,569,090 $ 5,627,888 $ 7,716,712 Operating income (loss) Refining (1) (2) $ 89,158 $ 312,602 $ 338,803 $ 900,405 WNRL (2) 13,271 18,424 43,056 41,454 Retail 11,832 24,937 21,193 36,356 Other (27,318 ) (23,365 ) (74,010 ) (74,231 ) Operating income from segments 86,943 332,598 329,042 903,984 Other income (expense), net (30,935 ) (22,383 ) (73,804 ) (67,062 ) Consolidated income before income taxes $ 56,008 $ 310,215 $ 255,238 $ 836,922 Depreciation and amortization Refining (2) $ 37,265 $ 35,400 $ 111,601 $ 105,916 WNRL (2) 10,579 8,963 29,470 25,816 Retail 5,710 5,846 17,622 17,257 Other 767 1,168 2,638 3,457 Consolidated depreciation and amortization $ 54,321 $ 51,377 $ 161,331 $ 152,446 Capital expenditures Refining (2) $ 65,909 $ 61,399 $ 200,681 $ 127,914 Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) WNRL (2) 8,530 10,648 24,378 52,150 Retail 3,593 3,903 8,528 13,175 Other 305 481 1,510 2,737 Consolidated capital expenditures $ 78,337 $ 76,431 $ 235,097 $ 195,976 Total assets Refining (2) (including $1,267,455 of goodwill) $ 4,394,967 $ 3,574,746 WNRL (2) 528,554 601,215 Retail (including $21,988 of goodwill) 430,363 430,147 Other 361,241 1,234,285 Consolidated total assets $ 5,715,125 $ 5,840,393 (1) The effect of our economic hedging activity is included within the operating income of our refining segment as a component of cost of products sold. The cost of products sold within our refining segment included $0.1 million in net realized and unrealized economic hedging gains for the three months ended September 30, 2016 , $8.6 million in net realized and unrealized economic hedging losses for the nine months ended September 30, 2016 , respectively, and $27.2 million and $10.3 million in net realized and unrealized economic hedging gains for the three and nine months ended September 30, 2015 , respectively. Also included within cost of products sold for our refining segment is the net effect of non-cash LCM recoveries of $15.2 million and $102.5 million for the three and nine months ended September 30, 2016 , respectively, charges of $36.8 million for the three months ended September 30, 2015 and recoveries of $17.1 million for the nine months ended September 30, 2015 . (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 and nine months ended September 30, 2015 . The information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the St. Paul Park Logistics Assets and the TexNew Mex Pipeline System .
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	Operating results for the Company’s operating segments are as follows: Three Months Ended September 30, 2016 (in millions) Refining Retail Other Total Revenues Customer $ 452.7 $ 279.6 $ — $ 732.3 Intersegment 154.1 — — 154.1 Segment revenues 606.8 279.6 — 886.4 Elimination of intersegment revenues — — (154.1 ) (154.1 ) Total revenues $ 606.8 $ 279.6 $ (154.1 ) $ 732.3 Income (loss) from operations $ 14.4 $ 4.4 $ (7.2 ) $ 11.6 Income from equity method investment $ 5.3 $ — $ — $ 5.3 Depreciation and amortization $ 9.7 $ 2.2 $ 0.2 $ 12.1 Capital expenditures $ 42.8 $ 1.6 $ 0.1 $ 44.5 Three Months Ended September 30, 2015 (in millions) Refining Retail Other Total Revenues Customer $ 584.0 $ 307.6 $ — $ 891.6 Intersegment 178.3 — — 178.3 Segment revenues 762.3 307.6 — 1,069.9 Elimination of intersegment revenues — — (178.3 ) (178.3 ) Total revenues $ 762.3 $ 307.6 $ (178.3 ) $ 891.6 Income (loss) from operations $ 111.1 $ 8.6 $ (5.1 ) $ 114.6 Income from equity method investment $ 4.2 $ — $ — $ 4.2 Depreciation and amortization $ 8.8 $ 2.0 $ 0.2 $ 11.0 Capital expenditures $ 16.4 $ 1.1 $ — $ 17.5
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]	Nine Months Ended September 30, 2016 (in millions) Refining Retail Other Total Revenues Customer $ 1,373.3 $ 775.7 $ — $ 2,149.0 Intersegment 419.0 — — 419.0 Segment revenues 1,792.3 775.7 — 2,568.0 Elimination of intersegment revenues — — (419.0 ) (419.0 ) Total revenues $ 1,792.3 $ 775.7 $ (419.0 ) $ 2,149.0 Income (loss) from operations $ 124.6 $ 9.2 $ (22.7 ) $ 111.1 Income from equity method investment $ 15.3 $ — $ — $ 15.3 Depreciation and amortization $ 27.9 $ 6.5 $ 0.6 $ 35.0 Capital expenditures $ 95.7 $ 3.2 $ 0.3 $ 99.2 Nine Months Ended September 30, 2015 (in millions) Refining Retail Other Total Revenues Customer $ 1,789.7 $ 855.5 $ — $ 2,645.2 Intersegment 502.0 — — 502.0 Segment revenues 2,291.7 855.5 — 3,147.2 Elimination of intersegment revenues — — (502.0 ) (502.0 ) Total revenues $ 2,291.7 $ 855.5 $ (502.0 ) $ 2,645.2 Income (loss) from operations $ 374.7 $ 16.9 $ (18.2 ) $ 373.4 Income from equity method investment $ 12.0 $ — $ — $ 12.0 Depreciation and amortization $ 26.3 $ 5.7 $ 0.6 $ 32.6 Capital expenditures $ 30.7 $ 4.2 $ 0.3 $ 35.2
Reconciliation of Assets from Segment to Consolidated [Table Text Block]	Total assets by segment were as follows: (in millions) Refining Retail Other Total At September 30, 2016 $ 1,266.8 $ 132.0 $ 23.5 $ 1,422.3 At December 31, 2015 $ 917.4 $ 138.7 $ 81.2 $ 1,137.3

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following tables represent our assets and liabilities for our commodity hedging contracts measured at fair value on a recurring basis as of September 30, 2016 and December 31, 2015 , and the basis for that measurement: Carrying Value at September 30, 2016 Fair Value Measurement Using Netting Adjustments Recorded Value at September 30, 2016 Level 1 Level 2 Level 3 (In thousands) Gross financial assets: Other current assets $ 34,060 $ — $ 34,060 $ — $ (7,303 ) $ 26,757 Other assets 4,455 — 4,455 — (1,604 ) 2,851 Gross financial liabilities: Accrued liabilities (10,449 ) — (9,688 ) (761 ) 5,992 (4,457 ) Other long-term liabilities (3,068 ) — (3,068 ) — 2,915 (153 ) $ 24,998 $ — $ 25,759 $ (761 ) $ — $ 24,998 Carrying Value at December 31, 2015 Fair Value Measurement Using Netting Adjustments Recorded Value at December 31, 2015 Level 1 Level 2 Level 3 (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]	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 and nine months ended September 30, 2016 and 2015 . Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Asset (liability) balance at beginning of period $ (1,951 ) $ 1,614 $ (5,756 ) $ 330 Change in fair value 237 (2,505 ) 537 — Fair value of trades entered into during the period — — — (1,262 ) Fair value reclassification from Level 3 to Level 2 953 (288 ) 4,458 (247 ) Liability balance at end of period $ (761 ) $ (1,179 ) $ (761 ) $ (1,179 )
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	As of September 30, 2016 and December 31, 2015 , the carrying amount and estimated fair value of our debt was as follows: September 30, December 31, (In thousands) Western obligations: Carrying amount $ 1,383,625 $ 889,000 Fair value 1,380,125 867,178 NTI obligations: Carrying amount $ 402,000 $ 350,000 Fair value 412,500 360,500 WNRL obligations: Carrying amount $ 320,300 $ 445,000 Fair value 330,800 439,000
Northern Tier Energy LP [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]	The following table provides the assets and liabilities carried at fair value measured on a recurring basis at September 30, 2016 and December 31, 2015 : Balance at Quoted prices in active markets Significant other observable inputs Unobservable inputs (in millions) September 30, 2016 (Level 1) (Level 2) (Level 3) ASSETS Cash and cash equivalents $ 14.6 $ 14.6 $ — $ — Restricted cash 195.0 195.0 — — Other current assets Derivative asset - current 4.1 — 4.1 — Other assets Derivative asset - long-term 0.6 — 0.6 — $ 214.3 $ 209.6 $ 4.7 $ — LIABILITIES Accrued liabilities Derivative liability - current $ 6.1 $ — $ 6.1 $ — $ 6.1 $ — $ 6.1 $ — Balance at Quoted prices in active markets Significant other observable inputs Unobservable inputs (in millions) December 31, 2015 (Level 1) (Level 2) (Level 3) ASSETS Cash and cash equivalents $ 70.9 $ 70.9 $ — $ — Other current assets Derivative asset - current 1.9 — 1.9 — $ 72.8 $ 70.9 $ 1.9 $ — LIABILITIES Accrued liabilities Derivative liability - current $ 9.4 $ — $ 9.4 $ — $ 9.4 $ — $ 9.4 $ —
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	The carrying value of debt, which is reported on the Company’s condensed consolidated balance sheets, reflects the cash proceeds received upon issuance, net of subsequent repayments. The fair value of the 2020 Secured Notes disclosed below was determined based on quoted prices in active markets (Level 1). September 30, 2016 December 31, 2015 (in millions) Carrying Amount Fair Value Carrying Amount Fair Value 2020 Secured Notes $ 350.0 $ 360.5 $ 350.0 $ 360.5 Outstanding borrowings on ABL Facility 52.0 52.0 — — Total $ 402.0 $ 412.5 $ 350.0 $ 360.5

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2016
Inventory [Line Items]
Schedule of Inventory, Current [Table Text Block]	Inventories were as follows: September 30, December 31, (In thousands) Refined products (1) $ 259,125 $ 201,928 Crude oil and other raw materials 348,109 288,403 Lubricants 11,118 14,996 Retail store merchandise 42,386 42,211 Inventories $ 660,738 $ 547,538 (1) Includes $15.8 million and $14.5 million of refined products inventory valued using the first-in, first-out ("FIFO") valuation method at September 30, 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 in Southwest Retail, 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. In our retail segment, refined product inventory is valued using the FIFO inventory valuation method for Southwest Retail and the LIFO inventory valuation method for SuperAmerica. Retail merchandise inventory is valued using the retail inventory method. As of September 30, 2016 and December 31, 2015 , refined products valued under the LIFO method and crude oil and other raw materials totaled 10.4 million barrels and 10.0 million barrels, respectively. At September 30, 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 $193.3 million and $198.4 million , respectively. During the three months ended September 30, 2016 and 2015 , cost of products sold included net non-cash recoveries of $79.5 million and $105.0 million , respectively, from changes in our LIFO reserves. During the nine months ended September 30, 2016 and 2015 , cost of products sold included net non-cash charges of $5.1 million and net non-cash recoveries of $129.0 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 $72.6 million and $175.1 million at September 30, 2016 and December 31, 2015 , respectively. These non-cash LCM recoveries decreased cost of products sold by $15.2 million and $102.5 million for the three and nine months ended September 30, 2016 , respectively, and by $17.1 million for the nine months ended September 30, 2015 . The non-cash LCM charge for the three months ended September 30, 2015 , increased cost of products sold by $36.8 million . Average LIFO cost per barrel of our refined products and crude oil and other raw materials inventories as of September 30, 2016 and December 31, 2015 , were as follows: September 30, 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 4,033 $ 279,917 $ 69.41 3,536 $ 259,722 $ 73.45 Crude oil and other 6,348 384,067 60.50 6,490 391,237 60.28 10,381 $ 663,984 63.96 10,026 $ 650,959 64.93
Northern Tier Energy LP [Member]
Inventory [Line Items]
Schedule of Inventory, Current [Table Text Block]	September 30, December 31, (in millions) 2016 2015 Crude oil and refinery feedstocks $ 158.8 $ 171.8 Refined products 161.6 162.0 Merchandise 22.6 22.8 Supplies and sundry items 20.1 19.0 363.1 375.6 Lower of cost or market inventory reserve (72.6 ) (134.4 ) Total $ 290.5 $ 241.2

Property, Plant and Equipment34

Property, Plant and Equipment, Net (Tables)	9 Months Ended
	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment [Table Text Block]	Property, plant and equipment, net was as follows: September 30, December 31, (In thousands) Refinery facilities and related equipment $ 2,198,560 $ 2,113,650 Pipelines, terminals and transportation equipment 553,402 427,854 Retail facilities and related equipment 327,898 324,686 Wholesale facilities and related equipment 53,190 59,875 Corporate 52,105 50,607 3,185,155 2,976,672 Accumulated depreciation (1,070,501 ) (923,415 ) 2,114,654 2,053,257 Construction in progress 242,637 251,914 Property, plant and equipment, net $ 2,357,291 $ 2,305,171
Northern Tier Energy LP [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment [Table Text Block]	Major classes of property, plant and equipment (“PP&E”) consisted of the following: Estimated September 30, December 31, (in millions) Useful Lives 2016 2015 Land $ 7.1 $ 9.0 Retail stores and equipment 2 - 22 years 76.6 72.3 Refinery and equipment 5 - 24 years 431.6 457.2 Buildings and building improvements 25 years 13.0 11.7 Software 5 years 18.9 18.9 Vehicles 5 years 5.8 5.6 Other equipment 2 - 7 years 12.0 10.4 Precious metals 10.4 10.2 Assets under construction 119.1 73.3 694.5 668.6 Less: Accumulated depreciation (190.2 ) (180.8 ) Property, plant and equipment, net $ 504.3 $ 487.8

Intangible Assets, Net (Tables)

Intangible Assets, Net (Tables)	9 Months Ended
	Sep. 30, 2016
Intangible Assets, Net (Excluding Goodwill) [Abstract]
Schedule of Intangible Assets and Goodwill [Table Text Block]	Intangible assets, net was as follows: September 30, 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 (In thousands) Amortizable assets: Licenses and permits $ 20,427 $ (14,913 ) $ 5,514 $ 20,427 $ (13,729 ) $ 6,698 3.5 Customer relationships 7,172 (4,102 ) 3,070 7,551 (3,921 ) 3,630 5.8 Rights-of-way and other 7,889 (2,388 ) 5,501 6,839 (1,797 ) 5,042 5.5 35,488 (21,403 ) 14,085 34,817 (19,447 ) 15,370 Unamortizable assets: Franchise rights and trademarks 50,500 — 50,500 50,500 — 50,500 Liquor licenses 19,958 — 19,958 19,075 — 19,075 Intangible assets, net $ 105,946 $ (21,403 ) $ 84,543 $ 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 $ 720 2017 2,880 2018 2,880 2019 2,212 2020 1,268 2021 980

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Schedule of Debt [Table Text Block]	Long-term debt was as follows: September 30, December 31, (In thousands) Western obligations: Revolving Credit Facility due 2019 $ — $ — Term Loan - 5.25% Credit Facility due 2020 534,875 539,000 6.25% Senior Unsecured Notes due 2021 350,000 350,000 Term Loan - 5.50% Credit Facility due 2023 498,750 — Total Western obligations 1,383,625 889,000 NTI obligations: Revolving Credit Facility due 2019 52,000 — 7.125% Senior Secured Notes due 2020 350,000 350,000 Total NTI obligations 402,000 350,000 WNRL obligations: Revolving Credit Facility due 2018 20,300 145,000 7.5% Senior Notes due 2023 300,000 300,000 Total WNRL obligations 320,300 445,000 Less unamortized discount, premium and debt issuance costs 50,245 33,606 Long-term debt 2,055,680 1,650,394 Current portion of long-term debt (10,500 ) (5,500 ) Long-term debt, net of current portion $ 2,045,180 $ 1,644,894 As of September 30, 2016 , annual maturities of long-term debt for the remainder of 2016 are $2.6 million . For 2017, 2018, 2019 and 2020, long-term debt maturities are $10.5 million , $30.8 million , $62.5 million and $872.0 million , respectively. Thereafter, total long-term debt maturities are $1,127.5 million . Interest and debt expense were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Contractual interest: Western obligations $ 20,475 $ 12,150 $ 45,606 $ 36,250 NTI obligations 6,918 6,970 20,707 20,173 WNRL obligations 6,039 5,854 19,144 15,481 33,432 24,974 85,457 71,904 Amortization of loan fees 2,479 1,932 6,395 5,630 Amortization of original issuance discount 381 — 410 — Other interest expense 1,287 747 3,727 2,973 Capitalized interest (3,123 ) (757 ) (7,924 ) (1,338 ) Interest and debt expense $ 34,456 $ 26,896 $ 88,065 $ 79,169

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2016
Distribution Made to Limited Partner [Line Items]
Schedule of Stockholders Equity [Table Text Block]	Changes to equity during the nine months ended September 30, 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 134,528 52,229 186,757 Other comprehensive loss, net of tax (52 ) (70 ) (122 ) Dividends (111,555 ) — (111,555 ) Stock-based compensation 6,264 5,203 11,467 Tax deficiency from stock-based compensation (434 ) — (434 ) Distributions to non-controlling interests — (49,906 ) (49,906 ) NTI merger (14,020 ) (1,329,348 ) (1,343,368 ) Transaction costs for NTI merger (11,741 ) — (11,741 ) Issuance of WNRL common units — 277,751 277,751 Offering costs for issuance of WNRL common units — (477 ) (477 ) Treasury stock issuance 438,168 — 438,168 Treasury stock purchases (75,000 ) — (75,000 ) Balance at September 30, 2016 $ 1,665,455 $ 601,991 $ 2,267,446 Changes to equity during the nine months ended September 30, 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 393,211 213,722 606,933 Other comprehensive income, net of tax 65 66 131 Dividends (93,612 ) — (93,612 ) Stock-based compensation 3,216 8,814 12,030 Excess tax benefit from stock-based compensation 879 — 879 Distributions to non-controlling interests — (176,289 ) (176,289 ) Treasury stock purchases (105,000 ) — (105,000 ) Other — (221 ) (221 ) Balance at September 30, 2015 $ 1,318,467 $ 1,714,028 $ 3,032,495
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 Shares purchased during Q2, 2016 — — Shares purchased at June 30, 2016 2,462,350 75,000 Shares purchased during Q3, 2016 — — Shares purchased at September 30, 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 April 8 April 18 May 2 0.38 34,685 Third quarter July 15 July 25 August 9 0.38 41,202 Fourth quarter (1) October 13 October 24 November 8 0.38 — Total $ 111,488 (1) The fourth quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $41.2 million .
Northern Tier Energy LP [Member]
Distribution Made to Limited Partner [Line Items]
Schedule of Stockholders Equity [Table Text Block]	(in millions) Partners' Capital Accumulated Other Comprehensive Income Total Partners' Equity Balance at December 31, 2015 $ 392.9 $ 0.2 $ 393.1 Net income 88.9 — 88.9 Asset sale to entity under common control 146.1 — 146.1 Distributions (52.7 ) — (52.7 ) Equity-based compensation expense 10.4 — 10.4 Other (0.3 ) — (0.3 ) Amortization of net prior service cost and deferred loss on defined benefit plans — (0.2 ) (0.2 ) Balance at September 30, 2016 $ 585.3 $ — $ 585.3
Distributions Made to Limited Partner, by Distribution [Table Text Block]	The table below summarizes NTI's 2016 quarterly distribution declarations and payments: Declaration Date Record Date Payment Date Distribution per Unit February 3, 2016 February 12, 2016 February 19, 2016 $ 0.38 June 13, 2016 June 23, 2016 June 23, 2016 0.18 Total $ 0.56 The following table details the quarterly distributions paid to common unitholders for each of the quarters in the year ended December 31, 2015 and the nine months ended September 30, 2016 : Date Declared Date Paid Common Units and equivalents at record date (in millions) Distribution per common unit and equivalent Total Distribution (in millions) 2015 Distributions: February 5, 2015 February 27, 2015 93.7 $ 0.49 $ 45.9 May 5, 2015 May 29, 2015 93.7 1.08 100.8 August 4, 2015 August 28, 2015 93.7 1.19 111.3 November 3, 2015 November 25, 2015 93.7 1.04 97.3 Total distributions paid during 2015 $ 3.80 $ 355.3 2016 Distributions: February 3, 2016 February 19, 2016 94.2 $ 0.38 $ 36.0 June 13, 2016 June 23, 2016 93.0 0.18 16.7 Total distributions paid during 2016 $ 0.56 $ 52.7
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 July 26, 2016 August 12, 2016 August 26, 2016 0.4125 October 24, 2016 November 7, 2016 November 23, 2016 0.4225 Total $ 1.6300 In addition to its quarterly distributions, WNRL paid incentive distributions of $1.2 million , $2.9 million , $0.3 million and $0.5 million for the three and nine months ended September 30, 2016 and 2015 , respectively, to Western as its general partner and holder of its incentive distribution rights.

Retirement Plans (Tables)

Retirement Plans (Tables)	9 Months Ended
	Sep. 30, 2016
Compensation and Retirement Disclosure [Abstract]
Schedule of Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]	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 Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Beginning of period balance $ 599 $ (1,234 ) $ 651 $ (1,291 ) Amortization of net prior service cost — — (63 ) 41 Reclassification of loss to income — 13 11 38 Income tax — (5 ) — (14 ) End of period balance $ 599 $ (1,226 ) $ 599 $ (1,226 )

Crude Oil and Refined Product39

Crude Oil and Refined Product Risk Management (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative [Line Items]
Derivative Instruments, Gain (Loss) [Table Text Block]	The following tables summarize our economic hedging activity recognized within cost of products sold for the three and nine months ended September 30, 2016 and 2015 , and open commodity hedging positions as of September 30, 2016 and December 31, 2015 : Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Economic hedging results Realized hedging gain, net $ 27,757 $ 26,949 $ 46,110 $ 52,325 Unrealized hedging gain (loss), net (27,616 ) 271 (54,698 ) (42,073 ) Total hedging gain (loss), net $ 141 $ 27,220 $ (8,588 ) $ 10,252 September 30, December 31, (In thousands) Open commodity hedging instruments (barrels) Crude oil differential swaps, net long positions 5,622 5,155 Crude oil futures, net short positions (687 ) (562 ) Refined product price and crack spread swaps, net short positions (3,902 ) (5,645 ) Total open commodity hedging instruments, net long (short) positions 1,033 (1,052 ) Fair value of outstanding contracts, net Other current assets $ 26,757 $ 78,125 Other assets 2,851 11,881 Accrued liabilities (4,457 ) (10,273 ) Other long-term liabilities (153 ) — Fair value of outstanding contracts - unrealized gain, net $ 24,998 $ 79,733
Offsetting Assets [Table Text Block]	The following table presents offsetting information regarding Western's commodity hedging contracts as of September 30, 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 September 30, 2016 (In thousands) Financial assets: Current assets $ 34,060 $ (7,303 ) $ 26,757 Other assets 4,455 (1,604 ) 2,851 Financial liabilities: Accrued liabilities (10,449 ) 5,992 (4,457 ) Other long-term liabilities (3,068 ) 2,915 (153 ) $ 24,998 $ — $ 24,998 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 (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 Inventory positions (futures and swaps): Crude oil differential swaps, net long positions 3,042 2,580 Crude oil futures, net short positions (687 ) — Distillate - net short positions (137 ) — Refined products - net short positions (315 ) (875 ) Natural gas futures - net long positions 151 329 Refined product positions (crack spread swaps): Distillate - net short positions (850 ) (1,680 ) Unleaded gasoline - net short positions (525 ) —
Northern Tier Energy LP [Member]
Derivative [Line Items]
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location [Table Text Block]	The tables below, however, are presented on a gross asset and gross liability basis. September 30, 2016 (in millions) Balance Sheet Location Assets Liabilities Commodity instruments: Swaps Other current assets $ 4.0 $ 2.2 Swaps Accrued liabilities 0.5 0.9 Swaps Other assets 1.3 0.8 Futures Accrued liabilities — 2.8 Forwards Other current assets 2.4 — Forwards Accrued liabilities — 2.9 Total $ 8.2 $ 9.6 December 31, 2015 (in millions) Balance Sheet Location Assets Liabilities Commodity instruments: Swaps Accrued liabilities $ — $ 7.9 Futures Other current assets 0.4 — Forwards Other current assets 1.5 — Forwards Accrued liabilities — 1.5 Total $ 1.9 $ 9.4
Schedule of Derivative Instruments [Table Text Block]	At September 30, 2016 and December 31, 2015 , the Company had open commodity derivative instruments as follows: September 30, 2016 December 31, 2015 Crude oil and refined products (thousands of barrels): Futures - long — 90 Futures - short 869 933 Swaps - long 4,438 5,155 Swaps - short 750 525 Forwards - long 3,747 4,445 Forwards - short 2,863 2,572 Natural gas (thousands of MMBTUs): Swaps 1,598 1,554 The information below presents the notional volume of outstanding contracts by type of instrument and year of maturity at September 30, 2016 : Notional Contract Volumes by Year of Maturity 2016 2017 Crude oil and refined products (thousands of barrels): Futures - short 869 — Swaps - long 2,159 2,279 Swaps - short 750 — Forwards - long 3,747 — Forwards - short 2,863 — Natural gas (thousands of MMBTUs): Swaps 321 1,277
Derivative Instruments, Gain (Loss) [Table Text Block]	All derivative contracts are marked to market at period end and the resulting gains and losses are recognized in earnings. The following tables provide information about the gain or loss recognized in income on the Company's derivative instruments and the line items in the financial statements in which such gains and losses are reflected. Recognized gains and losses on derivatives were as follows: Three Months Ended Nine Months Ended (in millions) September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Gain (loss) on the change in fair value of outstanding derivatives $ (3.8 ) $ (1.3 ) $ 6.1 $ 0.3 Settled derivative gains (losses) (0.8 ) 3.9 (13.6 ) 1.1 Total recognized gain (loss) $ (4.6 ) $ 2.6 $ (7.5 ) $ 1.4 Gain (loss) recognized in cost of sales $ (4.4 ) $ 3.4 $ (8.2 ) $ 3.3 Gain (loss) recognized in operating expenses (0.2 ) (0.8 ) 0.7 (1.9 ) Total recognized net gain (loss) on derivatives $ (4.6 ) $ 2.6 $ (7.5 ) $ 1.4

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2016
Northern Tier Energy LP [Member]
Guarantor Obligations [Line Items]
Schedule of Asset Retirement Obligations [Table Text Block]	The following table summarizes the changes in asset retirement obligations: Nine Months Ended (in millions) September 30, 2016 September 30, 2015 Asset retirement obligation balance at beginning of period $ 2.4 $ 2.4 Costs incurred to remediate (0.2 ) (0.3 ) Accretion expense 0.2 0.2 Asset retirement obligation balance at end of period $ 2.4 $ 2.3

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2016
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 nine months ended September 30, 2016 : Number of Units Weighted Average Grant Date Fair Value Not vested at December 31, 2015 399,214 $ 37.43 Awards granted 375,774 28.52 Awards vested (109,634 ) 37.63 Awards forfeited (6,848 ) 43.81 Not vested at September 30, 2016 658,506 32.25
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 nine months ended September 30, 2016 , is set forth below: Number of Phantom Units Weighted Average Not vested at December 31, 2015 279,787 $ 28.06 Awards granted 101,955 22.69 Awards vested (86,406 ) 25.80 Awards forfeited (10,181 ) 31.87 Not vested at September 30, 2016 285,155 26.42
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 our phantom stock award activity under the NTI LTIP for the nine months ended September 30, 2016 , is set forth below: Number of Phantom Stock Weighted Average Not vested at December 31, 2015 — $ — Awards granted 848,267 20.25 Awards vested (13,817 ) 20.25 Awards forfeited (12,132 ) 20.25 Not vested at September 30, 2016 822,318 20.25
Northern Tier Energy LP [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]	Number of phantom common units Weighted Weighted (in thousands) Average Grant Average Term Service-Based Performance-Based Total Date Value Until Maturity Nonvested at December 31, 2015 581.9 260.7 842.6 $ 24.00 1.5 Awarded 381.0 163.6 544.6 $ 25.87 2.5 Incremental performance units — 231.8 231.8 $ 27.82 2.0 Forfeited (16.5 ) (19.1 ) (35.6 ) $ 25.36 — Vested (269.2 ) (1.8 ) (271.0 ) $ 24.10 — Exchanged due to merger (677.2 ) (635.2 ) (1,312.4 ) $ 25.45 2.0 Nonvested at September 30, 2016 — — — $ — —
Restricted Stock [Member] | Northern Tier Energy LP [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 service-based restricted common unit activity is set forth below: Number of Weighted Weighted restricted common units Average Grant Average Term (in thousands) Date Value Until Maturity Nonvested at December 31, 2015 191.5 $ 24.75 1.0 Forfeited (12.3 ) $ 25.57 — Vested (34.5 ) $ 26.83 — Exchanged due to merger (144.7 ) $ 24.18 0.5 Nonvested at September 30, 2016 — $ — —

Earnings per Share (Tables)

Earnings per Share (Tables)	9 Months Ended
	Sep. 30, 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 Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands, except per share data) Basic earnings per common share: Allocation of earnings: Net income attributable to Western Refining, Inc. $ 38,575 $ 153,303 $ 134,528 $ 393,211 Distributed earnings (41,269 ) (32,498 ) (111,555 ) (93,612 ) Undistributed income (loss) attributable to Western Refining, Inc. $ (2,694 ) $ 120,805 $ 22,973 $ 299,599 Weighted-average number of common shares outstanding 108,424 94,826 97,802 95,308 Basic earnings per common share: Distributed earnings per share $ 0.38 $ 0.34 $ 1.14 $ 0.98 Undistributed earnings (loss) per share (0.02 ) 1.27 0.23 3.14 Basic earnings per common share $ 0.36 $ 1.61 $ 1.37 $ 4.12 Diluted earnings per common share: Net income attributable to Western Refining, Inc. $ 38,575 $ 153,303 $ 134,528 $ 393,211 Weighted-average diluted common shares outstanding 108,734 94,924 98,110 95,408 Diluted earnings per common share $ 0.35 $ 1.61 $ 1.37 $ 4.12
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 Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Weighted-average number of common shares outstanding 108,424 94,826 97,802 95,308 Restricted share units and phantom stock 310 98 308 100 Weighted-average number of diluted shares outstanding 108,734 94,924 98,110 95,408

Cash Flows (Tables)

Cash Flows (Tables)	9 Months Ended
	Sep. 30, 2016
Other Significant Noncash Transactions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	Supplemental Cash Flow Information Supplemental disclosures of cash flow information were as follows: Nine Months Ended September 30, 2016 2015 (In thousands) Non-cash operating activities were as follows: Income taxes paid $ 40,562 $ 210,656 Interest paid, excluding amounts capitalized 83,156 62,216 Non-cash investing activities were as follows: Assets acquired through capital lease obligations $ 4,644 $ 24,578 Accrued capital expenditures 33,111 31,744 PP&E derecognized from sale leaseback continuing involvement release 2,799 1,773 Transfer of capital spares from fixed asset to inventory — 1,490 Transfer of capital spares from fixed assets to other assets 699 — Transfer of capital spares from other assets to fixed assets 161 — Non-cash financing activities were as follows: Reduction of long-term debt proceeds from original issuance discount $ 10,250 $ — Treasury stock issuance 438,168 — Distributions accrued on unvested equity awards — 2,602 Distributions receivable from equity method investee — 4,250 Accrued offering costs for issuance of WNRL common units 60 —
Northern Tier Energy LP [Member]
Other Significant Noncash Transactions [Line Items]
Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]	Supplemental cash flow information is as follows: Nine Months Ended (in millions) September 30, 2016 September 30, 2015 Net cash from operating activities included: Interest paid $ 15.2 $ 15.6 Income taxes paid 0.1 2.7 Noncash investing activities included: Capital expenditures included in accounts payable $ 15.6 $ 9.6 PP&E derecognized from sale leaseback continuing involvement release 2.8 1.8 Book value of tank and terminal related assets sold to WNRL 48.9 — Common equity investment in WNRL 14.0 — PP&E additions resulting from a capital lease 0.3 — Noncash financing activities included: Distributions accrued on unvested equity awards $ — $ 2.6 Increase in equity due to proceeds received exceeding book value of assets sold to WNRL 146.1 — We reported the cash proceeds from the sale of the SPPR Logistics Assets to WNRL as restricted cash in our Condensed Consolidated Balance Sheet at September 30, 2016 . This cash is restricted until the earlier of a) use of the cash to invest in capital projects to replace the collateral assets that we sold, b) acceptance by holders of our 2020 Secured Notes of an offer to repurchase such notes at par or c) expiration of an offer to repurchase for cash up to $195.0 million aggregate principal amount the 2020 Secured Notes. The Company commenced a tender offer to repurchase the 2020 Secured Notes on October 17, 2016, and such offer expires on November 15, 2016. Any cash remaining after the offer to repurchase expires will become unrestricted and available for general corporate purposes.

Leases and Other Commitments (T

Leases and Other Commitments (Tables)	9 Months Ended
	Sep. 30, 2016
Leases [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	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 September 30, 2016 : Operating Capital Remaining 2016 $ 14,021 $ 1,380 2017 54,078 5,419 2018 50,739 5,444 2019 45,648 5,553 2020 41,467 5,744 2021 and thereafter 346,889 73,027 Total minimum lease payments $ 552,842 96,567 Less amount that represents interest 40,951 Present value of net minimum capital lease payments $ 55,616

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2016
Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Schedule of Related Party Transactions [Table Text Block]	he Company engaged in the following related party transactions with unconsolidated affiliates for the three and nine months ended September 30, 2016 and 2015 : Three Months Ended Nine Months Ended (in millions) Location in Statement of Operations and Comprehensive Income September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Western Refining: Asphalt sales Revenue $ 8.9 $ 7.5 $ 28.0 $ 35.3 Feedstock sales Revenue — 0.1 — 0.6 Railcar rental Revenue 0.1 — 0.2 0.2 Refined product purchases Cost of sales — 1.5 — 1.5 Tank and terminal service fees Cost of sales 1.9 — 1.9 — Shared services purchases Selling, general and administrative expenses 0.8 1.0 2.5 2.6 Minnesota Pipe Line Company: Pipeline transportation purchases Cost of sales 12.3 13.9 41.1 41.3 The Company had the following outstanding receivables and payables with non-consolidated related parties at September 30, 2016 and December 31, 2015 : (in millions) Balance Sheet Location September 30, 2016 December 31, 2015 Net receivable (payable) with related party: Western Refining, Inc. Accounts receivable, net $ 1.9 $ 2.8 Western Refining Logistics, LP Accounts payable (1.2 ) — Minnesota Pipe Line Company Accounts payable (1.2 ) (2.7 )

Condensed Consolidating Finan46

Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Condensed Balance Sheet [Table Text Block]	CONDENSED CONSOLIDATING BALANCE SHEETS As of September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ 21 $ 234,970 $ 31,105 $ — $ 266,096 Restricted cash — — 195,000 — 195,000 Accounts receivable, trade, net of a reserve for doubtful accounts — 137,775 309,552 — 447,327 Accounts receivable, affiliate 15,778 71,656 3,378 (90,812 ) — Inventories — 380,161 280,577 — 660,738 Prepaid expenses — 104,195 24,943 — 129,138 Other current assets — 83,042 38,539 — 121,581 Total current assets 15,799 1,011,799 883,094 (90,812 ) 1,819,880 Equity method investment — — 98,185 — 98,185 Property, plant and equipment, net — 1,114,593 1,242,698 — 2,357,291 Goodwill — — 1,289,443 — 1,289,443 Intangible assets, net — 31,947 52,596 — 84,543 Investment in subsidiaries 5,462,120 — — (5,462,120 ) — Due from affiliate — 2,460,977 — (2,460,977 ) — Other assets, net — 32,195 33,588 — 65,783 Total assets $ 5,477,919 $ 4,651,511 $ 3,599,604 $ (8,013,909 ) $ 5,715,125 LIABILITIES AND EQUITY Current liabilities: Accounts payable, trade $ — $ 306,033 $ 328,683 $ — $ 634,716 Accounts payable, affiliate — — 90,812 (90,812 ) — Accrued liabilities 10,960 107,907 97,302 — 216,169 Current portion of long-term debt 10,500 — — — 10,500 Total current liabilities 21,460 413,940 516,797 (90,812 ) 861,385 Long-term liabilities: Long-term debt, less current portion 1,330,027 — 715,153 — 2,045,180 Due to affiliate 2,460,977 — — (2,460,977 ) — Lease financing obligations — 45,333 9,208 — 54,541 Deferred income tax liability, net — 380,508 36,443 — 416,951 Deficit in subsidiaries — 497,548 — (497,548 ) — Other liabilities — 59,349 10,273 — 69,622 Total long-term liabilities 3,791,004 982,738 771,077 (2,958,525 ) 2,586,294 Equity: Equity - Western 1,665,455 3,254,833 1,709,739 (4,964,572 ) 1,665,455 Equity - Non-controlling interests — — 601,991 — 601,991 Total equity 1,665,455 3,254,833 2,311,730 (4,964,572 ) 2,267,446 Total liabilities and equity $ 5,477,919 $ 4,651,511 $ 3,599,604 $ (8,013,909 ) $ 5,715,125 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 3,791,084 — — (3,791,084 ) — Due from affiliate — 1,623,553 — (1,623,553 ) — Other assets, net — 42,166 22,831 — 64,997 Total assets $ 3,791,105 $ 4,203,549 $ 3,312,431 $ (5,473,692 ) $ 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 1,623,553 — — (1,623,553 ) — Lease financing obligations — 42,168 11,064 — 53,232 Deferred income tax liability, net — 275,634 37,280 — 312,914 Deficit in subsidiaries — 287,761 — (287,761 ) — Other liabilities — 63,674 4,921 — 68,595 Total long-term liabilities 2,479,880 669,237 841,832 (1,911,314 ) 2,079,635 Equity: Equity - Western 1,299,297 3,129,505 373,818 (3,503,323 ) 1,299,297 Equity - Non-controlling interests — — 1,646,609 — 1,646,609 Total equity 1,299,297 3,129,505 2,020,427 (3,503,323 ) 2,945,906 Total liabilities and equity $ 3,791,105 $ 4,203,549 $ 3,312,431 $ (5,473,692 ) $ 5,833,393
Condensed Income Statement [Table Text Block]	CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Nine Months Ended September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 4,466,234 $ 3,881,556 $ (2,719,902 ) $ 5,627,888 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 3,780,557 3,196,344 (2,719,902 ) 4,256,999 Direct operating expenses (exclusive of depreciation and amortization) — 333,556 353,751 — 687,307 Selling, general and administrative expenses 139 82,283 84,235 — 166,657 Gain on disposal of assets, net — (208 ) (973 ) — (1,181 ) Maintenance turnaround expense — 891 26,842 — 27,733 Depreciation and amortization — 79,620 81,711 — 161,331 Total operating costs and expenses 139 4,276,699 3,741,910 (2,719,902 ) 5,298,846 Operating income (loss) (139 ) 189,535 139,646 — 329,042 Other income (expense): Equity in earnings of subsidiaries 184,428 5,689 — (190,117 ) — Interest income — 317 119 — 436 Interest and debt expense (49,761 ) (2,284 ) (36,020 ) — (88,065 ) Other, net — (208 ) 14,033 — 13,825 Income (loss) before income taxes 134,528 193,049 117,778 (190,117 ) 255,238 Provision for income taxes — (67,721 ) (760 ) — (68,481 ) Net income (loss) 134,528 125,328 117,018 (190,117 ) 186,757 Less net income attributable to non-controlling interests — — 52,229 — 52,229 Net income (loss) attributable to Western Refining, Inc. $ 134,528 $ 125,328 $ 64,789 $ (190,117 ) $ 134,528 Comprehensive income attributable to Western Refining, Inc. $ 134,528 $ 125,328 $ 64,737 $ (190,117 ) $ 134,476 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Three Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 1,846,297 $ 1,478,695 $ (755,902 ) $ 2,569,090 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 1,476,431 1,175,243 (755,902 ) 1,895,772 Direct operating expenses (exclusive of depreciation and amortization) — 111,871 122,569 — 234,440 Selling, general and administrative expenses 48 28,061 26,356 — 54,465 Gain on disposal of assets, net — (6 ) (46 ) — (52 ) Maintenance turnaround expense — 490 — — 490 Depreciation and amortization — 24,830 26,547 — 51,377 Total operating costs and expenses 48 1,641,677 1,350,669 (755,902 ) 2,236,492 Operating income (loss) (48 ) 204,620 128,026 — 332,598 Other income (expense): Equity in earnings of subsidiaries 166,608 6,647 — (173,255 ) — Interest income — 106 80 — 186 Interest and debt expense (13,257 ) (703 ) (12,936 ) — (26,896 ) Other, net — (6 ) 4,333 — 4,327 Income (loss) before income taxes 153,303 210,664 119,503 (173,255 ) 310,215 Provision for income taxes — (92,114 ) (3 ) — (92,117 ) Net income (loss) 153,303 118,550 119,500 (173,255 ) 218,098 Less net income attributable to non-controlling interests — — 64,795 — 64,795 Net income (loss) attributable to Western Refining, Inc. $ 153,303 $ 118,550 $ 54,705 $ (173,255 ) $ 153,303 Comprehensive income attributable to Western Refining, Inc. $ 153,303 $ 118,558 $ 54,705 $ (173,255 ) $ 153,311 CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS AND COMPREHENSIVE INCOME Nine Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Net sales $ — $ 5,611,815 $ 4,372,591 $ (2,267,694 ) $ 7,716,712 Operating costs and expenses: Cost of products sold (exclusive of depreciation and amortization) — 4,612,431 3,470,232 (2,267,694 ) 5,814,969 Direct operating expenses (exclusive of depreciation and amortization) — 331,423 343,051 — 674,474 Selling, general and administrative expenses 142 87,486 82,180 — 169,808 Loss (gain) on disposal of assets, net — 444 (601 ) — (157 ) Maintenance turnaround expense — 1,188 — — 1,188 Depreciation and amortization — 74,457 77,989 — 152,446 Total operating costs and expenses 142 5,107,429 3,972,851 (2,267,694 ) 6,812,728 Operating income (loss) (142 ) 504,386 399,740 — 903,984 Other income (expense): Equity in earnings of subsidiaries 433,921 8,576 — (442,497 ) — Interest income — 308 242 — 550 Interest and debt expense (40,568 ) (1,943 ) (36,658 ) — (79,169 ) Other, net — (519 ) 12,076 — 11,557 Income (loss) before income taxes 393,211 510,808 375,400 (442,497 ) 836,922 Provision for income taxes — (229,635 ) (354 ) — (229,989 ) Net income (loss) 393,211 281,173 375,046 (442,497 ) 606,933 Less net income attributable to non-controlling interests — — 213,722 — 213,722 Net income (loss) attributable to Western Refining, Inc. $ 393,211 $ 281,173 $ 161,324 $ (442,497 ) $ 393,211 Comprehensive income attributable to Western Refining, Inc. $ 393,211 $ 281,197 $ 161,365 $ (442,497 ) $ 393,276
Condensed Cash Flow Statement [Table Text Block]	CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS Nine Months Ended September 30, 2016 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Cash flows from operating activities: Net cash provided by (used in) operating activities $ (42,552 ) $ 226,792 $ 141,120 $ (47,483 ) $ 277,877 Cash flows from investing activities: Capital expenditures — (113,533 ) (121,804 ) 240 (235,097 ) Return of capital from equity method investment 13,537 — — (13,537 ) — Increase in restricted cash — — (195,000 ) — (195,000 ) Use of restricted cash — 69,106 — — 69,106 Contributions to affiliate — (603,987 ) (20,286 ) 624,273 — Proceeds from the sale of assets — 348 3,804 (240 ) 3,912 Net cash provided by (used in) investing activities 13,537 (648,066 ) (333,286 ) 610,736 (357,079 ) Cash flows from financing activities: Additions to long-term debt 500,000 — — — 500,000 Payments on long-term debt and capital lease obligations (5,375 ) (748 ) (1,027 ) — (7,150 ) Borrowings on revolving credit facility — — 393,900 — 393,900 Repayments on revolving credit facility — — (466,600 ) — (466,600 ) Payments for NTI units related to merger (859,893 ) — — — (859,893 ) Transaction costs for NTI merger (11,741 ) — — — (11,741 ) Proceeds from issuance of WNRL common units — — 277,751 — 277,751 Offering costs for issuance of WNRL common units — — (417 ) — (417 ) Deferred financing costs (11,408 ) — (1,002 ) — (12,410 ) Distribution to affiliate — — (61,020 ) 61,020 — Purchases of common stock for treasury (75,000 ) — — — (75,000 ) Distribution to non-controlling interest holders — — (54,115 ) — (54,115 ) Dividends paid (111,555 ) — — — (111,555 ) Contributions from affiliates 603,987 — 20,286 (624,273 ) — Distribution to Western Refining, Inc. — — — — — Excess tax benefit from stock-based compensation — 26 — — 26 Net cash provided by (used in) financing activities 29,015 (722 ) 107,756 (563,253 ) (427,204 ) Net decrease in cash and cash equivalents — (421,996 ) (84,410 ) — (506,406 ) Cash and cash equivalents at beginning of year 21 656,966 115,515 — 772,502 Cash and cash equivalents at end of year $ 21 $ 234,970 $ 31,105 $ — $ 266,096 CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS Nine Months Ended September 30, 2015 (In thousands) Parent Guarantor Subsidiaries Non-Guarantors Eliminations Consolidated Cash flows from operating activities: Net cash provided by (used in) operating activities $ 67,772 $ 345,293 $ 383,762 $ (131,163 ) $ 665,664 Cash flows from investing activities: Capital expenditures — (108,988 ) (88,545 ) 1,557 (195,976 ) Use of restricted cash — 154,681 — — 154,681 Return of capital from equity method investment — — 5,780 — 5,780 Contributions to affiliate — (158,652 ) (18,457 ) 177,109 — Proceeds from the sale of assets — 2,028 590 (1,557 ) 1,061 Net cash provided by (used in) investing activities — (110,931 ) (100,632 ) 177,109 (34,454 ) Cash flows from financing activities: Additions to long-term debt — — 300,000 — 300,000 Payments on long-term debt and capital lease obligations (4,125 ) (658 ) (776 ) — (5,559 ) Repayments on revolving credit facility — — (269,000 ) — (269,000 ) Distribution to affiliate — — (131,163 ) 131,163 — Deferred financing costs — — (6,820 ) — (6,820 ) Purchases of common stock for treasury (105,000 ) — — — (105,000 ) Distribution to non-controlling interest holders — — (173,687 ) — (173,687 ) Dividends paid (93,612 ) — — — (93,612 ) Contributions from affiliates 134,965 — 42,144 (177,109 ) — Excess tax benefit from stock-based compensation — 879 — — 879 Net cash provided by (used in) financing activities (67,772 ) 221 (239,302 ) (45,946 ) (352,799 ) Net increase in cash and cash equivalents — 234,583 43,828 — 278,411 Cash and cash equivalents at beginning of year 21 288,986 142,152 — 431,159 Cash and cash equivalents at end of year $ 21 $ 523,569 $ 185,980 $ — $ 709,570

Acquisitions (Tables)

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Restructuring Cost and Reserve [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]	The consolidated statements of operations include the results of the Merger beginning on June 23, 2016. The following unaudited pro forma information assumes that (i) the Merger occurred on January 1, 2015; (ii) $500.0 million was borrowed to fund the Merger consideration on January 1, 2015, resulting in increased interest and debt expense of $17.0 million for the nine months ended September 30, 2016 and $9.1 million and $27.1 million for the three and nine months ended September 30, 2015 , respectively; and (iii) income tax expense increased as a result of the increased net income attributable to Western Refining, Inc. offset by increased interest and debt expense of $7.0 million for the nine months ended September 30, 2016 and $19.1 million and $64.9 million , for the three and nine months ended September 30, 2015 , respectively. Unaudited Pro Forma for the Three Months Ended Nine Months Ended September 30, September 30, 2015 2016 2015 (In thousands) Net sales $ 2,569,090 $ 5,627,888 $ 7,716,712 Operating income 332,598 329,042 903,984 Net income 189,905 162,768 514,874 Net income attributable to Western Refining, Inc. 184,319 145,862 498,715 Basic earnings per share $ 1.65 $ 1.35 $ 4.43 Diluted earnings per share 1.65 1.34 4.43 Merger and Reorganization Expenses We incurred professional service fees in connection with the Merger transaction. Additionally, we incurred costs associated with initiating a plan of reorganization for various positions during the third quarter of 2016. In relation to this reorganization plan, it was determined that certain employees would be terminated during 2016 and 2017. We recognized $2.8 million and $4.0 million of expense during the three and nine months ended September 30, 2016 , respectively, which included compensation related to the severance of employment and retention bonuses for selected employees. These costs have been included in Other, net in the accompanying Condensed Consolidated Statements of Operations. All reorganization and related costs are recognized in the Other category. We recognize these costs ratably from September 1, 2016, the effective date of the agreements, through the remaining service period, which varies for each employee, but in no case is later than September 1, 2017. As of September 30, 2016 , we anticipate that these costs will continue to be recognized through the third quarter of 2017 and for the expenses to be completely paid out by December 31, 2017. The following table summarizes the expense activity related to the Merger and Reorganization for the three and nine months ended September 30, 2016 : Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Beginning liability for merger and reorganization costs $ 452 $ 470 $ 189 $ 808 Third-party professional service fees 178 — 1,321 — Reorganization and related personnel costs incurred during period 2,666 — 2,666 — Cash payments to third-party professional service providers (442 ) — (1,133 ) — Cash payments made to severed employees (1,487 ) (112 ) (1,676 ) (450 ) Ending liability for merger and reorganization costs $ 1,367 $ 358 $ 1,367 $ 358
Restructuring and Related Costs [Table Text Block]	The following table summarizes the expense activity related to the Merger and Reorganization for the three and nine months ended September 30, 2016 : Three Months Ended Nine Months Ended September 30, September 30, 2016 2015 2016 2015 (In thousands) Beginning liability for merger and reorganization costs $ 452 $ 470 $ 189 $ 808 Third-party professional service fees 178 — 1,321 — Reorganization and related personnel costs incurred during period 2,666 — 2,666 — Cash payments to third-party professional service providers (442 ) — (1,133 ) — Cash payments made to severed employees (1,487 ) (112 ) (1,676 ) (450 ) Ending liability for merger and reorganization costs $ 1,367 $ 358 $ 1,367 $ 358
Northern Tier Energy LP [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Costs [Table Text Block]		The following table summarizes the merger-related expense activity for the three and nine months ended September 30, 2016 : Three Months Ended Nine Months Ended (in millions) September 30, 2016 September 30, 2015 September 30, 2016 September 30, 2015 Beginning liability for merger and reorganization costs $ 0.4 $ 0.5 $ 0.2 $ 0.8 Third-party professional service fees 0.2 — 1.3 — Reorganization and related personnel costs incurred during period 1.3 — 1.3 — Cash payments to third-party professional service providers (0.4 ) — (1.1 ) — Cash payments made to severed employees (0.4 ) (0.1 ) (0.6 ) (0.4 ) Ending liability for merger and reorganization costs $ 1.1 $ 0.4 $ 1.1 $ 0.4

Organization (WNR Organization)

Organization (WNR Organization) (Details)	3 Months Ended	9 Months Ended
	Mar. 31, 2016	Sep. 30, 2016operating_segmentsstores_stationsrefineriesStoreSegment
Segment Reporting Information [Line Items]
Number of Reportable Segments | operating_segments		3
Number of Stores | stores_stations		545
Retail network [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets | refineries		2
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | Segment		2
Number of Stores | Store		285
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	38.30%	100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		100.00%

Organization (WNR - Business Co

Organization (WNR - Business Combinations) (Details)	Sep. 14, 2016USD ($)shares	Dec. 21, 2015$ / sharesshares	Sep. 30, 2016$ / sharesshares	Jun. 30, 2016shares	May 31, 2016shares	Sep. 30, 2016USD ($)$ / shares	Dec. 31, 2015USD ($)mibbl	Jun. 23, 2016USD ($)
TexNew Mex 16 inch pipeline [Member]
Business Acquisition [Line Items]
Proceeds from Divestiture of Businesses							$ 170,000,000
Pipelines [Member] | TexNew Mex 16 inch pipeline [Member]
Business Acquisition [Line Items]
Pipeline, Miles | mi							375
Western Refining Logistics, LP [Member]
Business Acquisition [Line Items]
Partners' Capital Account, Units, Sold in Public Offering | shares				562,500	3,750,000
Western Refining Logistics, LP [Member] | St. Paul Park Logistics Assets [Member]
Business Acquisition [Line Items]
Proceeds from Divestiture of Businesses						$ 195,000,000
Western Refining Logistics, LP [Member] | Gas Gathering and Processing Equipment [Member] | Crude Oil Storage Tanks [Member] | TexNew Mex 16 inch pipeline [Member]
Business Acquisition [Line Items]
Long-term Purchase Commitment, Minimum Volume Required | bbl							80,000
TexNew Mex Units [Member] | Western Refining Logistics, LP [Member] | TexNew Mex 16 inch pipeline [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable							$ 80,000
Common Units [Member] | Western Refining Logistics, LP [Member] | St. Paul Park Logistics Assets [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable	$ 628,224
Common Units [Member] | Western Refining Logistics, LP [Member] | TexNew Mex 16 inch pipeline [Member]
Business Acquisition [Line Items]
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable							$ 421,031
Minimum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit | $ / shares		$ 15
Maximum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit | $ / shares			$ 15.357			$ 15.357
Common Stock [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit | $ / shares		$ 0.2986
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | shares		17,100,000
Common Stock [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit | $ / shares			$ 0.28896			$ 0.28896
Common Stock [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit | $ / shares		$ 0.7036
Line of Credit [Member] | Term Loan, due 2023 [Member]
Business Acquisition [Line Items]
Debt Instrument, Face Amount								$ 500,000,000
Common Units [Member]
Business Acquisition [Line Items]
Partners' Capital Account, Units, Sold in Public Offering | shares			1,125,000
Common Units [Member] | Western Refining Logistics, LP [Member]
Business Acquisition [Line Items]
Partners' Capital Account, Units, Sold in Public Offering | shares	7,500,000

Organization (WNR - Equity) (De

Organization (WNR - Equity) (Details) - shares	1 Months Ended		3 Months Ended	9 Months Ended
	Jun. 30, 2016	May 31, 2016	Mar. 31, 2016	Sep. 30, 2016
Northern Tier Energy LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			38.30%	100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Western Refining Logistics GP, LLC [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Western Refining Logistics, LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				52.60%
Partners' Capital Account, Units, Sold in Public Offering	562,500	3,750,000
Investor [Member] | Northern Tier Energy LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Investor [Member] | Western Refining Logistics, LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				47.40%

Organization (NTI Organization)

Organization (NTI Organization) (Details) $ / shares in Units, $ in Thousands, shares in Millions	Dec. 21, 2015$ / sharesshares	Sep. 30, 2016USD ($)stores_stationsStore$ / sharesbbl	Sep. 30, 2015USD ($)
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Proceeds from the sale of assets | $		$ 3,912	$ 1,061
Number of Stores | stores_stations		545
Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		100.00%
Number of Stores | Store		285
Northern Tier Energy LP [Member] | Subsidiaries [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Equity Method Investment, Ownership Percentage		100.00%
MPL Investments Inc. [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Equity Method Investment, Ownership Percentage		17.00%
Minnesota Pipe Line Company [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Preferred Interest By Parent		100.00%
Crude Oil Pipeline Capacity | bbl		465,000
St Paul Park Refining Company [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Number Of Barrels Of Refinery Crude Oil Capacity Per Stream Day | bbl		98,000
Minnesota Pipe Line Company, LLC [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Equity Method Investment, Ownership Percentage		17.00%
Investor [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest		100.00%
Minimum [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Cash payments to acquire business, per unit	$ 15
Minimum [Member] | Northern Tier Unitholders [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Cash payments to acquire business, per unit	15
Maximum [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Cash payments to acquire business, per unit		$ 15.357
Entity Operated Units [Member] | Northern Tier Retail Company [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Number of Stores | Store		170
Franchised Units [Member] | Super America Franchising Company [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Number of Stores | Store		115
Common Stock [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | shares	17.1
Common Stock [Member] | Northern Tier Unitholders [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Common Stock [Member] | Western Refining, Inc. [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | shares	17.1
Common Stock [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Payment of shares to acquire business, per unit		$ 0.28896
Common Stock [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Common Stock [Member] | Maximum [Member] | NTI Public Unitholder [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Restricted cash [Member] | Western Refining Logistics, LP [Member] | St. Paul Park Logistics Assets [Member]
Organization Consolidation And Presentation Of Financial Statements Disclosure [Line Items]
Other Significant Noncash Transaction, Value of Consideration Received | $		$ 195,000

Basis of Presentation and Sig52

Basis of Presentation and Significant Accounting Policies (WNR) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Mar. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Non-controlling interests		$ 601,991	$ 1,646,609
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%	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		52.60%
Northern Tier Energy LP [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%

Basis of Presentation and Sig53

Basis of Presentation and Significant Accounting Policies (NTI) (Details) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016USD ($)stores_stationsStore	Mar. 31, 2016	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)operating_segmentsstores_stationsStoreSegment	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Segment Reporting Information [Line Items]
Cost Method Investments | $	$ 6.8			$ 6.8		$ 6.8
Number of Reportable Segments | operating_segments				3
Number of Stores | stores_stations	545			545
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%		100.00%
Number of Reportable Segments | Segment				2
Number of Stores	285			285
Maximum Ethanol Volume				15.00%
Excise and Sales Taxes | $	$ 104.6		$ 93.6	$ 323.5	$ 296.6
St Paul Park Refining Company [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				1.00%
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				52.60%
Entity Operated Units [Member] | Northern Tier Retail Company [Member]
Segment Reporting Information [Line Items]
Number of Stores	170			170
Franchised Units [Member] | Super America Franchising Company [Member]
Segment Reporting Information [Line Items]
Number of Stores	115			115
Minimum [Member] | Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Required Frequency Of Maintenance				1 year
Maximum [Member] | Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Required Frequency Of Maintenance				6 years

Segment Information (WNR - Addi

Segment Information (WNR - Additional Information) (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)stores_stationsrefineriesStoremibbl	Sep. 30, 2015USD ($)stores_stations	Sep. 30, 2016USD ($)operating_segmentsstores_stationsrefineriesStoreSegmentmibbl	Sep. 30, 2015USD ($)stores_stations	Jun. 30, 2016stores_stations	Dec. 31, 2015USD ($)
Segment Reporting Information [Line Items]
Number of Reportable Segments | operating_segments			3
Derivative, Gain (Loss) on Derivative, Net	$ 141	$ 27,220	$ (8,588)	$ 10,252
Number of Stores | stores_stations	545		545
Inventory, Change in Lower of Cost or Market Reserve	$ (15,200)	$ 36,800	$ (102,500)	$ (17,100)
Refining Group [Member] | Refining Equipment [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets | refineries	3		3
Retail Group [Member]
Segment Reporting Information [Line Items]
Number of Stores | stores_stations	260	261	260	261
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Pipeline, Miles | mi	692		692
Active Storage Capacity | bbl	12,400,000		12,400,000
Non-Staffed Fueling Locations [Member] | Retail Group [Member]
Segment Reporting Information [Line Items]
Number of Stores | stores_stations		52		52	51
Glencore Supply Agreement [Member] | Refining Group [Member]
Segment Reporting Information [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 6,100	$ 23,300	$ 32,100	$ 39,300
Net Assets	$ 4,000		$ 4,000			$ 1,800
El Paso Facility [Member] | Refining Group [Member] | Refining Equipment [Member]
Segment Reporting Information [Line Items]
Active Storage Capacity | bbl	131,000		131,000
Gallup Facility [Member] | Refining Group [Member] | Refining Equipment [Member]
Segment Reporting Information [Line Items]
Active Storage Capacity | bbl	25,000		25,000
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | Segment			2
Derivative, Gain (Loss) on Derivative, Net	$ (4,600)	2,600	$ (7,500)	1,400
Number of Stores | Store	285		285
Cost of Sales [Member] | Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (4,400)	$ 3,400	$ (8,200)	$ 3,300
RetailGroup_UpperGreatPlains [Member] | Wholly Owned Properties [Member] | Retail Group [Member]
Segment Reporting Information [Line Items]
Number of Stores | stores_stations	170		170
RetailGroup_UpperGreatPlains [Member] | Retail Group [Member] | Franchised Units [Member]
Segment Reporting Information [Line Items]
Number of Stores | stores_stations	115		115

(WNR - Segment Financial Inform

(WNR - Segment Financial Information) (Details) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2016USD ($)stores_stationsrefineries	Sep. 30, 2015USD ($)stores_stations		Sep. 30, 2016USD ($)stores_stationsrefineries		Sep. 30, 2015USD ($)stores_stations		Dec. 31, 2015USD ($)
Segment Reporting Information [Line Items]
Net sales	$ 2,065,076	$ 2,569,090		$ 5,627,888		$ 7,716,712
Operating income	86,943	332,598		329,042		903,984
Other income (expense), net	(30,935)	(22,383)		(73,804)		(67,062)
Income before income taxes	56,008	310,215		255,238		836,922
Depreciation and amortization	54,321	51,377		161,331		152,446
Capital expenditures	78,337	76,431		235,097		195,976
Goodwill	1,289,443			1,289,443				$ 1,289,443
Total assets	$ 5,715,125	5,840,393		$ 5,715,125		5,840,393		$ 5,833,393
Number of Stores | stores_stations	545			545
Refining Group [Member]
Segment Reporting Information [Line Items]
Revenues	$ (1,099,307)	(1,474,374)		$ (2,936,525)		(4,555,005)	[1]
Operating income	89,158	312,602		338,803	[2]	900,405	[1],[2]
Depreciation and amortization	37,265	35,400		111,601		105,916	[1]
Capital expenditures	65,909	61,399		200,681		127,914	[1]
Total assets	4,394,967	3,574,746	[1]	4,394,967		3,574,746	[1]
Retail Group [Member]
Segment Reporting Information [Line Items]
Revenues	(579,662)	(631,005)		(1,588,562)		(1,744,986)
Operating income	11,832	24,937		21,193		36,356
Depreciation and amortization	5,710	5,846		17,622		17,257
Capital expenditures	3,593	3,903		8,528		13,175
Total assets	$ 430,363	$ 430,147		$ 430,363		$ 430,147
Number of Stores | stores_stations	260	261		260		261
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Operating income	$ (27,318)	$ (23,365)		$ (74,010)		$ (74,231)
Depreciation and amortization	767	1,168		2,638		3,457
Capital expenditures	305	481		1,510		2,737
Total assets	361,241	1,234,285		361,241		1,234,285
Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Revenues	(386,107)	(463,711)		(1,102,801)		(1,416,721)	[1]
Operating income	13,271	18,424		43,056		41,454	[1]
Depreciation and amortization	10,579	8,963		29,470		25,816	[1]
Capital expenditures	8,530	10,648		24,378		52,150	[1]
Total assets	528,554	601,215	[1]	528,554		601,215	[1]
Intersegment Eliminations [Member] | Refining Group [Member]
Segment Reporting Information [Line Items]
Revenues	(736,020)	(843,674)		(2,075,758)		(2,403,438)	[1]
Intersegment Eliminations [Member] | Retail Group [Member]
Segment Reporting Information [Line Items]
Revenues	(17,959)	(2,788)		(21,471)		(8,517)
Intersegment Eliminations [Member] | Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Revenues	(183,154)	(216,959)		(513,101)		(607,249)	[1]
Operating Segments [Member] | Refining Group [Member]
Segment Reporting Information [Line Items]
Revenues	(1,835,327)	(2,318,048)		(5,012,283)		(6,958,443)	[1]
Operating Segments [Member] | Retail Group [Member]
Segment Reporting Information [Line Items]
Revenues	(597,621)	(633,793)		(1,610,033)		(1,753,503)
Operating Segments [Member] | Western Refining Logistics, LP [Member]
Segment Reporting Information [Line Items]
Revenues	$ (569,261)	$ (680,670)		$ (1,615,902)		$ (2,023,970)	[1]
Refining Equipment [Member] | Refining Group [Member]
Segment Reporting Information [Line Items]
Property, Plant and Equipment, Operated, Number of Significant Assets | refineries	3			3
[1]	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 and nine months ended September 30, 2015. The information contained herein for WNRL has been retrospectively adjusted, to include the historical results of the St. Paul Park Logistics Assets and the TexNew Mex Pipeline System.
[2]	The effect of our economic hedging activity is included within the operating income of our refining segment as a component of cost of products sold. The cost of products sold within our refining segment included $0.1 million in net realized and unrealized economic hedging gains for the three months ended September 30, 2016, $8.6 million in net realized and unrealized economic hedging losses for the nine months ended September 30, 2016, respectively, and $27.2 million and $10.3 million in net realized and unrealized economic hedging gains for the three and nine months ended September 30, 2015, respectively.

Segment Information (NTI - Add

Segment Information (NTI - Additional Information) (Details)	9 Months Ended
	Sep. 30, 2016operating_segmentsstores_stationsStoreSegment
Segment Reporting Information [Line Items]
Number of Reportable Segments | operating_segments	3
Number of Stores | stores_stations	545
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Number of Reportable Segments | Segment	2
Number of Stores	285
Entity Operated Units [Member] | Northern Tier Retail Company [Member]
Segment Reporting Information [Line Items]
Number of Stores	170

Segment Information (NTI - Segm

Segment Information (NTI - Segment Financial Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating income	$ 86,943	$ 332,598	$ 329,042	$ 903,984
Depreciation and amortization	54,321	51,377	161,331	152,446
Capital expenditures	78,337	76,431	235,097	195,976
Total assets	5,715,125	5,840,393	5,715,125	5,840,393	$ 5,833,393
Northern Tier Energy LP [Member]
Segment Reporting Information [Line Items]
Revenues	(732,300)	(891,600)	(2,149,000)	(2,645,200)
Operating income	11,600	114,600	111,100	373,400
Income from equity method investment	5,300	4,200	15,300	12,000
Depreciation and amortization	12,100	11,000	35,000	32,600
Capital expenditures	44,500	17,500	99,200	35,200
Total assets	1,422,300		1,422,300		1,137,300
Northern Tier Energy LP [Member] | Refining [Member]
Segment Reporting Information [Line Items]
Revenues	(452,700)	(584,000)	(1,373,300)	(1,789,700)
Operating income	14,400	111,100	124,600	374,700
Income from equity method investment	5,300	4,200	15,300	12,000
Depreciation and amortization	9,700	8,800	27,900	26,300
Capital expenditures	42,800	16,400	95,700	30,700
Total assets	1,266,800		1,266,800		917,400
Northern Tier Energy LP [Member] | Retail [Member]
Segment Reporting Information [Line Items]
Revenues	(279,600)	(307,600)	(775,700)	(855,500)
Operating income	4,400	8,600	9,200	16,900
Income from equity method investment	0	0	0	0
Depreciation and amortization	2,200	2,000	6,500	5,700
Capital expenditures	1,600	1,100	3,200	4,200
Total assets	132,000		132,000		138,700
Northern Tier Energy LP [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(154,100)	(178,300)	(419,000)	(502,000)
Northern Tier Energy LP [Member] | Intersegment Eliminations [Member] | Refining [Member]
Segment Reporting Information [Line Items]
Revenues	(154,100)	(178,300)	(419,000)	(502,000)
Northern Tier Energy LP [Member] | Intersegment Eliminations [Member] | Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	(154,100)	(178,300)	(419,000)	(502,000)
Northern Tier Energy LP [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Revenues	(886,400)	(1,069,900)	(2,568,000)	(3,147,200)
Northern Tier Energy LP [Member] | Operating Segments [Member] | Refining [Member]
Segment Reporting Information [Line Items]
Revenues	(606,800)	(762,300)	(1,792,300)	(2,291,700)
Northern Tier Energy LP [Member] | Operating Segments [Member] | Retail [Member]
Segment Reporting Information [Line Items]
Revenues	(279,600)	(307,600)	(775,700)	(855,500)
Northern Tier Energy LP [Member] | Corporate and Other Reconciling Items [Member]
Segment Reporting Information [Line Items]
Total assets	23,500		23,500		$ 81,200
Northern Tier Energy LP [Member] | Corporate and Other Reconciling Items [Member] | Other Segments [Member]
Segment Reporting Information [Line Items]
Operating income	(7,200)	(5,100)	(22,700)	(18,200)
Income from equity method investment	0	0	0	0
Depreciation and amortization	200	200	600	600
Capital expenditures	$ 100	$ 0	$ 300	$ 300

Fair Value Measurement (Details

Fair Value Measurement (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash Equivalents, at Carrying Value	$ 0	$ 70,100
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Hypothetical Change in Estimated Future Cash Flows	$ (100)

(Assets & Liabilities) (Details

(Assets & Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	$ 24,998	$ 79,733
Commodity Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	24,998	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	24,998	79,733
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 1
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] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	25,759	85,489
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(761)	(5,756)
Commodity Contract [Member] | Other current assets | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	34,060	95,062
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	7,303	16,937
Derivative Asset	26,757	78,125
Commodity Contract [Member] | Other current assets | Fair Value, Measurements, Recurring [Member] | Level 1
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 | Fair Value, Measurements, Recurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	34,060	95,062
Commodity Contract [Member] | Other current assets | Fair Value, Measurements, Recurring [Member] | Level 3
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 | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,455	11,881
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	1,604	0
Derivative Asset	2,851	11,881
Commodity Contract [Member] | Other assets | Fair Value, Measurements, Recurring [Member] | Level 1
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 | Fair Value, Measurements, Recurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,455	11,881
Commodity Contract [Member] | Other assets | Fair Value, Measurements, Recurring [Member] | Level 3
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 | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(10,449)	(21,454)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	5,992	11,181
Derivative Liability	(4,457)	(10,273)
Commodity Contract [Member] | Accrued liabilities | Fair Value, Measurements, Recurring [Member] | Level 1
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 | Fair Value, Measurements, Recurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(9,688)	(15,698)
Commodity Contract [Member] | Accrued liabilities | Fair Value, Measurements, Recurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(761)	(5,756)
Commodity Contract [Member] | Other long-term liabilities | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(3,068)	(5,756)
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	2,915	5,756
Derivative Liability	(153)	0
Commodity Contract [Member] | Other long-term liabilities | Fair Value, Measurements, Recurring [Member] | Level 1
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 | Fair Value, Measurements, Recurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	(3,068)	(5,756)
Commodity Contract [Member] | Other long-term liabilities | Fair Value, Measurements, Recurring [Member] | Level 3
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

Fair Value Measurement (Level 3 Rollforward) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivative Asset			$ 79,733
Derivative Asset	$ 24,998		24,998
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Level 3
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Derivative Asset		$ 1,614		$ 330
Derivative Liability	(1,951)		(5,756)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Gain (Loss) Included in Earnings	237	(2,505)	537	0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Purchases	0	0	0	(1,262)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3	953	(288)	4,458	(247)
Derivative Liability	$ (761)	$ (1,179)	$ (761)	$ (1,179)

Fair Value Measurement (Fair Va

Fair Value Measurement (Fair Value, Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 2,055,680	$ 1,650,394
Western Refining, Inc. [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,383,625	889,000
Western Refining, Inc. [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	1,380,125	867,178
Northern Tier Energy LP [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	402,000	350,000
Northern Tier Energy LP [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	412,500	360,500
Western Refining Logistics, LP [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	320,300	445,000
Western Refining Logistics, LP [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value	$ 330,800	$ 439,000

Fair Value Measurement (NTI - A

Fair Value Measurement (NTI - Assets & Liabilities Carried at Fair Value, Measured on Recurring Basis) (Details) - Northern Tier Energy LP [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	$ 14.6	$ 70.9
Other Assets, Fair Value Disclosure	195
Derivative Asset, Current	4.1	1.9
Derivative Asset, Noncurrent	0.6
Assets, Fair Value Disclosure, Recurring	214.3	72.8
Derivative Liability, Current	6.1	9.4
Liabilities, Fair Value Disclosure, Recurring	6.1	9.4
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	14.6	70.9
Other Assets, Fair Value Disclosure	195
Derivative Asset, Current	0	0
Derivative Asset, Noncurrent	0
Assets, Fair Value Disclosure, Recurring	209.6	70.9
Derivative Liability, Current	0	0
Liabilities, Fair Value Disclosure, Recurring	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Other Assets, Fair Value Disclosure	0
Derivative Asset, Current	4.1	1.9
Derivative Asset, Noncurrent	0.6
Assets, Fair Value Disclosure, Recurring	4.7	1.9
Derivative Liability, Current	6.1	9.4
Liabilities, Fair Value Disclosure, Recurring	6.1	9.4
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Other Assets, Fair Value Disclosure	0
Derivative Asset, Current	0	0
Derivative Asset, Noncurrent	0
Assets, Fair Value Disclosure, Recurring	0	0
Derivative Liability, Current	0	0
Liabilities, Fair Value Disclosure, Recurring	$ 0	$ 0

Fair Value Measurement (NTI - F

Fair Value Measurement (NTI - Fair Value Measurement, Additional Information) (Details) - Northern Tier Energy LP [Member]	9 Months Ended
	Sep. 30, 2016USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Liability, Transfers Into Level 3	$ 0
Assets, Fair Value Adjustment	0
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Financial and Nonfinancial Liabilities, Fair Value Disclosure	$ 0

Fair Value Measurement (NTI -64

Fair Value Measurement (NTI - Fair Value of Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, less current portion	$ 2,045,180	$ 1,644,894
Northern Tier Energy LP [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, less current portion	395,500	342,000
Long-term Line of Credit	52,000
Northern Tier Energy LP [Member] | Senior Secured Notes Due Two Thousand Twenty [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, less current portion	350,000	350,000
Securities Borrowed, Fair Value Disclosure	52,000	0
Long-term Line of Credit	52,000	0
Notes Payable, Fair Value Disclosure	360,500	360,500
Long-term Debt, Gross	402,000	350,000
Debt Instrument, Fair Value Disclosure	$ 412,500	$ 360,500

Inventories (Inventory Summary)

Inventories (Inventory Summary) (Details) bbl in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)bbl
Inventory, Net [Abstract]
Refined products (1)	[1]	$ 259,125		$ 259,125		$ 201,928
Crude oil and other raw materials		348,109		348,109		288,403
Lubricants		11,118		11,118		14,996
Retail store merchandise		42,386		42,386		42,211
Inventories		660,738		660,738		$ 547,538
Inventory Adjustments [Abstract]
Inventory, Change in Lower of Cost or Market Reserve		$ (15,200)	$ 36,800	$ (102,500)	$ (17,100)
Inventory Valued Using LIFO | bbl		10,381		10,381		10,026
Inventory, LIFO Reserve		$ 193,300		$ 193,300		$ 198,400
Inventory, LIFO Reserve, Effect on Income, Net		(79,500)	$ (105,000)	5,100	$ (129,000)
Refined Products, Inventories [Member]
Inventory Adjustments [Abstract]
FIFO Inventory Amount		$ 15,800		$ 15,800		$ 14,500
[1]	Includes $15.8 million and $14.5 million of refined products inventory valued using the first-in, first-out ("FIFO") valuation method at September 30, 2016 and December 31, 2015, respectively.

Inventories (LIFO Cost per Barr

Inventories (LIFO Cost per Barrel) (Details) bbl in Thousands, $ in Thousands	Sep. 30, 2016USD ($)bbl$ / Barrel	Dec. 31, 2015USD ($)bbl$ / Barrel
Inventory Disclosure [Abstract]
Energy Related Inventory, Refined Products, Volume | bbl	4,033	3,536
Energy Related Inventory, Refined Products, LIFO Inventory Amount | $	$ 279,917	$ 259,722
Energy Related Inventory, Refined Products, Average Lifo Cost Per Barrel | $ / Barrel	69.41	73.45
Energy Related Inventory, Crude Oil and Natural Gas Liquids, Volume | bbl	6,348	6,490
Energy Related Inventory, Crude Oil and Natural Gas Liquids, LIFO Inventory Amount | $	$ 384,067	$ 391,237
Energy Related Inventory, Crude Oil and Natural Gas Liquids, Average LIFO Cost Per Barrel | $ / Barrel	60.50	60.28
Inventory Valued Using LIFO | bbl	10,381	10,026
LIFO Inventory Amount | $	$ 663,984	$ 650,959
Energy Related Inventory, Average LIFO Cost Per Barrel | $ / Barrel	63.96	64.93

Inventories (NTI Inventories) (

Inventories (NTI Inventories) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Inventory [Line Items]
Crude oil and other raw materials	$ 348,109	$ 288,403
Retail store merchandise	42,386	42,211
Inventory Valuation Reserves	72,600	175,100
Inventories	660,738	547,538
Northern Tier Energy LP [Member]
Inventory [Line Items]
Crude oil and other raw materials	158,800	171,800
Energy Related Inventory, Crude Oil, Products and Merchandise	161,600	162,000
Retail store merchandise	22,600	22,800
Inventory, Supplies, Net of Reserves	20,100	19,000
Inventory, Net Before Adjustments	363,100	375,600
Inventory Valuation Reserves	72,600	134,400
Inventories	$ 290,500	$ 241,200
Percentage of LIFO Inventory	88.00%	89.00%

Equity Method Investment (WNR)

Equity Method Investment (WNR) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 98,185,000		$ 98,185,000		$ 97,513,000
Income (Loss) from Equity Method Investments	$ 0	$ 0	$ 0	$ 0
Minnesota Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	17.00%		17.00%
Equity method investment	$ 98,200,000		$ 98,200,000		97,500,000
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	21,200,000		21,200,000		$ 21,300,000
Equity Method Investment, Quoted Market Value	0		0
Proceeds from Equity Method Investment, Dividends or Distributions	10,200,000	4,200,000	14,500,000	10,000,000
Income (Loss) from Equity Method Investments	$ 5,300,000	$ 4,200,000	$ 15,300,000	$ 12,000,000

Equity Method Investment (NTI)

Equity Method Investment (NTI) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 98,185			$ 98,185		$ 97,513
Distributions receivable from equity method investee	0		$ 4,250	0	$ 4,250
Income (Loss) from Equity Method Investments	0		0	0	0
Minnesota Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity method investment	98,200			98,200		97,500
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	21,200			21,200		21,300
Proceeds from Equity Method Investment, Dividends or Distributions	10,200		4,200	14,500	10,000
Income (Loss) from Equity Method Investments	5,300		4,200	$ 15,300	12,000
Northern Tier Energy LP [Member]
Schedule of Equity Method Investments [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest				17.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		38.30%		100.00%
Equity method investment	82,800			$ 82,800		82,100
Income (Loss) from Equity Method Investments				800	6,200
Northern Tier Energy LP [Member] | Minnesota Pipe Line Company [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity	5,800			5,800		$ 5,900
Proceeds from Equity Method Investment, Dividends or Distributions	10,200		4,200	14,500	10,000
Distributions receivable from equity method investee			4,200		4,200
Income (Loss) from Equity Method Investments	$ (5,300)		$ (4,200)	$ (15,300)	$ (12,000)
St Paul Park Refining Company [Member]
Schedule of Equity Method Investments [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest				1.00%

Property, Plant and Equipment70

Property, Plant and Equipment, Net (WNR PP&E) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross, Excluding Construction in Progress	$ 3,185,155		$ 3,185,155		$ 2,976,672
Accumulated depreciation	(1,070,501)		(1,070,501)		(923,415)
Property, plant and equipment, net, excluding construction in progress	2,114,654		2,114,654		2,053,257
Property, plant and equipment, net	2,357,291		2,357,291		2,305,171
Depreciation	53,300	$ 50,400	158,100	$ 149,300
Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,198,560		2,198,560		2,113,650
Pipelines [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	553,402		553,402		427,854
Retail [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	327,898		327,898		324,686
Wholesale Assets [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	53,190		53,190		59,875
Corporate and Other [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	52,105		52,105		50,607
Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 242,637		$ 242,637		$ 251,914

Property, Plant and Equipment71

Property, Plant and Equipment, Net (NTI PP&E) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	$ 1,070,501		$ 1,070,501		$ 923,415
Property, plant and equipment, net (WNRL: $0 and $321,251, respectively)	2,357,291		2,357,291		2,305,171
Retail [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	327,898		327,898		324,686
Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,198,560		2,198,560		2,113,650
Northern Tier Energy LP [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	694,500		694,500		668,600
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	190,200		190,200		180,800
Property, plant and equipment, net (WNRL: $0 and $321,251, respectively)	504,300		504,300		487,800
Capital Leased Assets, Gross	10,800		10,800		13,300
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation	2,100		2,100		2,000
Other Depreciation and Amortization	800	$ 900	2,800	$ 2,800
Interest Costs Capitalized	2,000	$ 0	4,900	$ 0
Northern Tier Energy LP [Member] | Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	7,100		7,100		9,000
Northern Tier Energy LP [Member] | Retail [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	76,600		76,600		72,300
Northern Tier Energy LP [Member] | Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	431,600		431,600		457,200
Northern Tier Energy LP [Member] | Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	13,000		$ 13,000		11,700
Property, Plant and Equipment, Useful Life			25 years
Northern Tier Energy LP [Member] | Computer Software, Intangible Asset [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	18,900		$ 18,900		18,900
Property, Plant and Equipment, Useful Life			5 years
Northern Tier Energy LP [Member] | Vehicles [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	5,800		$ 5,800		5,600
Property, Plant and Equipment, Useful Life			5 years
Northern Tier Energy LP [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	12,000		$ 12,000		10,400
Northern Tier Energy LP [Member] | Precious Metals [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	10,400		10,400		10,200
Northern Tier Energy LP [Member] | Asset under Construction [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$ 119,100		$ 119,100		$ 73,300
Minimum [Member] | Northern Tier Energy LP [Member] | Retail [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			2 years
Minimum [Member] | Northern Tier Energy LP [Member] | Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			5 years
Minimum [Member] | Northern Tier Energy LP [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			2 years
Maximum [Member] | Northern Tier Energy LP [Member] | Retail [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			22 years
Maximum [Member] | Northern Tier Energy LP [Member] | Refining Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			24 years
Maximum [Member] | Northern Tier Energy LP [Member] | Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life			7 years

Intangible Assets, Net Finite-L

Intangible Assets, Net Finite-Lived Intangibles (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 35,488		$ 35,488		$ 34,817
Finite-Lived Intangible Assets, Accumulated Amortization	21,403		21,403		19,447
Finite-Lived Intangible Assets, Net	14,085		14,085		15,370
Amortization of Intangible Assets	700	$ 700	2,200	$ 2,100
Finite-Lived Intangible Assets, Net, Amortization Expense, Rolling Maturity [Abstract]
Finite-Lived Intangible Assets, Amortization Expense, Remainder of Fiscal Year	720		720
Finite-Lived Intangible Assets, Amortization Expense, Year Two	2,880		2,880
Finite-Lived Intangible Assets, Amortization Expense, Year Three	2,880		2,880
Finite-Lived Intangible Assets, Amortization Expense, Year Four	2,212		2,212
Finite-Lived Intangible Assets, Amortization Expense, Year Five	1,268		1,268
Finite-Lived Intangible Assets, Amortization Expense, after Year Five	980		$ 980
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		20,427
Finite-Lived Intangible Assets, Accumulated Amortization	14,913		14,913		13,729
Finite-Lived Intangible Assets, Net	5,514		$ 5,514		6,698
Finite-Lived Intangible Asset, Useful Life			3 years 6 months 4 days
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	7,172		$ 7,172		7,551
Finite-Lived Intangible Assets, Accumulated Amortization	4,102		4,102		3,921
Finite-Lived Intangible Assets, Net	3,070		$ 3,070		3,630
Finite-Lived Intangible Asset, Useful Life			5 years 9 months 15 days
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	7,889		$ 7,889		6,839
Finite-Lived Intangible Assets, Accumulated Amortization	2,388		2,388		1,797
Finite-Lived Intangible Assets, Net	$ 5,501		$ 5,501		$ 5,042
Finite-Lived Intangible Asset, Useful Life			5 years 6 months 18 days

Intangible Assets, Net Indefini

Intangible Assets, Net Indefinite-Lived Intangibles (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Indefinite-lived Intangible Assets [Line Items]
Intangible Assets, Gross (Excluding Goodwill)	$ 105,946	$ 104,392
Finite-Lived Intangible Assets, Accumulated Amortization	21,403	19,447
Intangible assets, net	84,543	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)	$ 19,958	$ 19,075

Intangible Assets, Net NTI Inta

Intangible Assets, Net NTI Intangibles (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Indefinite-lived Intangible Assets [Line Items]
Intangible assets, net	$ 84,543	$ 84,945
Northern Tier Energy LP [Member]
Indefinite-lived Intangible Assets [Line Items]
Intangible assets, net	33,800	33,800
Indefinite-Lived Franchise Rights	12,400	12,400
Indefinite-Lived Trademarks	$ 21,400	$ 21,400

(Debt Summary) (Details)

(Debt Summary) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt	$ 2,055,680	$ 1,650,394
Debt Instrument, Unamortized Discount (Premium), Net	50,245	33,606
Current portion of long-term debt	10,500	5,500
Long-term debt, less current portion	2,045,180	1,644,894
Revolving Credit Facility [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Long-term debt	52,000
Western Refining, Inc. [Member]
Debt Instrument [Line Items]
Long-term debt	1,383,625	889,000
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	534,875	539,000
Western Refining, Inc. [Member] | Line of Credit [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Long-term debt	498,750	0
Western Refining, Inc. [Member] | Senior Notes [Member] | 6.25% Senior Notes due 2021 [Member]
Debt Instrument [Line Items]
Long-term debt	350,000	350,000
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Long-term debt	402,000	350,000
Long-term debt, less current portion	395,500	342,000
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	350,000
Western Refining Logistics, LP [Member]
Debt Instrument [Line Items]
Long-term debt	320,300	445,000
Western Refining Logistics, LP [Member] | Revolving Credit Facility [Member] | Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Long-term debt	20,300	145,000
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	$ 300,000

Long-Term Debt (Interest Expens

Long-Term Debt (Interest Expense and Other Financing Costs) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	$ 33,432	$ 24,974	$ 85,457	$ 71,904
Amortization of loan fees	2,479	1,932	6,395	5,630
Amortization of original issuance discount	381	0	410	0
Interest Income (Expense), Net	1,287	747	3,727	2,973
Capitalized interest	3,123	757	7,924	1,338
Interest Expense	34,456	26,896	88,065	79,169
Western Refining, Inc. [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	20,475	12,150	45,606	36,250
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	6,918	6,970	20,707	20,173
Interest Expense	5,800	7,500	18,500	22,500
Western Refining Logistics, LP [Member]
Debt Instrument [Line Items]
Interest Expense, Debt, Excluding Amortization	$ 6,039	$ 5,854	$ 19,144	$ 15,481

Long-Term Debt (Revolving Credi

Long-Term Debt (Revolving Credit Facilities) (Details)	Sep. 29, 2014USD ($)	Oct. 15, 2013	Sep. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 15, 2016USD ($)	Oct. 02, 2014USD ($)	Oct. 16, 2013USD ($)	Jul. 17, 2012USD ($)
Debt Instrument [Line Items]
Long-term debt			$ 2,055,680,000	$ 1,650,394,000		$ 2,055,680,000
Borrowings on revolving credit facility						393,900,000	$ 0
Repayments of Long-term Lines of Credit						466,600,000	$ 269,000,000
Loans [Member] | Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Long-term Line of Credit			$ 0			$ 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								$ 500,000,000		$ 300,000,000
Line of Credit Facility, Difference Between Current Borrowing Capacity and Maximum Borrowing Capacity								150,000,000
Line of Credit Facility, Maximum Borrowing Capacity								$ 650,000,000
Line of Credit Facility, Expiration Date		Oct. 16, 2018
Debt Instrument, Interest Rate, Stated Percentage			4.50%			4.50%
Borrowings on revolving credit facility			$ 20,300,000	145,000,000	$ 269,000,000
Repayments of Long-term Lines of Credit						$ 179,100,000
Debt Instrument, Interest Rate, Effective Percentage			3.34%			3.34%
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. 2, 2019
Line of Credit Facility, Remaining Borrowing Capacity			$ 257,000,000			$ 257,000,000
Long-term Line of Credit			0			$ 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, Expiration Date						Sep. 29, 2019
Line of Credit Facility, Remaining Borrowing Capacity			205,700,000			$ 205,700,000
Long-term debt			52,000,000			52,000,000
Letters of Credit Outstanding, Amount			$ 47,600,000			$ 47,600,000
Debt Instrument, Interest Rate, Effective Percentage			5.91%			5.91%
Revolving Credit Facility [Member] | Minimum [Member] | Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital								4.50
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] | Maximum [Member] | Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Ratio of Indebtedness to Net Capital								5
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] | Revolving Credit Agreement - WNRL [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Remaining Borrowing Capacity			$ 479,000,000			$ 479,000,000
Long-term Line of Credit			20,300,000			20,300,000
Letters of Credit Outstanding, Amount			700,000			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			100,100,000			100,100,000
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] | 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%
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] | 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] | 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%
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			305,300,000			305,300,000
Line of Credit Facility, Remaining Borrowing Capacity			205,700,000			205,700,000
Long-term debt			402,000,000	350,000,000		402,000,000
Borrowings on revolving credit facility						339,500,000	$ 0
Long-term Line of Credit			52,000,000			52,000,000
Letters of Credit Outstanding, Amount			$ 47,600,000			$ 47,600,000
Northern Tier Energy LP [Member] | Revolving Credit Facility [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 750,000,000
Long-term debt				$ 0
Northern Tier Energy LP [Member] | 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%
Northern Tier Energy LP [Member] | 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%
Northern Tier Energy LP [Member] | Base Rate [Member] | Revolving Credit Facility [Member] | Base Rate Loans [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%
Northern Tier Energy LP [Member] | Base Rate [Member] | Revolving Credit Facility [Member] | Base Rate Loans [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%
Northern Tier Energy LP [Member] | 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
Northern Tier Energy LP [Member] | London Interbank Offered Rate (LIBOR) [Member] | Revolving Credit Facility [Member] | Libor Indexed Loans [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%
Northern Tier Energy LP [Member] | London Interbank Offered Rate (LIBOR) [Member] | Revolving Credit Facility [Member] | Libor Indexed Loans [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) (De

Long-Term Debt (Term Loans) (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2016	Dec. 31, 2013	Jun. 23, 2016	May 27, 2016	Nov. 13, 2013	Mar. 25, 2013
Line of Credit [Member] | Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Unused Borrowing Capacity, Amount	$ 500
Debt Instrument, Face Amount					$ 550
Debt Instrument, Periodic Payment, Principal		$ 1.4
Line of Credit Facility, Maximum Borrowing Capacity				$ 700	$ 200
Debt Instrument, Interest Rate, Stated Percentage					5.25%
Debt Instrument, Interest Rate, Effective Percentage	5.80%
Line of Credit [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount			$ 500
Debt Instrument, Unamortized Discount (Premium) and Debt Issuance Costs, Net			$ 17
Debt Instrument, Periodic Payment, Principal	$ 1.3
Debt Instrument, Interest Rate, Stated Percentage			5.50%
Debt Instrument, Interest Rate, Effective Percentage	5.99%
Senior Notes [Member] | 6.25% Senior Notes due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount						$ 350
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%
Base Rate [Member] | Line of Credit [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.50%
London Interbank Offered Rate (LIBOR) [Member] | Line of Credit [Member] | Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		4.25%
London Interbank Offered Rate (LIBOR) [Member] | Line of Credit [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate	4.50%
London Interbank Offered Rate (LIBOR) [Member] | Line of Credit [Member] | Minimum [Member] | Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					1.00%
London Interbank Offered Rate (LIBOR) [Member] | Line of Credit [Member] | Minimum [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			1.00%

Long-Term Debt (Notes) (Details

Long-Term Debt (Notes) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2016	Sep. 30, 2015	Oct. 28, 2016	Jun. 23, 2016	Feb. 11, 2015	Sep. 25, 2014	Nov. 13, 2013	Nov. 12, 2013	Mar. 25, 2013	Nov. 08, 2012
Debt Instrument [Line Items]
Repayments of Long-term Lines of Credit		$ 466,600	$ 269,000
Additions to long-term debt		500,000	$ 300,000
Long-term Debt, Maturities, Repayments of Principal, Remainder of Fiscal Year		2,600
Long-term Debt, Maturities, Repayments of Principal in Year Two		10,500
Long-term Debt, Maturities, Repayments of Principal in Year Three		30,800
Long-term Debt, Maturities, Repayments of Principal in Year Four		62,500
Long-term Debt, Maturities, Repayments of Principal in Year Five		872,000
Long-term Debt, Maturities, Repayments of Principal after Year Five		$ 1,127,500
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
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%
Line of Credit [Member] | Term Loan, due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage								5.25%
Debt Instrument, Face Amount								$ 550,000
Debt Instrument, Interest Rate, Effective Percentage		5.80%
Line of Credit [Member] | Term Loan, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage					5.50%
Debt Instrument, Face Amount					$ 500,000
Debt Instrument, Interest Rate, Effective Percentage		5.99%
Subsequent Event [Member] | Senior Notes [Member] | 7.125% NTI Secured Notes, due 2020 [Member]
Debt Instrument [Line Items]
Tender offer, debt repayment				$ 195,000

Long-Term Debt (NTI Debt) (Deta

Long-Term Debt (NTI Debt) (Details) - USD ($) $ in Thousands	Sep. 29, 2014	Sep. 30, 2016	Dec. 31, 2015	Jul. 17, 2012
Debt Instrument [Line Items]
Long-term debt		$ 2,055,680	$ 1,650,394
Long-term debt, less current portion		2,045,180	1,644,894
Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Revolving Credit Facility Commitment Amount	$ 500,000
Long-term debt		402,000	350,000
Line of Credit Facility, Maximum Borrowing Capacity		305,300
Line of Credit Facility, Remaining Borrowing Capacity		205,700
Letters of Credit Outstanding, Amount		47,600
Long-term Line of Credit		52,000
Long-term debt, less current portion		$ 395,500	$ 342,000
Revolving Credit Facility [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Expiration Date		Sep. 29, 2019
Asset-based credit facility [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Payments of Debt Issuance Costs	3,000
Senior Secured Notes Due Two Thousand Twenty [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage			7.125%
Senior Secured Notes Due Two Thousand Twenty [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Long-term debt, less current portion			$ 350,000
Debt Instrument, Interest Rate, Stated Percentage		7.125%
Debt Instrument, Unamortized Premium	4,200
Debt Issuance Costs, Noncurrent, Net		$ 9,500	11,600
Percentage of Ownership of Direct and Indirect Subsidiaries, Subject to Guarantee Agreement		100.00%
NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Current Borrowing Capacity	500,000			$ 300,000
Line of Credit Facility, Expiration Date		Sep. 29, 2019
Long-term debt		$ 52,000
Debt Instrument, Interest Rate, Effective Percentage		5.91%
Line of Credit Facility, Remaining Borrowing Capacity		$ 205,700
Letters of Credit Outstanding, Amount		$ 47,600
NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Long-term debt			$ 0
Line of Credit Facility, Maximum Borrowing Capacity	$ 750,000
NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage		0.25%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	1.50%
NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage		0.375%
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage	2.00%
Base Rate [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Base Rate Loans [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		0.50%
Base Rate [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Base Rate Loans [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.00%
London Interbank Offered Rate (LIBOR) [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis		LIBOR
London Interbank Offered Rate (LIBOR) [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Libor Indexed Loans [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.50%
London Interbank Offered Rate (LIBOR) [Member] | NTI Senior Secured Asset-Based Revolving Credit Facility [Member] | Revolving Credit Facility [Member] | Libor Indexed Loans [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.00%

Equity (Equity Rollforward) (De

Equity (Equity Rollforward) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Schedule of Capitalization, Equity [Line Items]
Beginning Balance			$ 2,945,906	$ 2,787,644
Net income attributable to Western Refining, Inc.	$ 38,575	$ 153,303	134,528	393,211
Less net income attributable to non-controlling interests	5,733	64,795	52,229	213,722
Net income	44,308	218,098	186,757	606,933
Other Comprehensive Income (Loss), Net of Tax	0	8	(122)	131
Dividends			(111,555)	(93,612)
Stock-based compensation			11,467	12,030
Tax deficiency from stock-based compensation			434	879
Distributions to non-controlling interests			49,906	176,289
NTI merger			(1,343,368)	221
Transaction costs for NTI merger			11,741
Issuance of WNRL common units			277,751
Offering costs for issuance of WNRL common units			477
Treasury stock issuance			438,168
Treasury stock purchases			75,000	105,000
Ending Balance	2,267,446	3,032,495	2,267,446	3,032,495
Parent [Member]
Schedule of Capitalization, Equity [Line Items]
Beginning Balance			1,299,297	1,119,708
Other Comprehensive Income (Loss), Net of Tax			(52)	65
Dividends			(111,555)	(93,612)
Stock-based compensation			6,264	3,216
Tax deficiency from stock-based compensation			(434)	879
Distributions to non-controlling interests			0	0
Stock Issued During Period, Value, Acquisitions			(14,020)
NTI merger				0
Transaction costs for NTI merger			(11,741)
Issuance of WNRL common units			0
Offering costs for issuance of WNRL common units			0
Treasury stock issuance			438,168
Treasury stock purchases			75,000	105,000
Ending Balance	1,665,455	1,318,467	1,665,455	1,318,467
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			52,229	213,722
Other Comprehensive Income (Loss), Net of Tax			(70)	66
Dividends			0	0
Stock-based compensation			5,203	8,814
Tax deficiency from stock-based compensation			0	0
Distributions to non-controlling interests			49,906	176,289
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests			1,329,348
NTI merger				221
Transaction costs for NTI merger			0
Issuance of WNRL common units			277,751
Offering costs for issuance of WNRL common units			(477)
Treasury stock issuance			0
Treasury stock purchases			0	0
Ending Balance	$ 601,991	$ 1,714,028	$ 601,991	$ 1,714,028

Equity (Share Issuance) (Detail

Equity (Share Issuance) (Details) - Northern Tier Energy LP [Member] - Common Stock [Member] shares in Millions	Dec. 21, 2015shares
Class of Stock [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17.1
Stock Issued During Period, Shares, Treasury Stock Reissued	11.6

Equity (Share Repurchase Progra

Equity (Share Repurchase Program Summary) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2016	Sep. 30, 2015
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Authorized Amount	$ 200,000			$ 200,000
Disclosure of Repurchase Agreements [Abstract]
Treasury Stock, Shares			9,089,623	9,089,623
Payments for Repurchase of Equity [Abstract]
Treasury Stock, Value			$ 363,168	$ 363,168
Purchase of common stock for treasury				(75,000)	$ (105,000)
Treasury Stock, Value	0			0
Share Repurchase Program - Authorized September 2015 [Member]
Equity, Class of Treasury Stock [Line Items]
Stock Repurchase Program, Remaining Authorized Repurchase Amount	$ 125,000			$ 125,000
Disclosure of Repurchase Agreements [Abstract]
Treasury Stock, Shares	2,462,350	2,462,350	0	0
Treasury Stock, Shares, Acquired	0	0	2,462,350
Treasury Stock, Shares	2,462,350	2,462,350	2,462,350	2,462,350
Payments for Repurchase of Equity [Abstract]
Treasury Stock, Value	$ 75,000	$ 75,000	$ 0	$ 0
Purchase of common stock for treasury	0	0	(75,000)
Treasury Stock, Value	$ 75,000	$ 75,000	$ 75,000	$ 75,000

Equity (Dividends) (Details)

Equity (Dividends) (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended					9 Months Ended
		Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Dividends Payable [Line Items]
Payments of Ordinary Dividends, Common Stock			$ 41,202	$ 34,685	$ 35,601		$ 111,488
Cash dividends declared per common share			$ 0.38		$ 0.38	$ 0.34	$ 1.14	$ 0.98
Subsequent Event [Member]
Dividends Payable [Line Items]
Payments of Ordinary Dividends, Common Stock		$ 41,200
Cash dividends declared per common share	[1]	$ 0.38
[1]	(1) The fourth quarter 2016 cash dividend of $0.38 per common share will result in an estimated aggregate payment of $41.2 million.

Equity (Distributions) (Details

Equity (Distributions) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended					9 Months Ended		12 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2016
Northern Tier Energy LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0	$ 0.18	$ 0.38	$ 1.19	$ 0.56	$ 2.76
Western Refining Logistics, LP [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Distributions Declared, Per Unit		$ 0.4125	$ 0.4025	$ 0.3925
Incentive Distribution, Distribution		$ 1.2			$ 0.3	$ 2.9	$ 0.5
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							$ 1.6300

Equity (NTI - Equity Informatio

Equity (NTI - Equity Information) (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 21, 2015	Nov. 05, 2015	Sep. 30, 2016
Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid		$ 97.3	$ 52.7
Stock Issued During Period, Shares, Share-based Compensation, Net of Forfeitures			114,047
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			100.00%
Maximum Number Of Days For Cash Distribution To Unitholders			60 days
Investor [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			100.00%
Investor [Member] | Northern Tier Energy LP [Member] | Limited Partner [Member]
Limited Partners' Capital Account [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	100.00%
Minimum [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Cash payments to acquire business, per unit	$ 15
Minimum [Member] | Northern Tier Unitholders [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Limited Partners' Capital Account [Line Items]
Cash payments to acquire business, per unit	15
Maximum [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Cash payments to acquire business, per unit			$ 15.357
Common Stock [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17,100,000
Common Stock [Member] | Northern Tier Unitholders [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Limited Partners' Capital Account [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Common Stock [Member] | Western Refining, Inc. [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Limited Partners' Capital Account [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17,100,000
Common Stock [Member] | Minimum [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Payment of shares to acquire business, per unit			$ 0.28896
Common Stock [Member] | Maximum [Member] | Northern Tier Energy LP [Member]
Limited Partners' Capital Account [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Common Stock [Member] | Maximum [Member] | NTI Public Unitholder [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member]
Limited Partners' Capital Account [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036

Equity (NTI - Distribution Made

Equity (NTI - Distribution Made to Limited Partners) (Details) - Northern Tier Energy LP [Member] - USD ($) $ / shares in Units, $ in Millions	Jun. 14, 2016	Feb. 04, 2016	Nov. 05, 2015	Aug. 06, 2015	May 06, 2015	Feb. 06, 2015	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Nov. 03, 2015	Aug. 04, 2015
Distribution Made to Limited Partner [Line Items]
Maximum Number Of Days For Cash Distribution To Unitholders											60 days
Limited Partners' Capital Account, Units Outstanding							92,947,533				92,947,533		92,833,486
Distribution Made to Limited Partner, Distributions Declared, Per Unit							$ 0	$ 0.18	$ 0.38	$ 1.19	$ 0.56	$ 2.76
Distribution Made to Limited Partner, Cash Distributions Paid			$ 97.3								$ 52.7
Cash Distribution [Member]
Distribution Made to Limited Partner [Line Items]
Distribution Made to Limited Partner, Declaration Date	Jun. 13, 2016	Feb. 3, 2016	Nov. 3, 2015	Aug. 4, 2015	May 5, 2015	Feb. 5, 2015
Distribution Made to Limited Partner, Distribution Date	Jun. 23, 2016	Feb. 19, 2016	Nov. 25, 2015	Aug. 28, 2015	May 29, 2015	Feb. 27, 2015
Limited Partners' Capital Account, Units Outstanding		94,200,000			93,700,000	93,700,000	93,000,000				93,000,000			93,700,000	93,700,000
Distribution Made to Limited Partner, Distributions Declared, Per Unit	$ 0.18	$ 0.38	$ 1.04	$ 1.19	$ 1.08	$ 0.49					$ 0.56		$ 3.80
Distribution Made to Limited Partner, Cash Distributions Paid	$ 16.7	$ 36		$ 111.3	$ 100.8	$ 45.9					$ 52.7		$ 355.3

Equity (NTI - Equity Rollforwar

Equity (NTI - Equity Rollforward) (Details) - USD ($) $ in Thousands	Sep. 14, 2016	Nov. 05, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Class of Stock [Line Items]
Equity - Western					$ 1,299,297
Net income attributable to Western Refining, Inc.			$ 38,575	$ 153,303	134,528	$ 393,211
Offering costs for issuance of WNRL common units					477
Equity - Western			1,665,455		$ 1,665,455
Northern Tier Energy LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest					100.00%
Equity - Western					$ 393,100
Net income attributable to Western Refining, Inc.			3,600	$ 103,500	88,900	343,600
Offering costs for issuance of WNRL common units					146,100	$ 0
Distribution Made to Limited Partner, Cash Distributions Paid		$ 97,300			52,700
Stock Granted, Value, Share-based Compensation, Net of Forfeitures					10,400
Equity Based Compensation Reclassified to Liability					(300)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Tax					(200)
Equity - Western			585,300		585,300
Northern Tier Energy LP [Member] | AOCI Attributable to Parent [Member]
Class of Stock [Line Items]
Equity - Western					200
Net income attributable to Western Refining, Inc.					0
Offering costs for issuance of WNRL common units					0
Distribution Made to Limited Partner, Cash Distributions Paid					0
Stock Granted, Value, Share-based Compensation, Net of Forfeitures					0
Equity Based Compensation Reclassified to Liability					0
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Tax					(200)
Equity - Western			0		0
Northern Tier Energy LP [Member] | Common Units [Member]
Class of Stock [Line Items]
Equity - Western					392,900
Net income attributable to Western Refining, Inc.					88,900
Offering costs for issuance of WNRL common units	$ 146,100
Distribution Made to Limited Partner, Cash Distributions Paid					52,700
Stock Granted, Value, Share-based Compensation, Net of Forfeitures					10,400
Equity Based Compensation Reclassified to Liability					(300)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Tax					0
Equity - Western			$ 585,300		$ 585,300
Investor [Member] | Northern Tier Energy LP [Member]
Class of Stock [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest					100.00%

Income Taxes (WNR Income Taxes)

Income Taxes (WNR Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 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	(20.90%)	(29.70%)	(26.80%)	(27.50%)
Operating Loss Carryforwards, Reduction to Valuation Allowance			$ 0
Unrecognized tax benefits	$ 34.5		34.5
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	18.7		18.7
Unrecognized Tax Benefits, Period Increase (Decrease)	(6.7)		(5.7)
Decrease in Unrecognized Tax Benefits is Reasonably Possible	5.6		5.6
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0.4	$ 0.1	0.9	$ 0.3
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforwards, Valuation Allowance	$ 20.8		$ 20.8

Income Taxes (NTI Income Taxes)

Income Taxes (NTI Income Taxes) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Contingency [Line Items]
Effective Income Tax Rate Reconciliation, Percent	20.90%	29.70%	26.80%	27.50%
Northern Tier Energy LP [Member]
Income Tax Contingency [Line Items]
Effective Income Tax Rate Reconciliation, Percent	37.90%	3.40%	4.00%	2.10%
Effective Income Tax Rate Reconciliation At Statutory Income Tax Rate			40.40%	40.90%

Retirement Plans (WNR) (Details

Retirement Plans (WNR) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Cost Recognized	$ 4,500	$ 4,200	$ 13,600	$ 12,800
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Accumulated Other Comprehensive Income (Loss), Net of Tax			651	(1,291)
Amortization of net prior service cost	0	0	(63)	41
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, before Tax	0	13	11	38
Income tax	0	(5)	0	(14)
Accumulated Other Comprehensive Income (Loss), Net of Tax	599	(1,226)	599	(1,226)
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	600	700	1,800	1,900
Other Postretirement Benefit Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	30	200	100	700
Defined Benefit Plan, Benefit Obligation					$ 6,200
Northern Tier Energy LP [Member]
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Accumulated Other Comprehensive Income (Loss), Net of Tax			200
Accumulated Other Comprehensive Income (Loss), Net of Tax	0		0
Northern Tier Energy LP [Member] | Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$ 600	$ 600	$ 1,800	$ 1,900

Retirement Plans (NTI) (Details

Retirement Plans (NTI) (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)plan	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)plan	Sep. 30, 2015USD ($)
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Cost Recognized	$ 4.5	$ 4.2	$ 13.6	$ 12.8
Northern Tier Energy LP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Number Of Plans | plan	1		1
Other Postretirement Benefit Plan [Member] | Northern Tier Energy LP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Contribution Plan, Employer Non-matching Contribution, Percentage			3.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Match			100.00%
Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay			6.00%
Defined Contribution Plan, Cost Recognized	$ 1.8	1.6	$ 6	5.6
Pension Plan, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost	0.6	0.7	$ 1.8	1.9
Pension Plan, Defined Benefit [Member] | Northern Tier Energy LP [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Defined Benefit Plan Contributions By Employer Percentage Of Annual Compensation			5.00%
Us Treasury Bond Maturity Term Used To Determine Employer Contributions			30 years
Deferred Compensation Arrangement with Individual, Requisite Service Period			3 years
Net periodic benefit cost	$ 0.6	$ 0.6	$ 1.8	$ 1.9

(Risk Management) (Details)

(Risk Management) (Details) - Distillate Crack Spread Swaps [Member]	9 Months Ended
	Sep. 30, 2016$ / Incident
Minimum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	13.72
Maximum [Member]
Derivative [Line Items]
Underlying, Derivative Volume	16.86

Crude Oil and Refined Product94

Crude Oil and Refined Product Risk Management (Economic Hedging Activity) (Details) bbl in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)bbl	Sep. 30, 2015USD ($)bbl	Dec. 31, 2015USD ($)
Derivative [Line Items]
Realized Investment Gains (Losses) | $	$ 27,757	$ 26,949	$ 46,110	$ 52,325
Unrealized Gain (Loss) on Derivatives and Commodity Contracts | $	(27,616)	271	(54,698)	(42,073)
Derivative, Gain (Loss) on Derivative, Net | $	141	$ 27,220	(8,588)	$ 10,252
Derivative Asset | $	$ 24,998		$ 24,998		$ 79,733
Not Designated as Hedging Instrument [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume			(1,033)
Not Designated as Hedging Instrument [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume				(1,052)
Crude Oil [Member] | Not Designated as Hedging Instrument [Member] | Long [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume			(5,622)	(5,155)
Crude Oil [Member] | Not Designated as Hedging Instrument [Member] | Short [Member] | Future [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume			(687)	(562)
Fuel [Member] | Not Designated as Hedging Instrument [Member] | Short [Member] | Swap [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume			(3,902)	(5,645)

Crude Oil and Refined Product95

Crude Oil and Refined Product Risk Management (Derivative Instrument by Balance Sheet Location) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Asset	$ 24,998	$ 79,733
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	24,998	79,733
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset	24,998	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
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	34,060	95,062
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	7,303	16,937
Derivative Asset	26,757	78,125
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Other assets
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	4,455	11,881
Derivative Asset, Fair Value, Gross Liability and Obligation to Return Cash, Offset	1,604	0
Derivative Asset	2,851	11,881
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Accrued liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	10,449	21,454
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	5,992	11,181
Derivative Liability	(4,457)	(10,273)
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Other long-term liabilities
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Gross Liability	3,068	5,756
Derivative Liability, Fair Value, Gross Asset and Right to Reclaim Cash, Offset	2,915	5,756
Derivative Liability	$ (153)	$ 0

Crude Oil and Refined Product96

Crude Oil and Refined Product Risk Management (Notional Volume of Outstanding Contracts) (Details) - Not Designated as Hedging Instrument [Member] - bbl bbl in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume		(1,052)
Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,033)
Inventory Positions - Crude Oil - Differential Swaps - Current Fiscal Year [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(3,042)
Inventory Positions - Crude Oil - Differential Swaps - Year Two [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(2,580)
Inventory Positions - Crude Oil - Futures - Current Fiscal Year [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(687)
Inventory Positions - Crude Oil - Futures - Year Two [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	(315)
Inventory Positions - Refined Products - Futures & Swaps - Year Two [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(875)
Inventory Positions - Natural Gas - Futures & Swaps - Current Fiscal Year [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(151)
Inventory Positions - Natural Gas - Futures & Swaps - Year Two [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(329)
Refined Product Positions - Distillate - Crack Spread Swaps - Current Fiscal Year [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(850)
Refined Product Positions - Distillate - Crack Spread Swaps - Year Two [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(1,680)
Inventory Positions - Distillate - Crack Spread Swaps - Current Fiscal Year [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(137)
Inventory Positions - Distillate - Crack Spread Swaps - Year Two [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Refined Product Positions - Unleaded Gasoline - Crack Spread Swaps - Current Fiscal Year [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	(525)
Refined Product Positions - Unleaded Gasoline - Crack Spread Swaps - Year Two [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0

Crude Oil and Refined Product97

Crude Oil and Refined Product Risk Management (NTI - Notional Amounts & Derivative Maturities) (Details) - Northern Tier Energy LP [Member] bbl in Thousands, MMBTU in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2016MMBTUbbl	Dec. 31, 2015MMBTUbbl
Crude Oil And Refined Products [Member] | Future [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0	90
Crude Oil And Refined Products [Member] | Future [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	869	933
Crude Oil And Refined Products [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	4,438	5,155
Crude Oil And Refined Products [Member] | Swap [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	750	525
Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	3,747	4,445
Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	2,863	2,572
Natural Gas [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,598	1,554
Next Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Future [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Next Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	2,279
Next Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Swap [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Next Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Next Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	0
Next Fiscal Year [Member] | Natural Gas [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	1,277
Current Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Future [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	869
Current Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	2,159
Current Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Swap [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	750
Current Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	3,747
Current Fiscal Year [Member] | Crude Oil And Refined Products [Member] | Forward Contracts [Member] | Short [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Volume	2,863
Current Fiscal Year [Member] | Natural Gas [Member] | Swap [Member] | Long [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount, Energy Measure | MMBTU	321

Crude Oil and Refined Product98

Crude Oil and Refined Product Risk Management (NTI - Fair Value Amounts of Outstanding per Instrument) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Accrued liabilities | Future [Member]
Derivative [Line Items]
Derivative Asset, Current	$ 0
Derivative Liability, Current	2.8
Northern Tier Energy LP [Member]
Derivative [Line Items]
Derivative Asset, Current	4.1	$ 1.9
Derivative Liability, Current	6.1	9.4
Derivative Asset, Noncurrent	0.6
Derivative, Collateral, Right to Reclaim Cash	7.5	6
Northern Tier Energy LP [Member] | Other current assets | Swap [Member]
Derivative [Line Items]
Derivative Asset, Current	4
Derivative Liability, Current	2.2
Northern Tier Energy LP [Member] | Other current assets | Future [Member]
Derivative [Line Items]
Derivative Asset, Current		0.4
Derivative Liability, Current		0
Northern Tier Energy LP [Member] | Other current assets | Forward Contracts [Member]
Derivative [Line Items]
Derivative Asset, Current	2.4	1.5
Derivative Liability, Current	0	0
Northern Tier Energy LP [Member] | Other assets | Swap [Member]
Derivative [Line Items]
Derivative Asset, Noncurrent	1.3
Derivative Liability, Noncurrent	0.8
Northern Tier Energy LP [Member] | Accrued liabilities | Swap [Member]
Derivative [Line Items]
Derivative Asset, Current	0.5	0
Derivative Liability, Current	0.9	7.9
Northern Tier Energy LP [Member] | Accrued liabilities | Forward Contracts [Member]
Derivative [Line Items]
Derivative Asset, Current	0	0
Derivative Liability, Current	2.9	1.5
Northern Tier Energy LP [Member] | Assets [Member]
Derivative [Line Items]
Derivative Asset, Current	8.2	1.9
Northern Tier Energy LP [Member] | Liability [Member]
Derivative [Line Items]
Derivative Liability, Current	$ 9.6	$ 9.4

Crude Oil and Refined Product99

Crude Oil and Refined Product Risk Management (NTI - Recognized Gain & Loss on Derivatives) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 141	$ 27,220	$ (8,588)	$ 10,252
Northern Tier Energy LP [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives	(3,800)	(1,300)	6,100	300
Gain (Loss) on Sale of Derivatives	(800)	3,900	(13,600)	1,100
Derivative, Gain (Loss) on Derivative, Net	(4,600)	2,600	(7,500)	1,400
Northern Tier Energy LP [Member] | Cost of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(4,400)	3,400	(8,200)	3,300
Northern Tier Energy LP [Member] | Operating Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ (200)	$ (800)	$ 700	$ (1,900)

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - Northern Tier Energy LP [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Guarantor Obligations [Line Items]
Asset Retirement Obligation	$ 2.4	$ 2.3	$ 2.4	$ 2.4
Cost of Services, Environmental Remediation	0.2	0.3
Asset Retirement Obligation, Accretion Expense	$ 0.2	$ 0.2

Stock-Based Compensation (Stock

Stock-Based Compensation (Stock-Based Compensation, Western) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
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		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	2,391,711		2,391,711
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		$ 0.2		$ 6
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value		0.1	$ 0.3	3.7
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	$ 1.8	1.1	4.5	3.2
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested			3
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Weighted Average Grant Date Fair Value	21.2		21.2
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested	17.4		17.4
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	16.6		$ 16.6
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition			2 years 7 months 17 days
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation	$ 0	$ 0		$ (0.9)
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense			$ (0.4)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value			$ 4.1
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			375,774
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			(109,634)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period			(6,848)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	658,506		658,506
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			28.52
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			37.63
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	$ 32.25		$ 32.25
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 (St102

Stock-Based Compensation (Stock-Based Compensation, NTI) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
NTI 2012 LTIP [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Allocated Share-based Compensation Expense	$ 3	$ 2.4		$ 7.9
NTI 2012 LTIP [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	255,560		255,560
Allocated Share-based Compensation Expense			$ 11
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Weighted Average Grant Date Fair Value	$ 16.7		16.7
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested	21.8		21.8
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 11.4		$ 11.4
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition			1 year 6 months
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			0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period			848,267
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			13,817
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period			(12,132)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	822,318		822,318
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			$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value			20.25
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			20.25
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value			20.25
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 20.25		$ 20.25
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation	$ 0		$ 0
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, Vested in Period, Fair Value		0.1	$ 0.3	3.7
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Vested		$ 0.2		$ 6

Stock-Based Compensation (St103

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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Common Stock, Capital Shares Reserved for Future Issuance	4,098,368		4,098,368
Allocated Share-based Compensation Expense	$ 0.7	$ 0.6	$ 2	$ 1.5
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Total Weighted Average Grant Date Fair Value	7.5		7.5
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value, Nonvested	6.6		6.6
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$ 6.2		$ 6.2
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition			2 years 7 months 6 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			101,955
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period			(86,406)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period			(10,181)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	285,155		285,155
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			22.69
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value			25.80
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value			31.87
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 26.42		$ 26.42

Stock-Based Compensation (St104

Stock-Based Compensation (Stock-Based Compensation, NTI Information) (Details) - Northern Tier Energy LP [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Granted, Value, Share-based Compensation, Net of Forfeitures	$ 3	$ 2.4	$ 11	$ 7.9
Long Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred Compensation Arrangement with Individual, Common Stock Reserved for Future Issuance	200,000		200,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	800,000		800,000
Deferred Compensation Cash-based Arrangements, Liability, Current and Noncurrent	$ 9		$ 9
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options	$ 11.4		$ 11.4
Phantom Unit Award with Service-only Conditions [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, Nonvested, Number	0		0		581,900
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years

Stock-Based Compensation (St105

Stock-Based Compensation (Stock-Based Compensation, NTI Restricted Common Units) (Details) - Northern Tier Energy LP [Member] - Restricted Stock [Member] - $ / shares	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	191,500
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(12,300)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	34,500
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)	(144,700)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	0	191,500
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, Forfeitures, Weighted Average Grant Date Fair Value	25.57
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	26.83
Weighted Average Grant Date Fair Value, Equity Awards Other Than Options, Canceled Due to Merger	24.18
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 0	$ 24.75
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Terms	0 years	1 year
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Canceled, Weighted Average Remaining Contractual Terms	6 months

Stock-Based Compensation (St106

Stock-Based Compensation (Stock-Based Compensation, NTI Phantom Common Units) (Details) $ / shares in Units, $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2016USD ($)criteria$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Other liabilities | $	$ 69,622	$ 68,595
Northern Tier Energy LP [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Other liabilities | $	$ 25,700	$ 27,900
Northern Tier Energy LP [Member] | Western Refining Phantom Stock Units [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, Conversion Ratio	1.0323
Northern Tier Energy LP [Member] | Phantom Unit Award with Service-only Conditions [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity Awards Canceled Due to Business Combination	(677,200)
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	581,900
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	381,000
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(16,500)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(269,200)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	0	581,900
Northern Tier Energy LP [Member] | Western Phantom Unit Award with Service-only Conditions [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	800,000
Northern Tier Energy LP [Member] | Phantom Awards with Performance or Market Conditions [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of criteria in a performance-based equity award | criteria	2
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	4,600,000
Northern Tier Energy LP [Member] | Pre-Merger Period, Service Based Cash Denominated Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity Awards Canceled Due to Business Combination	(635,200)
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	260,700
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	163,600
Share-based Compensation Arrangement by Share-based Payment Award, Other Share Increase (Decrease)	231,800
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(19,100)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(1,800)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	0	260,700
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Cash Denominated Award Rate | $ / shares	$ 21.1049
Northern Tier Energy LP [Member] | Pre-Merger Period, Service Based Cash Denominated Awards [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, Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Terms	1 year 3 months 4 days
Other liabilities | $	$ 4,400
Northern Tier Energy LP [Member] | Phantom Share Units (PSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity Awards Canceled Due to Business Combination	(1,312,400)
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	842,600
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, Other Share Increase (Decrease)	231,800
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	(35,600)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	(271,000)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number	0	842,600
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 | $ / shares	$ 24
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ / shares	25.87
Share-based Compensation Arrangements by Share-based Payment Award, Options, Other Share Increase (Decrease) in Period, Weighted Average Exercise Price | $ / shares	27.82
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value | $ / shares	25.36
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value | $ / shares	24.10
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ / shares	$ 0	$ 24
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Outstanding, Weighted Average Remaining Contractual Terms	0 years	1 year 6 months
Share Based Compensation Arrangement By Share Based Payment Award Equity Instruments Other Than Options Grants In Period Weighted Average Remaining Contractual Terms	2 years 6 months
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Incremental Performance Units, Weighted Average Remaining Contractual Terms	2 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Canceled, Weighted Average Remaining Contractual Terms	2 years
Share Based Compensation Cancellation Due to Business Combination Weighted Average Grant Date Fair Value | $ / shares	$ 25.45
Minimum [Member] | Northern Tier Energy LP [Member] | Phantom Awards with Performance or Market Conditions [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Safety Multiple on Performance Awards	85.00%
Minimum [Member] | Northern Tier Energy LP [Member] | Pre-Merger Period, Service Based Cash Denominated Awards [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	5.00%
Maximum [Member] | Northern Tier Energy LP [Member] | Western Phantom Unit Award with Service-only Conditions [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	30.00%
Maximum [Member] | Northern Tier Energy LP [Member] | Phantom Awards with Performance or Market Conditions [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Safety Multiple on Performance Awards	115.00%
Maximum [Member] | Northern Tier Energy LP [Member] | Pre-Merger Period, Service Based Cash Denominated Awards [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	20.00%

Earnings per Share (Schedule of

Earnings per Share (Schedule of Earnings per Share, Basic) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share, Basic [Abstract]
Net income attributable to Western Refining, Inc.	$ 38,575	$ 153,303	$ 134,528	$ 393,211
Distributed Earnings	41,269	32,498	111,555	93,612
Undistributed Earnings, Basic	$ (2,694)	$ 120,805	$ 22,973	$ 299,599
Weighted Average Number of Shares Outstanding, Basic	108,424	94,826	97,802	95,308
Earnings Per Share, Basic, Distributed	$ 0.38	$ 0.34	$ 1.14	$ 0.98
Earnings Per Share, Basic, Undistributed	(0.02)	1.27	0.23	3.14
Earnings Per Share, Basic	$ 0.36	$ 1.61	$ 1.37	$ 4.12

Earnings per Share (Schedule108

Earnings per Share (Schedule of Earnings per Share, Diluted) (Details) - $ / shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share [Abstract]
Weighted Average Number of Shares Outstanding, Diluted	108,734	94,924	98,110	95,408
Incremental Common Shares Attributable to Dilutive Effect of Share-based Payment Arrangements	310	98	308	100
Earnings Per Share, Diluted	$ 0.35	$ 1.61	$ 1.37	$ 4.12

Cash Flows (WNR) (Details)

Cash Flows (WNR) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Oct. 28, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Income taxes paid	$ 40,562	$ 210,656
Interest paid, excluding amounts capitalized	83,156	62,216
Assets acquired through capital lease obligations	4,644	24,578
Accrued capital expenditures	33,111	31,744
PP&E derecognized from sale leaseback continuing involvement release	2,799	1,773
Transfer of capital spares from fixed asset to inventory	0	1,490
Transfer of capital spares from fixed assets to other assets	$ 699	$ 0
Transfer of capital spares from other assets to fixed assets	161	0
Reduction of long-term debt proceeds from original issuance discount	$ 10,250	$ 0
Treasury stock issuance	438,168	0
Distributions accrued on unvested equity awards	0	2,602
Distributions receivable from equity method investee	0	4,250
Accrued offering costs for issuance of WNRL common units	$ 60	$ 0
Subsequent Event [Member] | 7.125% NTI Secured Notes, due 2020 [Member] | Senior Notes [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Tender offer, debt repayment			$ 195,000

Cash Flows (NTI) (Details)

Cash Flows (NTI) (Details) - USD ($) $ in Thousands	Sep. 14, 2016	Sep. 30, 2016	Sep. 30, 2015	Oct. 28, 2016
Other Significant Noncash Transactions [Line Items]
Interest paid, excluding amounts capitalized		$ 83,156	$ 62,216
Accrued capital expenditures		33,111	31,744
Offering costs for issuance of WNRL common units		477
Northern Tier Energy LP [Member]
Other Significant Noncash Transactions [Line Items]
Interest paid, excluding amounts capitalized		15,200	15,600
Income Taxes Paid		100	2,700
Accrued capital expenditures		15,600	9,600
Property Plant And Equipment Recognized/Derecognized Related To Sale Leaseback Transactions		2,800	1,800
Property Plant And Equipment Recognized Additions Resulting From Capital Lease		300	0
Change in accrued distributions on participating equity awards		0	(2,600)
Offering costs for issuance of WNRL common units		146,100	0
St. Paul Park Logistics Assets [Member] | Western Refining Logistics, LP [Member]
Other Significant Noncash Transactions [Line Items]
Book value of assets sold	$ 48,900		0
Subsequent Event [Member] | Senior Notes [Member] | 7.125% NTI Secured Notes, due 2020 [Member]
Other Significant Noncash Transactions [Line Items]
Tender offer, debt repayment				$ 195,000
Subsequent Event [Member] | Senior Notes [Member] | 7.125% NTI Secured Notes, due 2020 [Member] | Northern Tier Energy LP [Member]
Other Significant Noncash Transactions [Line Items]
Tender offer, debt repayment				$ 195,000
Common Units [Member] | St. Paul Park Logistics Assets [Member] | Western Refining Logistics, LP [Member]
Other Significant Noncash Transactions [Line Items]
Other Significant Noncash Transaction, Value of Consideration Received		$ 14,000	$ 0

Leases and Other Commitments (D

Leases and Other Commitments (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Other Commitments [Line Items]
Capital Leased Assets, Number of Units	38		38
Description of Lessee Leasing Arrangements, Capital Leases			20
Capital Lease Obligations, Current	$ 1,300		$ 1,300		$ 1,000
Lease financing obligations	54,541		54,541		53,232
Deferred Gain on Sale of Property	300		300
Capital Leases, Future Minimum Payments, Annual, Due in Next Five Years	5,500		5,500
Operating Leases, Rent Expense, Net	17,900	$ 16,200	53,900	$ 47,800
Capital Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Remaining 2,016	1,380		1,380
2,017	5,419		5,419
2,018	5,444		5,444
2,019	5,553		5,553
2,020	5,744		5,744
2021 and thereafter	73,027		73,027
Total minimum lease payments	96,567		96,567
Less amount that represents interest	40,951		40,951		$ 44,100
Present value of net minimum capital lease payments	55,616		55,616
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
Remaining 2,016	14,021		14,021
2,017	54,078		54,078
2,018	50,739		50,739
2,019	45,648		45,648
2,020	41,467		41,467
2021 and thereafter	346,889		346,889
Operating Leases, Future Minimum Payments Due	552,842		$ 552,842
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		$ 15,700
Minimum [Member]
Other Commitments [Line Items]
Discount Rate, Capital Leases	3.24%		3.24%
Maximum [Member]
Other Commitments [Line Items]
Discount Rate, Capital Leases	10.51%		10.51%

Contingencies (WNR) (Details)

Contingencies (WNR) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended		33 Months Ended	60 Months Ended
	May 31, 2000	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Jul. 31, 2012	Dec. 31, 2013
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 18,000		$ 18,000		$ 18,300
Cost of products sold (exclusive of depreciation and amortization)		1,607,010	$ 1,895,772	4,256,999	$ 5,814,969
Northern Tier Energy LP [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 7,600		$ 7,600		8,600
Accrual for Environmental Loss Contingencies, Discount Rate		2.03%		2.03%
Northern Tier Energy LP [Member] | Environmental Issue [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 7,600		$ 7,600		8,600
Loss Contingency, Receivable		100		100		200
Accrual for Environmental Loss Contingencies, Discount		$ 2,400		$ 2,400		2,600
Fair Value Assumptions, Expected Term				21 years
Effect on Future Cash Flows, Amount				$ 2,900
Accrual for Environmental Loss Contingencies, Discount Rate		2.03%		2.03%
Renewable Identification Number [Member] | Environmental Issue [Member]
Loss Contingencies [Line Items]
Cost of products sold (exclusive of depreciation and amortization)		$ 15,800	$ 13,100	$ 51,900	$ 25,800
Four Corners Refineries [Member] | Four Corners 2005 Consent Agreements [Member] | Environmental Issue [Member]
Loss Contingencies [Line Items]
Loss Contingency, Loss in Period				100		100	$ 1,900		$ 50,800
Litigation Settlement, Amount								$ 2,700
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
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		5,200		5,200
Gain (Loss) Related to Litigation Settlement				3,500
El Paso Facility [Member] | Texas Natural Resources Conservation Commision [Member] | Environmental Issue [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 6,500		$ 6,500
Loss Contingency, Third Party Obligation After Threshold, Percentage	60.00%
Loss Contingency, Estimated Recovery from Third Party After Threshold, Amount	$ 20,000

Contingencies (NTI) (Details)

Contingencies (NTI) (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2016	Dec. 31, 2015
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 18	$ 18.3
Northern Tier Energy LP [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 7.6	8.6
Period Of Remediation Liabilities		21 years
Accrual for Environmental Loss Contingencies, Gross		$ 2.9
Accrual for Environmental Loss Contingencies, Discount Rate		2.03%
Receivables For Recoverable Costs		$ 0.1	0.2
Super America Franchising Company [Member]
Loss Contingencies [Line Items]
Standard License Term Of Franchise Store Agreements		10 years
Groundwater Contamination [Member] | Northern Tier Energy LP [Member]
Loss Contingencies [Line Items]
Carrying Value of Loss Contingencies Recorded on a Discounted Basis		$ 2.4	2.6
Wastewater Lagoon [Member] | Northern Tier Energy LP [Member]
Loss Contingencies [Line Items]
Accrual for Environmental Loss Contingencies		$ 5.2	$ 6
Litigation Settlement, Amount	$ 3.5

Related Party Transactions (WNR

Related Party Transactions (WNR Related Party Transactions) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Northern Tier Energy LP [Member] | Minnesota Pipe Line Company [Member]
Related Party Transaction [Line Items]
Gas Gathering, Transportation, Marketing and Processing Costs	$ 12,300	$ 13,900	$ 41,100	$ 41,300
El Paso Office Building [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party			200
Operating Leases, Rent Expense	60	$ 60	180	$ 180
Capital Lease Obligations	$ 0		$ 0

Related Party Transactions (NTI

Related Party Transactions (NTI Related Party Transactions) (Details) $ in Thousands, bbl in Millions	Sep. 14, 2016USD ($)	Sep. 30, 2016USD ($)mibbl	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)mibbl	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Related Party Transaction [Line Items]
Proceeds from the sale of assets				$ 3,912	$ 1,061
Offering costs for issuance of WNRL common units				$ 477
Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Offering costs for issuance of WNRL common units				$ 146,100	0
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | Sale Of Asphalt [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		$ 8,900	$ 7,500	28,000	35,300
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | Sale of Feedstock [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		0	100	0	600
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | Sublease of Rail Cars [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		100	0	200	200
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | shared service [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		800	1,000	2,500	2,600
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | Purchases Of Refined Product [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		0	1,500	0	1,500
Northern Tier Energy LP [Member] | Western Refining, Inc. [Member] | Tank and Terminal Service Fees [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		1,900	0	$ 1,900	0
Northern Tier Energy LP [Member] | Investor [Member]
Related Party Transaction [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
Northern Tier Energy LP [Member] | Minnesota Pipe Line Company, LLC [Member] | Crude Transportation Costs [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Amounts of Transaction		$ 12,300	$ 13,900	$ 41,100	41,300
Northern Tier Energy LP [Member] | Investor [Member]
Related Party Transaction [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest				100.00%
MPL Investments Inc. [Member]
Related Party Transaction [Line Items]
Equity Method Investment, Ownership Percentage		17.00%		17.00%
Accounts Payable [Member] | Northern Tier Energy LP [Member] | Minnesota Pipe Line Company, LLC [Member]
Related Party Transaction [Line Items]
Due to Affiliate		$ (1,200)		$ (1,200)		$ (2,700)
Accounts Receivable [Member] | Northern Tier Energy LP [Member] | Western Refining, Inc. [Member]
Related Party Transaction [Line Items]
Due from Affiliates		1,900		1,900		2,800
Accounts Receivable [Member] | Northern Tier Energy LP [Member] | Western Refining Logistics, LP [Member]
Related Party Transaction [Line Items]
Due to Affiliate		$ (1,200)		$ (1,200)		$ 0
St. Paul Park Logistics Assets [Member] | Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Pipeline, Miles | mi		2.5		2.5
St. Paul Park Logistics Assets [Member] | Western Refining Logistics, LP [Member]
Related Party Transaction [Line Items]
Book value of assets sold	$ 48,900				$ 0
Crude Oil Storage Tanks [Member] | St. Paul Park Logistics Assets [Member] | Northern Tier Energy LP [Member]
Related Party Transaction [Line Items]
Active Storage Capacity | bbl		4		4
Restricted cash [Member] | St. Paul Park Logistics Assets [Member] | Western Refining Logistics, LP [Member]
Related Party Transaction [Line Items]
Other Significant Noncash Transaction, Value of Consideration Received				$ 195,000

Condensed Consolidating Fina116

Condensed Consolidating Financial Information (Consolidation Information) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Mar. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Investment in subsidiaries		$ 0	$ 0
Equity - Western		$ 1,665,455	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		52.60%
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%	100.00%
Equity - Western		$ 585,300	393,100
Reportable Legal Entities [Member] | Parent Company [Member]
Segment Reporting Information [Line Items]
Investment in subsidiaries		5,462,120	3,791,084
Equity - Western		1,665,455	1,299,297
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Segment Reporting Information [Line Items]
Investment in subsidiaries		0	0
Equity - Western		$ 3,254,833	$ 3,129,505

Condensed Consolidating Fina117

Condensed Consolidating Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 266,096	$ 772,502	$ 709,570	$ 431,159	$ 431,159
Restricted cash	195,000	0
Accounts receivable, trade, net of a reserve for doubtful accounts	447,327	359,237
Accounts receivable, affiliate	0	0
Inventories	660,738	547,538
Prepaid expenses	129,138	73,213
Other current assets	121,581	169,728
Total current assets	1,819,880	1,922,218
Assets, Noncurrent [Abstract]
Restricted cash	0	69,106
Equity method investment	98,185	97,513
Property, plant and equipment, net	2,357,291	2,305,171
Goodwill	1,289,443	1,289,443
Intangible assets, net (WNRL: $0 and $7,757, respectively)	84,543	84,945
Investment in subsidiaries	0	0
Due from affiliate	0	0
Other assets, net	65,783	64,997
Total assets	5,715,125	5,833,393	5,840,393
Current liabilities:
Accounts payable, trade	634,716	553,957
Accounts payable, affiliate	0	0
Accrued liabilities	216,169	248,395
Current portion of long-term debt	10,500	5,500
Total current liabilities	861,385	807,852
Long-term liabilities:
Long-term debt, less current portion	2,045,180	1,644,894
Due to affiliate	0	0
Lease financing obligations	54,541	53,232
Deferred income tax liability, net	416,951	312,914
Deficit in subsidiaries	0	0
Other liabilities	69,622	68,595
Total long-term liabilities	2,586,294	2,079,635
Equity [Abstract]
Equity - Western	1,665,455	1,299,297
Non-controlling interests	601,991	1,646,609
Total equity	2,267,446	2,945,906	3,032,495	$ 2,787,644
Total liabilities and equity	5,715,125	5,833,393
Consolidation, Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0	0		0
Restricted cash	0
Accounts receivable, trade, net of a reserve for doubtful accounts	0	0
Accounts receivable, affiliate	(90,812)	(59,055)
Inventories	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	(90,812)	(59,055)
Assets, Noncurrent [Abstract]
Restricted cash		0
Equity method investment	0	0
Property, plant and equipment, net	0	0
Goodwill	0	0
Intangible assets, net (WNRL: $0 and $7,757, respectively)	0	0
Investment in subsidiaries	(5,462,120)	(3,791,084)
Due from affiliate	(2,460,977)	(1,623,553)
Other assets, net	0	0
Total assets	(8,013,909)	(5,473,692)
Current liabilities:
Accounts payable, trade	0	0
Accounts payable, affiliate	(90,812)	(59,055)
Accrued liabilities	0	0
Current portion of long-term debt	0	0
Total current liabilities	(90,812)	(59,055)
Long-term liabilities:
Long-term debt, less current portion	0	0
Due to affiliate	(2,460,977)	(1,623,553)
Lease financing obligations	0	0
Deferred income tax liability, net	0	0
Deficit in subsidiaries	(497,548)	(287,761)
Other liabilities	0	0
Total long-term liabilities	(2,958,525)	(1,911,314)
Equity [Abstract]
Equity - Western	(4,964,572)	(3,503,323)
Non-controlling interests	0	0
Total equity	(4,964,572)	(3,503,323)
Total liabilities and equity	(8,013,909)	(5,473,692)
Parent Company [Member] | Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	21	21	21		21
Restricted cash	0
Accounts receivable, trade, net of a reserve for doubtful accounts	0	0
Accounts receivable, affiliate	15,778	0
Inventories	0	0
Prepaid expenses	0	0
Other current assets	0	0
Total current assets	15,799	21
Assets, Noncurrent [Abstract]
Restricted cash		0
Equity method investment	0	0
Property, plant and equipment, net	0	0
Goodwill	0	0
Intangible assets, net (WNRL: $0 and $7,757, respectively)	0	0
Investment in subsidiaries	5,462,120	3,791,084
Due from affiliate	0	0
Other assets, net	0	0
Total assets	5,477,919	3,791,105
Current liabilities:
Accounts payable, trade	0	0
Accounts payable, affiliate	0	920
Accrued liabilities	10,960	5,508
Current portion of long-term debt	10,500	5,500
Total current liabilities	21,460	11,928
Long-term liabilities:
Long-term debt, less current portion	1,330,027	856,327
Due to affiliate	2,460,977	1,623,553
Lease financing obligations	0	0
Deferred income tax liability, net	0	0
Deficit in subsidiaries	0	0
Other liabilities	0	0
Total long-term liabilities	3,791,004	2,479,880
Equity [Abstract]
Equity - Western	1,665,455	1,299,297
Non-controlling interests	0	0
Total equity	1,665,455	1,299,297
Total liabilities and equity	5,477,919	3,791,105
Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	234,970	656,966	523,569		288,986
Restricted cash	0
Accounts receivable, trade, net of a reserve for doubtful accounts	137,775	122,593
Accounts receivable, affiliate	71,656	55,550
Inventories	380,161	311,589
Prepaid expenses	104,195	55,699
Other current assets	83,042	135,139
Total current assets	1,011,799	1,337,536
Assets, Noncurrent [Abstract]
Restricted cash		69,106
Equity method investment	0	0
Property, plant and equipment, net	1,114,593	1,099,787
Goodwill	0	0
Intangible assets, net (WNRL: $0 and $7,757, respectively)	31,947	31,401
Investment in subsidiaries	0	0
Due from affiliate	2,460,977	1,623,553
Other assets, net	32,195	42,166
Total assets	4,651,511	4,203,549
Current liabilities:
Accounts payable, trade	306,033	262,550
Accounts payable, affiliate	0	0
Accrued liabilities	107,907	142,257
Current portion of long-term debt	0	0
Total current liabilities	413,940	404,807
Long-term liabilities:
Long-term debt, less current portion	0	0
Due to affiliate	0	0
Lease financing obligations	45,333	42,168
Deferred income tax liability, net	380,508	275,634
Deficit in subsidiaries	497,548	287,761
Other liabilities	59,349	63,674
Total long-term liabilities	982,738	669,237
Equity [Abstract]
Equity - Western	3,254,833	3,129,505
Non-controlling interests	0	0
Total equity	3,254,833	3,129,505
Total liabilities and equity	4,651,511	4,203,549
Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Current assets:
Cash and cash equivalents	31,105	115,515	$ 185,980		$ 142,152
Restricted cash	195,000
Accounts receivable, trade, net of a reserve for doubtful accounts	309,552	236,644
Accounts receivable, affiliate	3,378	3,505
Inventories	280,577	235,949
Prepaid expenses	24,943	17,514
Other current assets	38,539	34,589
Total current assets	883,094	643,716
Assets, Noncurrent [Abstract]
Restricted cash		0
Equity method investment	98,185	97,513
Property, plant and equipment, net	1,242,698	1,205,384
Goodwill	1,289,443	1,289,443
Intangible assets, net (WNRL: $0 and $7,757, respectively)	52,596	53,544
Investment in subsidiaries	0	0
Due from affiliate	0	0
Other assets, net	33,588	22,831
Total assets	3,599,604	3,312,431
Current liabilities:
Accounts payable, trade	328,683	291,407
Accounts payable, affiliate	90,812	58,135
Accrued liabilities	97,302	100,630
Current portion of long-term debt	0	0
Total current liabilities	516,797	450,172
Long-term liabilities:
Long-term debt, less current portion	715,153	788,567
Due to affiliate	0	0
Lease financing obligations	9,208	11,064
Deferred income tax liability, net	36,443	37,280
Deficit in subsidiaries	0	0
Other liabilities	10,273	4,921
Total long-term liabilities	771,077	841,832
Equity [Abstract]
Equity - Western	1,709,739	373,818
Non-controlling interests	601,991	1,646,609
Total equity	2,311,730	2,020,427
Total liabilities and equity	$ 3,599,604	$ 3,312,431

Condensed Consolidating Fina118

Condensed Consolidating Financial Information (Condensed Consolidating Income Statement) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Financial Statements, Captions [Line Items]
Net sales	$ 2,065,076	$ 2,569,090	$ 5,627,888	$ 7,716,712
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	1,607,010	1,895,772	4,256,999	5,814,969
Direct operating expenses (exclusive of depreciation and amortization)	232,553	234,440	687,307	674,474
Selling, general and administrative expenses	57,320	54,465	166,657	169,808
Gain on disposal of assets, net	(279)	(52)	(1,181)	(157)
Maintenance turnaround expense	27,208	490	27,733	1,188
Depreciation and amortization	54,321	51,377	161,331	152,446
Total operating costs and expenses	1,978,133	2,236,492	5,298,846	6,812,728
Operating income	86,943	332,598	329,042	903,984
Income (Loss) from Equity Method Investments	0	0	0	0
Other income (expense):
Interest income	141	186	436	550
Interest and debt expense	(34,456)	(26,896)	(88,065)	(79,169)
Other, net	3,380	4,327	13,825	11,557
Income before income taxes	56,008	310,215	255,238	836,922
Provision for income taxes	(11,700)	(92,117)	(68,481)	(229,989)
Net income	44,308	218,098	186,757	606,933
Less net income attributable to non-controlling interests	5,733	64,795	52,229	213,722
Net income attributable to Western Refining, Inc.	38,575	153,303	134,528	393,211
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	38,575	153,311	134,476	393,276
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	(1,542,527)	(755,902)	(2,719,902)	(2,267,694)
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	(1,542,527)	(755,902)	(2,719,902)	(2,267,694)
Direct operating expenses (exclusive of depreciation and amortization)	0	0	0	0
Selling, general and administrative expenses	0	0	0	0
Gain on disposal of assets, net	0	0	0	0
Maintenance turnaround expense	0	0	0	0
Depreciation and amortization	0	0	0	0
Total operating costs and expenses	(1,542,527)	(755,902)	(2,719,902)	(2,267,694)
Operating income	0	0	0	0
Income (Loss) from Equity Method Investments	(62,194)	(173,255)	(190,117)	(442,497)
Other income (expense):
Interest income	0	0	0	0
Interest and debt expense	0	0	0	0
Other, net	0	0	0	0
Income before income taxes	(62,194)	(173,255)	(190,117)	(442,497)
Provision for income taxes	0	0	0	0
Net income	(62,194)	(173,255)	(190,117)	(442,497)
Less net income attributable to non-controlling interests	0	0	0	0
Net income attributable to Western Refining, Inc.	(62,194)	(173,255)	(190,117)	(442,497)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(62,194)	(173,255)	(190,117)	(442,497)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	0	0	0	0
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	0	0	0	0
Direct operating expenses (exclusive of depreciation and amortization)	0	0	0	0
Selling, general and administrative expenses	46	48	139	142
Gain on disposal of assets, net	0	0	0	0
Maintenance turnaround expense	0	0	0	0
Depreciation and amortization	0	0	0	0
Total operating costs and expenses	46	48	139	142
Operating income	(46)	(48)	(139)	(142)
Income (Loss) from Equity Method Investments	61,069	166,608	184,428	433,921
Other income (expense):
Interest income	0	0	0	0
Interest and debt expense	(22,448)	(13,257)	(49,761)	(40,568)
Other, net	0	0	0	0
Income before income taxes	38,575	153,303	134,528	393,211
Provision for income taxes	0	0	0	0
Net income	38,575	153,303	134,528	393,211
Less net income attributable to non-controlling interests	0	0	0	0
Net income attributable to Western Refining, Inc.	38,575	153,303	134,528	393,211
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	38,575	153,303	134,528	393,211
Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	1,970,512	1,846,297	4,466,234	5,611,815
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	1,733,544	1,476,431	3,780,557	4,612,431
Direct operating expenses (exclusive of depreciation and amortization)	113,416	111,871	333,556	331,423
Selling, general and administrative expenses	29,887	28,061	82,283	87,486
Gain on disposal of assets, net	(217)	(6)	(208)	444
Maintenance turnaround expense	366	490	891	1,188
Depreciation and amortization	27,286	24,830	79,620	74,457
Total operating costs and expenses	1,904,282	1,641,677	4,276,699	5,107,429
Operating income	66,230	204,620	189,535	504,386
Income (Loss) from Equity Method Investments	1,125	6,647	5,689	8,576
Other income (expense):
Interest income	100	106	317	308
Interest and debt expense	(788)	(703)	(2,284)	(1,943)
Other, net	(1,301)	(6)	(208)	(519)
Income before income taxes	65,366	210,664	193,049	510,808
Provision for income taxes	(11,418)	(92,114)	(67,721)	(229,635)
Net income	53,948	118,550	125,328	281,173
Less net income attributable to non-controlling interests	0	0	0	0
Net income attributable to Western Refining, Inc.	53,948	118,550	125,328	281,173
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	53,948	118,558	125,328	281,197
Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Net sales	1,637,091	1,478,695	3,881,556	4,372,591
Operating costs and expenses:
Cost of products sold (exclusive of depreciation and amortization)	1,415,993	1,175,243	3,196,344	3,470,232
Direct operating expenses (exclusive of depreciation and amortization)	119,137	122,569	353,751	343,051
Selling, general and administrative expenses	27,387	26,356	84,235	82,180
Gain on disposal of assets, net	(62)	(46)	(973)	(601)
Maintenance turnaround expense	26,842	0	26,842	0
Depreciation and amortization	27,035	26,547	81,711	77,989
Total operating costs and expenses	1,616,332	1,350,669	3,741,910	3,972,851
Operating income	20,759	128,026	139,646	399,740
Income (Loss) from Equity Method Investments	0	0	0	0
Other income (expense):
Interest income	41	80	119	242
Interest and debt expense	(11,220)	(12,936)	(36,020)	(36,658)
Other, net	4,681	4,333	14,033	12,076
Income before income taxes	14,261	119,503	117,778	375,400
Provision for income taxes	(282)	(3)	(760)	(354)
Net income	13,979	119,500	117,018	375,046
Less net income attributable to non-controlling interests	5,733	64,795	52,229	213,722
Net income attributable to Western Refining, Inc.	8,246	54,705	64,789	161,324
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 8,246	$ 54,705	$ 64,737	$ 161,365

Condensed Consolidating Fina119

Condensed Consolidating Financial Information (Condensed Consolidating Cash Flows) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities				$ 277,877	$ 665,664
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures	$ (78,337)		$ (76,431)	(235,097)	(195,976)
Return of capital from equity method investment				0	5,780
Increase in restricted cash				(195,000)	0
Use of restricted cash				69,106	154,681
Contributions to affiliate				0	0
Proceeds from the sale of assets				3,912	1,061
Net cash used in investing activities				(357,079)	(34,454)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt				500,000	300,000
Payments on long-term debt and capital lease obligations				(7,150)	(5,559)
Borrowings on revolving credit facility				393,900	0
Repayments on revolving credit facility				(466,600)	(269,000)
Payments for NTI units related to merger				(859,893)	0
Transaction costs for NTI merger				(11,741)	0
Proceeds from Issuance of Common Limited Partners Units				277,751	0
Offering costs for issuance of WNRL common units				(417)	0
Distribution to affiliate				0	0
Deferred financing costs				(12,410)	(6,820)
Purchase of common stock for treasury				(75,000)	(105,000)
Distribution to non-controlling interest holders				54,115	173,687
Dividends paid				(111,555)	(93,612)
Contributions from affiliates				0	0
Payments to Acquire Interest in Subsidiaries and Affiliates				0
Excess tax benefit from stock-based compensation				26	879
Net cash used in financing activities				(427,204)	(352,799)
Net increase in cash and cash equivalents				(506,406)	278,411
Cash and cash equivalents at beginning of period		$ 709,570		772,502	431,159
Cash and cash equivalents at end of period	266,096	772,502	709,570	266,096	709,570
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities				(42,552)	67,772
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures				0	0
Return of capital from equity method investment				13,537	0
Increase in restricted cash				0
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				500,000	0
Payments on long-term debt and capital lease obligations				(5,375)	(4,125)
Borrowings on revolving credit facility				0
Repayments on revolving credit facility				0	0
Payments for NTI units related to merger				(859,893)
Transaction costs for NTI merger				(11,741)
Proceeds from Issuance of Common Limited Partners Units				0
Offering costs for issuance of WNRL common units				0
Distribution to affiliate				0	0
Deferred financing costs				(11,408)	0
Purchase of common stock for treasury				(75,000)	(105,000)
Distribution to non-controlling interest holders				0	0
Dividends paid				(111,555)	(93,612)
Contributions from affiliates				603,987	134,965
Payments to Acquire Interest in Subsidiaries and Affiliates				0
Excess tax benefit from stock-based compensation				0	0
Net cash used in financing activities				29,015	(67,772)
Net increase in cash and cash equivalents				0	0
Cash and cash equivalents at beginning of period		21		21
Cash and cash equivalents at end of period	21	21	21	21	21
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities				226,792	345,293
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures				(113,533)	(108,988)
Return of capital from equity method investment				0	0
Increase in restricted cash				0
Use of restricted cash				69,106	154,681
Contributions to affiliate				(603,987)	(158,652)
Proceeds from the sale of assets				348	2,028
Net cash used in investing activities				(648,066)	(110,931)
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt				0	0
Payments on long-term debt and capital lease obligations				(748)	(658)
Borrowings on revolving credit facility				0
Repayments on revolving credit facility				0	0
Payments for NTI units related to merger				0
Transaction costs for NTI merger				0
Proceeds from Issuance of Common Limited Partners Units				0
Offering costs for issuance of WNRL common units				0
Distribution to affiliate				0	0
Deferred financing costs				0	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
Payments to Acquire Interest in Subsidiaries and Affiliates				0
Excess tax benefit from stock-based compensation				26	879
Net cash used in financing activities				(722)	221
Net increase in cash and cash equivalents				(421,996)	234,583
Cash and cash equivalents at beginning of period		523,569		656,966
Cash and cash equivalents at end of period	234,970	656,966	523,569	234,970	523,569
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities				141,120	383,762
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures				(121,804)	(88,545)
Return of capital from equity method investment				0	5,780
Increase in restricted cash				(195,000)
Use of restricted cash				0	0
Contributions to affiliate				(20,286)	(18,457)
Proceeds from the sale of assets				3,804	590
Net cash used in investing activities				(333,286)	(100,632)
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				(1,027)	(776)
Borrowings on revolving credit facility				393,900
Repayments on revolving credit facility				(466,600)	(269,000)
Payments for NTI units related to merger				0
Transaction costs for NTI merger				0
Proceeds from Issuance of Common Limited Partners Units				277,751
Offering costs for issuance of WNRL common units				(417)
Distribution to affiliate				(61,020)	(131,163)
Deferred financing costs				(1,002)	(6,820)
Purchase of common stock for treasury				0	0
Distribution to non-controlling interest holders				54,115	173,687
Dividends paid				0	0
Contributions from affiliates				20,286	42,144
Payments to Acquire Interest in Subsidiaries and Affiliates				0
Excess tax benefit from stock-based compensation				0	0
Net cash used in financing activities				107,756	(239,302)
Net increase in cash and cash equivalents				(84,410)	43,828
Cash and cash equivalents at beginning of period		185,980		115,515
Cash and cash equivalents at end of period	31,105	115,515	185,980	31,105	185,980
Consolidation, Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Net cash provided by operating activities				(47,483)	(131,163)
Net Cash Provided by (Used in) Investing Activities [Abstract]
Capital expenditures				240	1,557
Return of capital from equity method investment				(13,537)	0
Increase in restricted cash				0
Use of restricted cash				0	0
Contributions to affiliate				624,273	177,109
Proceeds from the sale of assets				(240)	(1,557)
Net cash used in investing activities				610,736	177,109
Net Cash Provided by (Used in) Financing Activities [Abstract]
Additions to long-term debt				0	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
Payments for NTI units related to merger				0
Transaction costs for NTI merger				0
Proceeds from Issuance of Common Limited Partners Units				0
Offering costs for issuance of WNRL common units				0
Distribution to affiliate				61,020	131,163
Deferred financing costs				0	0
Purchase of common stock for treasury				0	0
Distribution to non-controlling interest holders				0	0
Dividends paid				0	0
Contributions from affiliates				(624,273)	(177,109)
Payments to Acquire Interest in Subsidiaries and Affiliates				0
Excess tax benefit from stock-based compensation				0	0
Net cash used in financing activities				(563,253)	(45,946)
Net increase in cash and cash equivalents				0	0
Cash and cash equivalents at beginning of period		0		0
Cash and cash equivalents at end of period	$ 0	$ 0	$ 0	$ 0	$ 0

Acquisitions (WNR) (Details)

Acquisitions (WNR) (Details) - USD ($) $ / shares in Units, shares in Millions	Dec. 21, 2015	Mar. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Jun. 23, 2016
Business Acquisition [Line Items]
Payments for NTI units			$ 859,893,000	$ 0
Transaction costs for NTI merger			11,741,000
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payments for NTI units			859,900,000
Transaction costs for NTI merger			11,700,000
Business Combination, Separately Recognized Transactions, Net Gains and Losses			$ 0
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest			100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest		38.30%	100.00%
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] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17.1
Minimum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit	$ 15
Minimum [Member] | Common Stock [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit			$ 0.28896
Maximum [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit			$ 15.357
Maximum [Member] | Common Stock [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Line of Credit [Member] | Term Loan, due 2023 [Member]
Business Acquisition [Line Items]
Debt Instrument, Face Amount					$ 500,000,000

Acquisitions (Pro Forma) (Detai

Acquisitions (Pro Forma) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Business Acquisition [Line Items]
Net sales	$ 2,065,076	$ 2,569,090	$ 5,627,888	$ 7,716,712
Operating income	$ 86,943	332,598	329,042	903,984
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Business Acquisition, Pro Forma Interest Expense		(9,100)	(17,000)	(27,100)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest		189,905	162,768	514,874
Net Income (Loss) Attributable to Parent		$ 184,319	$ 145,862	$ 498,715
Earnings Per Share, Basic		$ 1.65	$ 1.35	$ 4.43
Earnings Per Share, Diluted		$ 1.65	$ 1.34	$ 4.43
Business Acquisition, Pro Forma Income Tax Expense (Benefit)		$ 19,100	$ 7,000	$ 64,900

Acquisitions (Merger & Reorgani

Acquisitions (Merger & Reorganization Expenses) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Northern Tier Energy LP [Member]
Restructuring Reserve [Roll Forward]
Restructuring Reserve	$ 452	$ 470	$ 189	$ 808
Restructuring Reserve	1,367	358	1,367	358
Northern Tier Energy LP [Member] | Other Restructuring [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	178	0	1,321	0
Payments for Restructuring	(442)	0	(1,133)	0
Northern Tier Energy LP [Member] | Employee Severance [Member]
Restructuring Reserve [Roll Forward]
Restructuring Charges	2,666	0	2,666	0
Payments for Restructuring	(1,487)	$ (112)	(1,676)	$ (450)
Corporate and Other Reconciling Items [Member] | Other Nonoperating Income (Expense) [Member]
Restructuring Cost and Reserve [Line Items]
Restructuring and Related Cost, Incurred Cost	$ 2,800		$ 4,000

Acquisitions (NTI - Merger Tran

Acquisitions (NTI - Merger Transaction) (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	Dec. 21, 2015	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Business Acquisition [Line Items]
Payments for NTI units					$ 859,893	$ 0
MergerCo HoldCo [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), Managing Member or General Partner, Ownership Interest					100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest			38.30%		100.00%
Merger-related expenses		$ 1,500		$ 0	$ 2,600	0
Restructuring Reserve		1,100		400	$ 1,100	400	$ 400	$ 200	$ 500	$ 800
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%
Investor [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest					100.00%
Merger Agreement Dated December Two Thousand Fifteen [Member] | Minimum [Member] | Northern Tier Unitholders [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit	$ 15
Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payments for NTI units					$ 859,900
Restructuring Reserve		$ 1,367		358	$ 1,367	358	$ 452	$ 189	$ 470	$ 808
Northern Tier Energy LP [Member] | Maximum [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit		$ 15.357			$ 15.357
Northern Tier Energy LP [Member] | Minimum [Member]
Business Acquisition [Line Items]
Cash payments to acquire business, per unit	15
Common Stock [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member] | Northern Tier Unitholders [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.2986
Common Stock [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member] | Western Refining, Inc. [Member]
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17.1
Common Stock [Member] | Merger Agreement Dated December Two Thousand Fifteen [Member] | Maximum [Member] | NTI Public Unitholder [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Common Stock [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares	17.1
Payment of shares to acquire business, per unit	$ 0.2986
Common Stock [Member] | Northern Tier Energy LP [Member] | Maximum [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit	$ 0.7036
Common Stock [Member] | Northern Tier Energy LP [Member] | Minimum [Member]
Business Acquisition [Line Items]
Payment of shares to acquire business, per unit		$ 0.28896			$ 0.28896
Third Party Professional Service [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Merger-related expenses		$ 200		0	$ 1,300	0
Payments for Restructuring		(400)		0	(1,100)	0
Employee Severance [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Merger-related expenses		1,300		0	1,300	0
Payments for Restructuring		(400)		(100)	(600)	(400)
Employee Severance [Member] | Northern Tier Energy LP [Member]
Business Acquisition [Line Items]
Payments for Restructuring		$ (1,487)		$ (112)	$ (1,676)	$ (450)

WNRL (Details)

WNRL (Details) bbl in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016mibbl	Sep. 30, 2015	Sep. 30, 2016mibbl	Sep. 30, 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			52.60%
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	32.20%	31.90%	31.80%	30.00%
Western Refining Logistics, LP [Member]
Variable Interest Entity [Line Items]
Pipeline, Miles | mi	692		692
Active Storage Capacity | bbl	12.4		12.4