Delek Logistics Partners (DKL) 10-K 29 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information Document - USD ($)	12 Months Ended
	Dec. 31, 2015	Feb. 26, 2016	Jun. 30, 2015
Entity Information [Line Items]
Entity Registrant Name	Delek Logistics Partners, LP
Entity Central Index Key	1,552,797
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 435,245,673
Common Units [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding		24,276,789
Subordinated Units [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding		0
General Partner
Entity Information [Line Items]
Common Stock, Shares, Outstanding		495,445

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands		Dec. 31, 2015	Dec. 31, 2014	[2]
Current assets:
Cash and cash equivalents	[1]	$ 0	$ 1,861	[3]
Accounts receivable		35,049	27,986
Inventory		10,451	10,316
Deferred tax assets		0	28
Other current assets		1,540	768
Total current assets		47,040	40,959
Property, plant and equipment:
Property, plant and equipment		325,647	308,088
Less: accumulated depreciation		(71,799)	(53,309)
Property, plant and equipment, net		253,848	254,779
Equity method investments		40,678	0
Goodwill		12,203	11,654
Intangible assets, net		15,482	16,520
Other non-current assets		6,037	7,374
Total assets		375,288	331,286	[4]
Current liabilities:
Accounts payable		6,850	17,929
Accounts payable to related parties		3,992	628
Excise and other taxes payable		4,871	5,443
Tank inspection liabilities		1,890	2,829
Pipeline release liabilities		1,393	1,899
Accrued expenses and other current liabilities		1,694	1,588
Total current liabilities		20,690	30,316
Non-current liabilities:
Revolving credit facility		351,600	251,750
Asset retirement obligations		3,506	3,319
Deferred tax liabilities		0	231
Other non-current liabilities		10,510	5,889
Total non-current liabilities		365,616	261,189
Equity (Deficit):
Total (deficit) equity		(11,018)	39,781
Total liabilities and (deficit) equity		375,288	331,286
Predecessor division equity
Equity (Deficit):
Total (deficit) equity		0	19,726
General partner - Delek; 495,445 units issued and outstanding at December 31, 2015 (494,197 at December 31, 2014)
Equity (Deficit):
Total (deficit) equity		(7,192)	(7,085)
Common unitholders - public; 9,478,273 units issued and outstanding at December 31, 2015 (9,417,189 at December 31, 2014) | Limited Partner [Member]
Equity (Deficit):
Total (deficit) equity		198,401	194,737
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2015 (2,799,258 at December 31, 2014) | Limited Partner [Member]
Equity (Deficit):
Total (deficit) equity		(280,828)	(241,112)
Subordinated unitholders - Delek; 11,999,258 units issued and outstanding at December 31, 2015 (11,999,258 at December 31, 2014) | Limited Partner [Member]
Equity (Deficit):
Total (deficit) equity		$ 78,601	$ 73,515
[1]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	Adjusted to include the historical balances of the Logistics Assets Predecessor.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parentheticals) - shares	Dec. 31, 2015	Dec. 31, 2014
General Partners' Capital Account, Units Issued	495,445	494,197
General Partners' Capital Account, Units Outstanding	495,445	494,197
Common - Public
Limited Partners' Capital Account, Units Issued	9,478,273	9,417,189
Limited Partners' Capital Account, Units Outstanding	9,478,273	9,417,189
Common - Delek
Limited Partners' Capital Account, Units Issued	2,799,258	2,799,258
Limited Partners' Capital Account, Units Outstanding	2,799,258	2,799,258
Subordinated- Delek
Limited Partners' Capital Account, Units Issued	11,999,258	11,999,258
Limited Partners' Capital Account, Units Outstanding	11,999,258	11,999,258

Consolidated Statements of Inco

Consolidated Statements of Income and Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Net Sales:
Affiliate	[1]	$ 152,564	[2]	$ 114,583	[3]	$ 78,173	[3]
Third Party		437,105	[2]	726,670	[3]	829,255	[3]
Net sales		589,669	[2]	841,253	[3],[4]	907,428	[3],[4]
Operating costs and expenses:
Cost of goods sold		436,304	[2]	697,221	[3],[4]	811,364	[3],[4]
Operating expenses	[5],[6]	44,923	[2]	39,465	[3],[4]	35,903	[3],[4]
General and administrative expenses		11,384	[2]	10,616	[3],[4]	7,526	[3],[4]
Depreciation and amortization		19,692	[2],[7]	15,022	[3],[4],[8]	13,738	[3],[4],[8]
Loss on asset disposals		104	[2],[7]	83	[3],[4],[8]	166	[3],[4],[8]
Total operating costs and expenses		512,407	[2]	762,407	[3],[4]	868,697	[3],[4]
Operating income		77,262	[2]	78,846	[3],[4]	38,731	[3],[4]
Interest expense, net		10,658	[2]	8,656	[3],[4]	4,570	[3],[4]
Loss on equity method investments		588	[2],[7]	0	[3],[8]	0	[3],[8]
Total non-operating expenses		11,246	[2]	8,656	[3]	4,570	[3]
Income before income tax (benefit) expense		66,016	[2]	70,190	[3],[4]	34,161	[3],[4]
Income tax (benefit) expense		(195)	[2]	132	[3],[4]	757	[3],[4]
Net income		66,211	[2],[7]	70,058	[3],[8]	33,404	[3],[8]
Less: loss attributable to Predecessors		(637)	[2]	(1,939)	[3],[4]	(14,426)	[3],[4]
Net income attributable to partners		66,848	[2]	71,997	[3],[4]	47,830	[3],[4]
Comprehensive income attributable to partners		66,848	[2]	71,997	[3]	47,830	[3]
Less: General partner's interest in net income, including incentive distribution rights		5,163	[2]	2,366	[3]	957	[3]
Limited partners' interest in net income		$ 61,685	[2]	$ 69,631	[3]	$ 46,873	[3]
Weighted average limited partner units outstanding:
Cash distributions per limited partner unit		$ 2.240		$ 1.900		$ 1.600
Common Units [Member]
Net income per limited partner unit:
Common units - (basic)		2.55	[2]	2.88	[3]	1.95	[3]
Common units - (diluted)		$ 2.52	[2]	$ 2.85	[3]	$ 1.93	[3]
Weighted average limited partner units outstanding:
Common units - (basic)		12,237,154	[2]	12,171,548	[3]	12,025,249	[3]
Common units - (diluted)		12,356,914	[2]	12,302,629	[3]	12,148,774	[3]
Subordinated- Delek
Net income per limited partner unit:
Subordinated units - Delek (basic and diluted)		$ 2.54	[2]	$ 2.88	[3]	$ 1.95	[3]
Weighted average limited partner units outstanding:
Subordinated units - Delek (basic and diluted)		11,999,258	[2]	11,999,258	[3]	11,999,258	[3]
[1]	See Note 4 for a description of our affiliate revenue transactions.
[2]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[5]	Adjusted to include operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.
[6]	Includes operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.
[7]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[8]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Consolidated Statements of Part

Consolidated Statements of Partners' Equity - USD ($) $ in Thousands		Total		Equity of Predecessors	Limited Partner [Member]Common - Public	Limited Partner [Member]Common - Delek	Limited Partner [Member]Subordinated- Delek	General Partner	El Dorado Terminal and Tank Assets [Member]	Tyler Terminal and Tank Assets [Member]
Beginning balance at Dec. 31, 2012		$ 166,733		$ 62,308	$ 178,728	$ (127,129)	$ 52,875	$ (49)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Sponsor contributions of equity to the Predecessor		33,339	[1]	33,339
Loss attributable to Predecessor		(14,426)	[2],[3]	(14,426)
Liabilities not assumed by the Partnership		213		213
Allocation of net assets acquired by the unitholders		0		(38,267)	0	37,502	0	765
Cash distributions	[4]	(129,564)		0	(13,223)	(96,848)	(16,907)	(2,586)
Sponsorship contribution of fixed assets		520	[1]	0	0	510	0	10
Net income attributable to partners		47,830	[2],[3]	0	18,035	5,455	23,383	957
Unit-based compensation		464		0	341	3,822	0	(3,699)
Other		99		0	(42)	8	35	98
Ending balance at Dec. 31, 2013		105,208		43,167	183,839	(176,680)	59,386	(4,504)
Footnote [Abstract]
Cash payments for acquisitions									$ 94,800
Decrease in equity balance due to acquisitions										$ 56,500
Distribution equivalents on vested phantom units		200
Sponsor contributions of equity to the Predecessor		3,722	[1]	3,722
Loss attributable to Predecessor		(1,939)	[2],[3]	(1,939)
Allocation of net assets acquired by the unitholders		0		(25,224)	0	24,720	0	504
Cash distributions	[5]	(141,092)		0	(17,099)	(99,035)	(21,658)	(3,300)
Sponsorship contribution of fixed assets		1,566	[1]	0	0	1,534	0	32
Net income attributable to partners		71,997	[2],[3]	0	27,386	8,166	35,005	1,440
Unit-based compensation		274		0	611	183	782	(1,302)
Other		45		0	0	0	0	45
Ending balance at Dec. 31, 2014	[6]	39,781		19,726	194,737	(241,112)	73,515	(7,085)
Footnote [Abstract]
Cash payments for acquisitions										95,900
Decrease in equity balance due to acquisitions										70,700
Distribution equivalents on vested phantom units		200
Sponsor contributions of equity to the Predecessor		115	[7]	115
Loss attributable to Predecessor		(637)	[8]	(637)	0	0	0	0
Allocation of net assets acquired by the unitholders		0		(19,204)	0	18,820	0	384
Cash distributions	[9]	(118,528)		0	(20,755)	(66,698)	(25,919)	(5,156)
Sponsorship contribution of fixed assets		584	[7]	0	0	573	0	11
Net income attributable to partners		66,848	[8]	0	24,039	7,121	30,525	5,163
Unit-based compensation		406		0	740	219	940	(1,493)
Other		413		0	(360)	249	(460)	984
Ending balance at Dec. 31, 2015		(11,018)		$ 0	$ 198,401	$ (280,828)	$ 78,601	$ (7,192)
Footnote [Abstract]
Cash payments for acquisitions										$ 61,900
Decrease in equity balance due to acquisitions									$ 42,700
Distribution equivalents on vested phantom units		$ 400
[1]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[4]	Cash distributions include $94.8 million in cash payments for an acquisition from Delek during 2013. As an entity under common control with Delek, we record the assets that we acquire from Delek on our consolidated balance sheet at Delek's historical book value instead of fair value. Additionally, any excess of cash paid over the historical book value of the assets acquired from Delek is recorded within equity. As a result of this accounting treatment, the acquisition resulted in a $56.5 million decrease in our equity balance during 2013. Distributions also include $0.2 million related to distribution equivalents on vested phantom units.
[5]	Cash distributions include $95.9 million in cash payments for an acquisition from Delek during 2014. As an entity under common control with Delek, we record the assets that we acquire from Delek on our consolidated balance sheet at Delek's historical book value instead of fair value. Additionally, any excess of cash paid over the historical book value of the assets acquired from Delek is recorded within equity. As a result of this accounting treatment, the acquisition resulted in a $70.7 million decrease in our equity balance during 2014. Distributions also include $0.2 million related to distribution equivalents on vested phantom units.
[6]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[7]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[8]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[9]	Cash distributions include $61.9 million in cash payments for the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition. As an entity under common control with Delek, we record the assets that we acquire from Delek on our balance sheet at Delek's historical book basis instead of fair value. Additionally, any excess of cash paid over the historical book basis of the assets acquired from Delek is recorded within equity. As a result of the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition, our equity balance decreased $42.7 million during the year ended December 31, 2015. Distributions also include $0.4 million related to distribution equivalents on vested phantom units.

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	[1]	Dec. 31, 2014		Dec. 31, 2013
Net income		$ 66,211	[2]	$ 70,058	[3],[4]	$ 33,404	[3],[4]
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		19,692	[2]	15,022	[3],[4],[5]	13,738	[3],[4],[5]
Amortization of unfavorable contract liability to revenue		0		2,670	[3]	2,623	[3]
Amortization of deferred revenue		(596)		(307)	[3]	(204)	[3]
Amortization of deferred financing costs		1,460		1,267	[3]	1,007	[3]
Accretion of asset retirement obligations		251		232	[3]	224	[3]
Loss on asset disposals		104	[2]	83	[3],[4],[5]	166	[3],[4],[5]
Deferred income taxes		14		(109)	[3]	309	[3]
Loss on equity method investments		588	[2]	0	[3],[4]	0	[3],[4]
Unit-based compensation expense		406		274	[3]	464	[3]
Changes in assets and liabilities, net of acquisitions:
Accounts receivable		(7,197)		2,892	[3]	(1,251)	[3]
Inventories and other current assets		(907)		7,894	[3]	(3,333)	[3]
Accounts payable and other current liabilities		(13,734)		(7,117)	[3]	7,332	[3]
Accounts payable to related parties		1,737		(885)	[3]	(8,635)	[3]
Non-current assets and liabilities, net		(5)		(1,550)	[3]	(4,030)	[3]
Net cash provided by operating activities		68,024		85,084	[3]	36,568	[3]
Cash flows from investing activities:
Business combinations		(400)		(22,650)	[3]	(10,737)	[3]
Purchases of property, plant and equipment		(19,956)		(9,012)	[3]	(25,597)	[3]
Proceeds from sales of property, plant and equipment		1,198		0	[3]	0	[3]
Equity method investments		(37,434)		0	[3]	0	[3]
Net cash used in investing activities		(56,592)		(31,662)	[3]	(36,334)	[3]
Cash flows from financing activities:
Proceeds from issuance of additional units to maintain 2% General Partner interest		50		45	[3]	99	[3]
Distributions to general partner		(3,918)		(1,382)	[3]	(690)	[3]
Distributions to common unitholders - public		(20,755)		(17,099)	[3]	(13,223)	[3]
Distributions to common unitholders - Delek		(6,046)		(5,053)	[3]	(3,944)	[3]
Distributions to subordinated unitholders		(25,919)		(21,658)	[3]	(16,907)	[3]
Distributions to Delek for acquisitions		(61,890)		(95,900)	[3]	(94,800)	[3]
Proceeds from revolving credit facility		396,400		499,750	[3]	206,300	[3]
Payments of revolving credit facility		(296,550)		(412,800)	[3]	(131,500)	[3]
Deferred financing costs paid		0		(3,688)	[3]	(2,273)	[3]
Predecessor division equity contribution		115		3,722	[3]	33,339	[3]
Reimbursement of capital expenditures by Sponsor		5,220		1,578	[3]	837	[3]
Net cash used in financing activities		(13,293)		(52,485)	[3]	(22,762)	[3]
Net (decrease) increase in cash and cash equivalents		(1,861)		937	[3]	(22,528)	[3]
Cash and cash equivalents at the beginning of the period	[3]	1,861	[6]	924		23,452
Cash and cash equivalents at the end of the period		0		1,861	[1],[3],[6]	924	[3]
Cash paid during the period for:
Interest		9,009		7,661	[3]	3,242	[3]
Income taxes		4		18	[3]	30	[3]
Non-cash investing activities:
Equity method investments		3,832		0	[3]	0	[3]
Increases in accrued capital expenditures		2,471		156	[3]	140	[3]
Non-cash financing activities:
Working capital retained by Sponsor		0		0	[3]	213	[3]
Sponsor contribution of fixed assets		$ 584		$ 1,566	[3]	$ 520	[3]
[1]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[5]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[6]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

General (Notes)

General (Notes)	12 Months Ended
	Dec. 31, 2015
General [Abstract]
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	General Organization As used in this report, the terms "Delek Logistics Partners, LP," the "Partnership," "we," "us," or "our" may refer to Delek Logistics Partners, LP, one or more of its consolidated subsidiaries or all of them taken as a whole. References in this report to "Delek" refer collectively to Delek US Holdings, Inc. and any of its subsidiaries, other than Delek Logistics Partners, LP and its subsidiaries and its general partner (as hereinafter defined). The Partnership is a Delaware limited partnership formed in April 2012 by Delek and its subsidiary Delek Logistics GP, LLC, our general partner (our "general partner'). On July 26, 2013 , the Partnership, through its wholly owned subsidiary Delek Marketing & Supply, LP ("Delek Logistics Marketing"), acquired from Delek (i) the refined products terminal (the “Tyler Terminal”) located at Delek's Tyler, Texas Refinery (the "Tyler Refinery") and (ii) 96 storage tanks and certain ancillary assets (the "Tyler Tank Assets" and, together with the Tyler Terminal, the “Tyler Terminal and Tank Assets”) adjacent to the Tyler Refinery (such transaction, the “Tyler Acquisition”). On February 10, 2014 , the Partnership, through its wholly owned subsidiary Delek Logistics Operating, LLC ("OpCo"), acquired from Delek (i) the refined products terminal (the “El Dorado Terminal”) located at Delek's El Dorado, Arkansas refinery (the "El Dorado Refinery") and (ii) 158 storage tanks and certain ancillary assets (the "El Dorado Tank Assets" and, together with the El Dorado Terminal, the “El Dorado Terminal and Tank Assets”) at and adjacent to the El Dorado Refinery (such transaction, the “El Dorado Acquisition”). On March 31, 2015, the Partnership, through OpCo, acquired from Delek two crude oil rail offloading racks, which are designed to receive up to 25,000 barrels per day (“bpd”) of light crude oil or 12,000 bpd of heavy crude oil, or any combination of the two, delivered by rail to the El Dorado Refinery and related ancillary assets (the “El Dorado Assets”) (such transaction, the "El Dorado Offloading Racks Acquisition"). On March 31, 2015, the Partnership, through its wholly owned subsidiary Delek Logistics Marketing, acquired from Delek a crude oil storage tank located adjacent to the Tyler Refinery (the "Tyler Crude Tank") and certain ancillary assets (collectively, with the Tyler Crude Tank, the "Tyler Assets") (such transaction, the "Tyler Crude Tank Acquisition"). The Tyler Crude Tank has approximately 350,000 barrels of shell capacity and is expected to primarily support the Tyler Refinery. The Tyler Assets, together with the El Dorado Assets, are hereinafter collectively referred to as the "Logistics Assets." The Tyler Acquisition, the El Dorado Acquisition, the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition are hereinafter collectively referred to as the "Acquisitions from Delek." The Acquisitions from Delek were accounted for as transfers between entities under common control. As entities under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of the Partnership have been retrospectively adjusted to include (i) the historical results of the Tyler Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through July 26, 2013 (the "Tyler Predecessor"), (ii) the historical results of the El Dorado Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through February 10, 2014 (the "El Dorado Predecessor"), (iii) the historical results of the El Dorado Assets, as owned and operated by Delek, for all periods presented through March 31, 2015 (the "El Dorado Assets Predecessor") and (iv) the historical results of the Tyler Assets, as owned and operated by Delek, for all periods presented through March 31, 2015 (the "Tyler Assets Predecessor"). The El Dorado Assets Predecessor, together with the Tyler Assets Predecessor, are hereinafter collectively referred to as the "Logistics Assets Predecessor." We refer to the historical results of the Tyler Predecessor, the El Dorado Predecessor, the El Dorado Assets Predecessor and the Tyler Assets Predecessor collectively as our "Predecessors." See Note 3 for further information regarding the El Dorado Acquisition and the Tyler Acquisition. Description of Business The Partnership primarily owns and operates logistics and marketing assets for crude oil and intermediate and refined products. A substantial majority of our existing assets are integral to and dependent on the success of Delek’s refining and marketing operations. We gather, transport and store crude oil and market, wholesale market, distribute, transport and store refined products in select regions of the southeastern United States and west Texas for Delek and third parties. The Partnership generates revenue by charging fees for gathering, transporting and storing crude oil and for marketing, wholesale marketing, distributing, transporting and storing refined products. A substantial majority of our contribution margin, which we define as net sales less cost of goods sold and operating expenses, is derived from commercial agreements with Delek with initial terms ranging from five to ten years.

Accounting Policies (Notes)

Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Accounting Policies [Text Block]	Accounting Policies Basis of Presentation Our consolidated financial statements include the accounts of the Partnership and its subsidiaries as well as our Predecessors. All intercompany accounts and transactions have been eliminated. The financial statements of our Predecessors have been prepared from the separate records maintained by Delek and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. Our Predecessors did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. As an entity under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value. We have evaluated subsequent events through the filing of this Annual Report on Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. The preparation of financial statements in conformity with U.S. generally accepted accounting principles (“U.S. GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Reclassifications Certain prior period amounts have been reclassified in order to conform to the current year presentation. Segment Reporting We are an energy business focused on crude oil, intermediate and refined products pipeline and storage activities and wholesale marketing, terminalling and offloading activities. Management reviews operating results in two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. The pipelines and transportation segment provides crude oil gathering, transportation and storage services to Delek's refining operations and independent third parties. The wholesale marketing and terminalling segment provides marketing, wholesale marketing and terminalling services to Delek's refining operations and independent third parties. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on the segment contribution margin. Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization. Segment reporting is more fully discussed in Note 15 . Cash and Cash Equivalents We maintain cash and cash equivalents in accounts with large, U.S. financial institutions. All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents. Accounts Receivable Accounts receivable primarily consists of trade receivables generated in the ordinary course of business. We perform on-going credit evaluations of our customers and generally do not require collateral on accounts receivable. All accounts receivable amounts are considered to be fully collectible. Accordingly, no allowance has been established as of December 31, 2015 and 2014 . One customer accounted for approximately 15.2% and 21.0% of the consolidated accounts receivable balance as of December 31, 2015 and 2014 , respectively. Inventory Inventory consists of refined products, which are stated at the lower of cost or market with cost determined on a first-in, first-out ("FIFO") basis. One third party vendor and Delek accounted for approximately 62.6% and 24.9% , respectively, of our consolidated inventory purchases in our wholesale marketing and terminalling segment during the year ended December 31, 2015 . One vendor in the wholesale marketing and terminalling segment accounted for a total of 69.0% of our consolidated inventory purchases during the year ended December 31, 2014 . Two vendors in the wholesale marketing and terminalling segment accounted for 96.1% of our consolidated inventory purchases during the year ended December 31, 2013 . Property, Plant and Equipment Assets acquired in conjunction with acquisitions are recorded at estimated fair market value in accordance with the purchase method of accounting as prescribed in Financial Accounting Standards Board ("FASB") Statement of Financial Accounting Standards Codification ("ASC") 805, Business Combinations ("ASC 805"). Other acquisitions of property and equipment are carried at cost. Betterments, renewals and extraordinary repairs that extend the life of an asset are capitalized. Maintenance and repairs are charged to expense as incurred. Depreciation is computed using the straight-line method over management’s estimated useful lives of the related assets, except for automotive equipment, which is depreciated using a declining-balance method. The estimated useful lives are as follows: Years Building and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 Intangible Assets Intangible assets consist of long-term supply contracts and indefinite-lived rights of way. We amortize the definite-lived long-term supply contracts on a straight-line basis over the estimated useful life of 11.5 years. The amortization expense is included in depreciation and amortization in the accompanying consolidated financial statements. Property, Plant and Equipment and Intangibles Impairment Property, plant and equipment and definite life intangibles are evaluated for impairment whenever indicators of impairment exist. In accordance with ASC 360, Property, Plant and Equipment and ASC 350, Intangibles - Goodwill and Other, we evaluate the realizability of these long-lived assets as events occur that might indicate potential impairment. In doing so, we assess whether the carrying amount of the asset is unrecoverable by estimating the sum of the future cash flows expected to result from the asset, undiscounted and without interest charges. If the carrying amount is more than the recoverable amount, an impairment charge must be recognized based on the fair value of the asset. Goodwill and Potential Impairment Goodwill in an acquisition represents the excess of the aggregate purchase price over the fair value of the identifiable net assets. Our goodwill is recorded at original fair value and is not amortized. Goodwill is subject to annual assessment to determine if an impairment of value has occurred and we perform this review annually in the fourth quarter. We could also be required to evaluate our goodwill if, prior to our annual assessment, we experience disruptions in our business, have unexpected significant declines in operating results, or sustain a permanent market capitalization decline. If an asset’s carrying amount exceeds its fair value, the impairment assessment leads to the testing of the implied fair value of the asset’s goodwill to its carrying amount. If the implied fair value is less than the carrying amount, a goodwill impairment charge is recorded. Our annual assessment of goodwill did not result in an impairment charge during the years ended December 31, 2015 , 2014 , or 2013 . Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in our combined consolidated balance sheet and adjusted for our shares of the net earnings and losses of the investee and cash distributions, which are separately stated in our combined consolidated statement of operations and our combined consolidated statement of cash flows. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary. Derivatives We record all derivative financial instruments, including forward fuel contracts, at estimated fair value in accordance with the provisions of ASC 815, Derivatives and Hedging ("ASC 815"). Changes in the fair value of the derivative instruments are recognized in operations, unless we elect to apply the hedge accounting treatment permitted under the provisions of ASC 815 allowing such changes to be classified as other comprehensive income. We validate the fair value of all derivative financial instruments on a periodic basis, utilizing exchange pricing and/or price index developers such as Platts or Argus. During the years ended December 31, 2015 , 2014 , and 2013 , we did not elect to apply hedge accounting treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of income and comprehensive income. Our policy under the guidance of ASC 815-10-45, Derivatives and Hedging—Other Presentation Matters ("ASC 815-10-45"), is to net the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and offset these values against any cash collateral associated with these derivative positions. See Note 17 for further discussion. Fair Value of Financial Instruments The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments ("ASC 825"). We apply the provisions of ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), in our presentation and disclosures regarding fair value, which pertain to certain financial assets and liabilities measured at fair value in the balance sheet on a recurring basis. ASC 820 defines fair value, establishes a framework for measuring fair value and expands disclosures about such measurements that are permitted or required under other accounting pronouncements. See Note 16 for further discussion. We apply the provisions of ASC 825 as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. By electing the fair value option in conjunction with a derivative, an entity can achieve an accounting result similar to a fair value hedge without having to comply with complex hedge accounting rules. As of December 31, 2015 or 2014 , we did not make the fair value election for any financial instruments not already carried at fair value in accordance with other standards. Self-Insurance Reserves We have no employees. Rather, we are managed by the directors and officers of our general partner. However, Delek employees providing services to the Partnership are covered under Delek’s insurance programs. Delek has workers' compensation and liability insurance with varying retentions and deductibles with limits that management considers adequate. Environmental Expenditures We have historically accrued environmental and clean-up related costs of a non-capital nature when it is both probable that a liability has been incurred and the amount can be reasonably estimated. Environmental liabilities represent the current estimated costs to investigate and remediate contamination at our properties. This estimate is based on internal and third-party assessments of the extent of the contamination, the selected remediation technology and review of applicable environmental regulations, typically considering estimated activities and costs for the next 15 years, unless a specific longer range estimate is practicable. Accruals for estimated costs from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study and include, but are not limited to, costs to perform remedial actions and costs of machinery and equipment that are dedicated to the remedial actions and that does not have an alternative use. Such accruals are adjusted as further information develops or circumstances change. We discount environmental liabilities to their present value if payments are fixed and determinable. Expenditures for equipment necessary for environmental issues relating to ongoing operations are capitalized. Estimated recoveries of costs from other parties are recorded on an undiscounted basis as assets when their realization is deemed probable. Asset Retirement Obligations We recognize liabilities which represent the fair value of a legal obligation to perform asset retirement activities, including those that are conditional on a future event, when the amount can be reasonably estimated. These obligations are related to the required cleanout of our pipelines and terminal tanks, and removal of certain above-grade portions of our pipelines situated on right-of-way property. The reconciliation of the beginning and ending carrying amounts of asset retirement obligations as of December 31, 2015 and 2014 is as follows (in thousands): December 31, 2015 2014 Beginning balance $ 3,319 $ 3,087 Liabilities settled (64 ) — Accretion expense 251 232 Ending balance $ 3,506 $ 3,319 In order to determine fair value, management must make certain estimates and assumptions including, among other things, projected cash flows, a credit-adjusted risk-free rate and an assessment of market conditions that could significantly impact the estimated fair value of the asset retirement obligation. Revenue Recognition Revenues for products sold are recorded at the point of sale upon delivery of product, which is the point at which title to the product is transferred, and when payment has either been received or collection is reasonably assured. Service revenues are recognized as crude oil, intermediate and refined products are shipped through, delivered by or stored in our pipelines, trucks, terminals and storage facility assets, as applicable. We do not recognize product sales revenues for these services, as title on the product never passes to us. All service revenues are based on regulated tariff rates or contractual rates. Cost of Goods Sold and Operating Expenses Cost of goods sold includes all costs of refined products, additives and related transportation. It also includes costs associated with the operation of our trucking assets. We do not recognize product cost of sales related to our shipping, delivering and storage services, as title to the product never passes to us. Operating expenses include the costs associated with the operation of owned terminals and other logistics assets, terminalling expense at third-party locations and pipeline maintenance costs. Sales, Use and Excise Taxes Our policy is to exclude sales, use and excise taxes from revenue when we are an agent of the taxing authority, in accordance with ASC 605-45, Revenue Recognition—Principal Agent Considerations . Deferred Financing Costs Deferred financing costs are included in other non-current assets in the accompanying consolidated balance sheets and represent expenses related to issuing and amending our revolving credit facility. These amounts are amortized ratably over the remaining term of our revolving credit facility and are included in interest expense in the accompanying consolidated statements of income and comprehensive income. Operating Leases We lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term, to renew the leases. None of these lease arrangements include fixed rental rate increases. Income Taxes We are not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of these income taxes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under our partnership agreement. We are subject to income taxes in certain states that do not follow the federal tax treatment of Partnerships. These income taxes are accounted for under the provisions of ASC 740, Income Taxes (ASC 740). This statement generally requires DKL to record deferred income taxes for the differences between the book and tax bases of its assets and liabilities, which are measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. Deferred income tax expense or benefit represents the net change during the year in our deferred income tax assets and liabilities, exclusive of the amounts held in other comprehensive income. U.S. GAAP requires management to evaluate uncertain tax positions taken by the Partnership. The financial statement effects of a tax position are recognized when the position is more likely than not, based on the technical merits, to be sustained upon examination by the Internal Revenue Service. Management has analyzed the tax positions taken by the Partnership, and has concluded that there are no uncertain positions taken or expected to be taken. The Partnership is subject to routine audits by taxing jurisdictions; however, there are currently no audits for any tax periods in progress. Equity Based Compensation Our general partner provides equity-based compensation to officers, directors and employees of our general partner or its affiliates, and certain consultants, affiliates of our general partner or other individuals who perform services for us, which includes unit options, restricted units, phantom units, unit appreciation rights, distribution equivalent rights, other unit-based awards and unit awards. Phantom units are measured based on the fair market value of the underlying stock on the date of grant. The fair value of our phantom units is determined based on the closing price of our common units on the grant date. The estimated fair value of our phantom units is amortized over the vesting period using the straight line method. All awards made through June 9, 2015 vest over a five-year service period unless such awards are amended in accordance with the LTIP. Beginning June 10, 2015, all awards made to only non-employee directors vest over a three-year service period unless such awards are amended in accordance with the LTIP. It is our practice to issue new units when phantom units vest. Net Income per Limited Partner Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and incentive distribution rights ("IDRs"). The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. At present, the only potentially dilutive units outstanding consist of unvested phantom units. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding. Comprehensive Income Comprehensive income for the years ended December 31, 2015 , 2014 , and 2013 was equivalent to net income. New Accounting Pronouncements In November 2015, the FASB issued guidance that requires deferred income tax liabilities and assets to be classified as noncurrent in a classified balance sheet, rather than being classified as current or noncurrent based on the classification of the related asset or liability for financial reporting, as previously required by the guidance. This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years and can be early adopted for any interim or annual financial statements that have not yet been issued. We prospectively adopted this guidance in the fourth quarter of 2015 and all deferred income tax liabilities and assets are now classified as noncurrent in our consolidated balance sheet as of December 31, 2015 . The adoption did not have a material impact on our business, financial position or results of operations. In September 2015, the FASB issued guidance that eliminates the requirement for an acquirer in a business combination to account for measurement-period adjustments retrospectively. Instead, acquirers must recognize measurement-period adjustments during the period in which they determine the amounts, including the effect on earnings of any amounts they would have recorded in previous periods if the accounting had been completed at the acquisition date. This guidance is effective for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years and can be early adopted for any interim or annual financial statements that have not yet been issued. We have prospectively adopted this guidance as of the fourth quarter of 2015 and the adoption did not have a material impact on our business, financial position or results of operations. In July 2015, the FASB issued guidance requiring entities to measure FIFO or average cost inventory at the lower of cost and net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. This guidance does not change the measurement of inventory measured using last-in, first-out or the retail inventory method. This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years and can be early adopted at the beginning of any interim or annual period for which financial statements have not yet been issued. We expect to adopt this guidance on or before the effective date, and we do not anticipate that the adoption will have a material impact on our business, financial position or results of operations. In April 2015, the FASB issued guidance which requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. Prior to the issuance of this guidance, debt issuance costs were required to be presented in the balance sheet as an asset. In August 2015, the FASB issued further clarification regarding an SEC staff announcement related to this guidance which permits entities to defer and present debt issuance costs associated with line-of-credit arrangements as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. Upon adoption, the guidance requires prior period financial statements to be retrospectively adjusted. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, with early adoption permitted. We adopted this guidance on December 31, 2015 and this adoption did not have a material impact on our business, financial position or results of operations. In April 2015, the FASB issued guidance regarding the effects on historical earnings per unit of master limited partnership dropdown transactions. This ASU specifies that for purposes of calculating historical earnings per unit under the two-class method, the earnings of a transferred business before the date of a dropdown transaction should be allocated entirely to the general partner and, therefore, the previously reported earnings per unit of the limited partners would not change as a result of the dropdown transaction. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, and shall be applied retrospectively to each period presented. We expect to adopt this guidance as of the effective date and we do not anticipate that the adoption will have a material impact on our business, financial position or results of operations. In May 2014, the FASB issued guidance regarding “Revenue from Contracts with Customers,” to clarify the principles for recognizing revenue. The core principle of the new guidance is that an entity 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 guidance also requires improved interim and annual disclosures that enable the users of financial statements to better understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period, and can be adopted either retrospectively to each prior reporting period presented using a practical expedient as allowed by the new guidance or retrospectively with a cumulative effect adjustment to retained earnings as of the date of initial application. Early adoption is not permitted. We are currently evaluating the impact that adopting this new standard will have on our business, financial position or results of operations.

Acquisitions (Notes)

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2015
Acquisitions [Abstract]
Acquisitions	Acquisitions Acquisitions from Delek The Partnership completed various transactions with Delek and our general partner during the years ended December 31, 2015 , 2014 and 2013 pursuant to which we acquired the following assets from Delek: • the El Dorado Assets effective March 31, 2015 for approximately $42.5 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility. • the Tyler Assets effective March 31, 2015 for approximately $19.4 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility. • the El Dorado Terminal and Tank Assets effective February 10, 2014 for $95.9 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility. • the Tyler Terminal and Tank Assets effective July 26, 2013 for $94.8 million in cash. Financial Results of the El Dorado Assets and the Tyler Assets The acquisitions of the El Dorado Assets and the Tyler Assets were considered transfers of businesses between entities under common control. Accordingly, the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition were recorded at amounts based on Delek's historical carrying value as of each respective acquisition date, which were $7.6 million and $11.6 million as of March 31, 2015 , respectively. Our historical financial statements have been retrospectively adjusted to reflect the results of operations, financial position, cash flows and equity attributable to the El Dorado Assets and the Tyler Assets as if we owned the assets for all periods presented. The results of the El Dorado Assets and the Tyler Assets are included in the pipelines and transportation segment. The following amounts associated with the El Dorado Assets and the Tyler Assets subsequent to March 31, 2015 , are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands): Year Ended December 31, 2015 El Dorado Assets Total operating revenues $ 4,449 Net income attributable to the Partnership $ 3,277 Costs associated with the acquisition $ 235 Tyler Assets Total operating revenues $ 1,620 Net income attributable to the Partnership $ 1,035 Costs associated with the acquisition $ 240 The results of the El Dorado Assets operations and the Tyler Assets operations prior to the completion of the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition on March 31, 2015 have been included in the El Dorado Assets Predecessor and Tyler Assets Predecessor results in the tables below. The results of the El Dorado Assets and the Tyler Assets subsequent to March 31, 2015 have been included in the Partnership's results. The tables below present our balance sheet and results of operations, the effect of including the results of the El Dorado Assets and the Tyler Assets, and the adjusted total amounts included in our consolidated financial statements. Consolidated Balance Sheet as of December 31, 2014 Delek Logistics Partners, LP El Dorado Assets Predecessor Tyler Assets Predecessor December 31, 2014 (In thousands) ASSETS Current Assets: Cash and cash equivalents $ 1,861 $ — $ — $ 1,861 Accounts receivable 27,986 — — 27,986 Inventory 10,316 — — 10,316 Deferred tax assets 28 — — 28 Other current assets 768 — — 768 Total current assets 40,959 — — 40,959 Property, plant and equipment: Property, plant and equipment 288,045 8,267 11,776 308,088 Less: accumulated depreciation (52,992 ) (317 ) — (53,309 ) Property, plant and equipment, net 235,053 7,950 11,776 254,779 Goodwill 11,654 — — 11,654 Intangible assets, net 16,520 — — 16,520 Other non-current assets 7,374 — — 7,374 Total assets $ 311,560 $ 7,950 $ 11,776 $ 331,286 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 17,929 $ — $ — $ 17,929 Accounts payable to related parties 628 — — 628 Excise and other taxes payable 5,443 — — 5,443 Tank inspection liabilities 2,829 — — 2,829 Pipeline release liabilities 1,899 — — 1,899 Accrued expenses and other current liabilities 1,588 — 1,588 Total current liabilities 30,316 — — 30,316 Non-current liabilities: Revolving credit facility 251,750 — — 251,750 Asset retirement obligations 3,319 — — 3,319 Deferred tax liabilities 231 — — 231 Other non-current liabilities 5,889 — — 5,889 Total non-current liabilities 261,189 — — 261,189 Equity: Predecessors division equity — 7,950 11,776 19,726 Common unitholders - public (9,417,189 units issued and outstanding) 194,737 — — 194,737 Common unitholders - Delek (2,799,258 units issued and outstanding) (241,112 ) — — (241,112 ) Subordinated unitholders - Delek (11,999,258 units issued and outstanding) 73,515 — — 73,515 General Partner unitholders - Delek (494,197 units issued and outstanding) (7,085 ) — — (7,085 ) Total equity 20,055 7,950 11,776 39,781 Total liabilities and equity $ 311,560 $ 7,950 $ 11,776 $ 331,286 Consolidated Statements of Income Delek Logistics Partners, LP El Dorado Assets Predecessor Tyler Assets Year Ended December 31, 2015 (In thousands) Net Sales $ 589,669 $ — $ — $ 589,669 Operating costs and expenses: Cost of goods sold 436,304 — — 436,304 Operating expenses 44,756 167 — 44,923 General and administrative expenses 11,384 — — 11,384 Depreciation and amortization 19,222 372 98 19,692 Loss on asset disposals 104 — — 104 Total operating costs and expenses 511,770 539 98 512,407 Operating income (loss) 77,899 (539 ) (98 ) 77,262 Interest expense, net 10,658 — — 10,658 Loss on equity method investments 588 — — 588 Total non-operating expenses 11,246 — — 11,246 Income (loss) before income tax benefit 66,653 (539 ) (98 ) 66,016 Income tax benefit (195 ) — — (195 ) Net income (loss) 66,848 (539 ) (98 ) 66,211 Less: loss attributable to Predecessors — (539 ) (98 ) (637 ) Net income attributable to partners $ 66,848 $ — $ — $ 66,848 Delek Logistics Partners, LP El Dorado Assets Predecessor Year Ended December 31, 2014 (1) (In thousands) Net Sales $ 841,253 $ — $ 841,253 Operating costs and expenses: Cost of goods sold 697,221 — 697,221 Operating expenses 38,003 679 39,465 General and administrative expenses 10,570 — 10,616 Depreciation and amortization 14,591 317 15,022 Loss on asset disposals 83 — 83 Total operating costs and expenses 760,468 996 762,407 Operating income (loss) 80,785 (996 ) 78,846 Interest expense, net 8,656 — 8,656 Income (loss) before income tax expense 72,129 (996 ) 70,190 Income tax expense 132 — 132 Net income (loss) 71,997 (996 ) 70,058 Less: loss attributable to Predecessors — (996 ) (1,939 ) Net income attributable to partners $ 71,997 $ — $ 71,997 Delek Logistics Partners, LP El Dorado Assets Predecessor Year Ended December 31, 2013 (1) (In thousands) Net Sales $ 907,428 $ — $ 907,428 Operating costs and expenses: Cost of goods sold 811,364 — 811,364 Operating expenses 35,640 263 35,903 General and administrative expenses 7,526 — 7,526 Depreciation and amortization 13,738 — 13,738 Loss on asset disposals 166 — 166 Total operating costs and expenses 868,434 263 868,697 Operating income (loss) 38,994 (263 ) 38,731 Interest expense, net 4,570 — 4,570 Income (loss) before income tax expense 34,424 (263 ) 34,161 Income tax expense 757 — 757 Net income (loss) 33,667 (263 ) 33,404 Less: loss attributable to Predecessors (14,163 ) (263 ) (14,426 ) Net income attributable to partners $ 47,830 $ — $ 47,830 (1) There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013 , as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services. Acquisitions from Third Parties During the years ended December 31, 2014 and 2013 , we acquired certain transportation, pipeline and terminalling assets to complement our existing assets, provide enhanced logistical capabilities and further our presence in certain areas. The acquisitions include the following: • On December 17, 2014 we acquired substantially all of the assets of Frank Thompson Transport, Inc. ("FTT"), a company that primarily hauled crude oil and asphalt products by transport truck, including 123 trucks and 205 trailers (the "FTT Assets"). • On October 1, 2014 we acquired from an affiliate of Magellan Midstream Partners, LP (i) a light products terminal in Mount Pleasant, Texas consisting of approximately 200,000 barrels of light product storage capacity, three truck loading lanes and ethanol blending capability (the "Mount Pleasant Terminal"), (ii) a light products storage facility in Greenville, Texas with approximately 325,000 barrels of storage capacity and a connection to the Explorer Pipeline System, a common carrier pipeline owned by a third party (the "Greenville Storage Facility"), and (iii) a 76-mile pipeline connecting the locations (the "Greenville-Mount Pleasant Pipeline"). The Mount Pleasant Terminal, the Greenville Storage Facility and the Greenville-Mount Pleasant Pipeline are hereinafter collectively referred to as the "Greenville-Mount Pleasant Assets." • On October 24, 2013 , we acquired from Enterprise Refined Products Company, LLC a refined product terminal in Little Rock, Arkansas consisting of a total of three products tanks with effective capacity of 140,000 barrels and a truck rack with throughput capacity of up to 10,000 bpd (the "North Little Rock Terminal"). • On July 19, 2013 , we acquired a 13.5-mile pipeline and certain ancillary assets (the "Hopewell Pipeline"), including a related delivery station (the "Hopewell Station") and pumps. The Hopewell Pipeline originates at the Tyler Refinery and terminates at the Hopewell Station, where it effectively connects to a 19-mile pipeline (the "Big Sandy Pipeline") that was owned by the Partnership at the time the Hopewell Pipeline was acquired and that originates at our light petroleum products terminal located in Big Sandy, Texas. The Hopewell Pipeline and the Big Sandy Pipeline form essentially one pipeline link between the Tyler Refinery and the Big Sandy Terminal (the "Tyler-Big Sandy Pipeline"). Purchase Price Allocations - Acquisitions from Third Parties The following table summarizes the allocation of the aggregate purchase price for each of the third party acquisitions described above (in thousands): FTT Assets (1) Greenville-Mount Pleasant Assets (2) North Little Rock Terminal Hopewell Property, plant and equipment $ 10,790 $ 4,829 $ 4,990 $ 3,538 Intangible assets — 5,171 10 984 Goodwill (3) 549 — — 1,200 Inventory — 1,125 — — Accounts Receivable 1,767 — — — Accounts Payable (1,181 ) — — — Total $ 11,925 $ 11,125 $ 5,000 $ 5,722 (1) During the fourth quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed in connection with working capital adjustments and an additional $0.4 million of consideration paid for additional assets. (2) During the third quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed. (3) All goodwill is expected to be deductible for tax purposes. Pro Forma Financial Information - Acquisitions from Third Parties Below are the unaudited pro forma consolidated results of operations of the Partnership for the years ended December 31, 2014 and 2013 , as if our 2014 acquisitions had occurred on January 1, 2013 (in thousands): Year Ended December 31, 2014 Year Ended December 31, 2013 As Reported Pro Forma As Reported Pro Forma FTT Assets: Net Sales $ 841,253 $ 854,842 $ 907,428 $ 921,017 Net income $ 70,058 $ 70,824 $ 33,404 $ 34,170 Greenville-Mount Pleasant Assets: Net Sales $ 841,253 $ 841,943 $ 907,428 $ 908,118 Net income $ 70,058 $ 69,621 $ 33,404 $ 32,967 Below are the unaudited pro forma consolidated results of operations of the Partnership for the year ended December 31, 2013 , as if our 2013 acquisitions had occurred on January 1, 2012 (in thousands): Year Ended December 31, 2013 As Reported Pro Forma North Little Rock Terminal: Net Sales $ 907,428 $ 908,867 Net income $ 33,404 $ 34,695 Hopewell: Net Sales $ 907,428 $ 908,382 Net income $ 33,404 $ 33,718

Related Party Transactions (Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Commercial Agreements The Partnership has various long-term, fee-based commercial agreements with Delek under which we provide crude oil gathering, crude oil, intermediate and refined products transportation and storage services and marketing, terminalling and offloading services to Delek. Each of these agreements include minimum quarterly volume or throughput commitments and have tariffs or fees indexed to inflation, provided that the tariffs or fees will not be decreased below the initial amount. Fees under each agreement are payable to us monthly by Delek or certain third parties to whom Delek has assigned certain of its rights. In most circumstances, if Delek or the applicable third party assignee fails to meet or exceed the minimum volume or throughput commitment during any calendar quarter, Delek, and not any third party assignee, will be required to make a quarterly shortfall payment to us equal to the volume of the shortfall multiplied by the applicable fee. Carry-over of any volumes in excess of such commitment to any subsequent quarter is not permitted. Exceptions to this requirement that Delek make minimum payments under a given agreement can exist if (i) there is an event of force majeure affecting our asset, or (ii) after the first three years of the applicable commercial agreement's term (a) there is an event of force majeure affecting the applicable Delek asset, or (b) if Delek shuts down the applicable refinery upon giving 12 months' notice, which such notice may only be given after the first two years of the applicable commercial agreement's term. In addition, Delek may terminate any of these agreements under certain circumstances. Under each of these agreements, we are required to maintain the capabilities of our pipelines and terminals such that Delek may throughput and/or store, as the case may be, specified volumes of crude oil, intermediate and refined products. To the extent that Delek is prevented by our failure to maintain such capacities from throughputting or storing such specified volumes for more than 30 days per year, Delek's minimum throughput commitment will be reduced proportionately and prorated for the portion of the quarter during which the specified throughput capacity was unavailable, and/or the storage fee will be reduced, prorated for the portion of the month during which the specified storage capacity was unavailable. Such reduction would occur even if actual throughput or storage amounts were below the minimum volume commitment levels. The tariffs, throughput fees and the storage fees under our agreements with Delek are subject to increase or decrease on July 1 of each year, by the amount of any change in the FERC oil pipeline index or, in the case of the east Texas marketing agreement, to the consumer price index and, in the case of the El Dorado Throughput and Tankage Agreement and the Tyler Throughput and Tankage Agreement, to other inflation-based indices; provided, however, that in no event will the fees be adjusted below the amount initially set forth in the applicable agreement. Our material commercial agreements with Delek include the following: Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (/bbl) Lion Pipeline System and SALA Gathering System: Crude Oil Pipelines (non-gathered) November 2012 5 / 15 Crude oil and refined products transportation 46,000 (2) $ 0 .97 (3) Refined Products Pipelines November 2012 5 / 15 40,000 $ 0.11 SALA Gathering System November 2012 5 / 15 Crude oil gathering 14,000 $ 2.56 (3) East Texas Crude Logistics System: Crude Oil Pipelines November 2012 5 / 15 Crude oil transportation and storage 35,000 $ 0.45 (4) Storage November 2012 5 / 15 N/A $ 284,090/month East Texas Marketing November 2012 10 (5) Marketing products for Tyler Refinery 50,000 $ 0.621/bbl (5) Big Sandy Terminal: (6) Refined Products Transportation November 2012 5 / 15 Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery 5,000 $ 0.57 Terminalling November 2012 5 / 15 5,000 $ 0.57 Storage November 2012 5 / 15 N/A $ 56,768/month Tyler Throughput and Tankage: Refined Products Throughput July 2013 8 / 16 Dedicated Terminalling and storage 50,000 $ 0.35 Storage July 2013 8 / 16 N/A $ 829,902/month Memphis Pipeline October 2013 5 Refined Products Transportation 10,959 $ 1.38/bbl El Dorado Throughput and Tankage: Refined Products Throughput February 2014 8 / 16 Dedicated terminalling and storage 11,000 $ 0.50/bbl Storage February 2014 8 / 16 N/A $1,309,085/month El Dorado Assets Throughput: Light Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (7) $ 1.00 Heavy Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (7) $ 2.25 (1) Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof. (2) Excludes volumes gathered on the SALA Gathering System. (3) Volumes gathered on the SALA Gathering System will not be subject to an additional fee for transportation on our Lion Pipeline System to the El Dorado Refinery. (4) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.682 /bbl. (5) Following the primary term, the marketing agreement automatically renews for successive one-year terms unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. An additional fee of 50% of the margin on products sold is also paid pursuant to the agreement. The fee shall not be less than $175,000 nor greater than $500,000 per quarter. (6) On July 19, 2013, we acquired the Hopewell Pipeline in order to effectively connect it with the Big Sandy Pipeline and thereby return the Big Sandy Terminal to operation. In connection with the acquisition, on July 25, 2013, we and Delek entered into the Amended and Restated Services Agreement (Big Sandy Terminal and Pipeline), which amended and restated the terminalling services agreement for the Big Sandy Terminal originally entered into in connection with the Offering. (7) The throughput agreement provides for a minimum throughput fee of $1.5 million per quarter for throughput of a combination of light and heavy crude. Pursuant to an arrangement with Delek and Lion Oil, to which we are not a party, J. Aron & Company ("J. Aron") acquires and holds title to substantially all crude oil, intermediate and refined products transported on our Lion Pipeline System, SALA Gathering System and on pipeline capacity we lease from Enterprise TE Products Pipeline Company LLC that runs from the El Dorado Refinery to our Memphis Terminal (the "Memphis Pipeline"). J. Aron is therefore considered the shipper for the liquid it owns on the Lion Pipeline System, the SALA Gathering System and the Memphis Pipeline. J. Aron also has title to the refined products stored at our Memphis, North Little Rock and El Dorado terminals and in the El Dorado Storage Tanks. Under (i) our pipelines and storage agreement with Lion Oil relating to the Lion Pipeline System and the SALA Gathering System, (ii) our terminalling agreements with Lion Oil relating to the Memphis and North Little Rock terminals and (iii) our throughput and tankage agreement relating to the El Dorado Terminal and Tank Assets, Lion Oil has assigned to J. Aron certain of its rights under these agreements, including the right to have J. Aron's crude oil and intermediate and refined products stored in or transported on or through these systems, Memphis and North Little Rock terminals and the El Dorado Terminal and Tank Assets, with Lion Oil acting as J. Aron's agent for scheduling purposes. Accordingly, even though this is effectively a financing arrangement for Delek whereby J. Aron sells the product back to Delek, J. Aron is technically our primary customer under each of these agreements. J. Aron will retain these storage and transportation rights for the term of its arrangement with Delek and Lion Oil, which currently runs through April 30, 2017, and J. Aron will pay us for the transportation, throughput and storage services we provide to it. The rights assigned to J. Aron will not alter Lion Oil's obligations to meet certain throughput minimum volumes under our agreements with respect to the transportation, throughputting and storage of crude oil, intermediate and refined products through our facilities, but J. Aron's throughput will be credited toward Lion Oil's minimum throughput commitments. Accordingly, Lion Oil will be responsible for making any shortfall payments incurred under the pipelines and storage agreement or the terminalling agreement which may result from minimum throughputs or volumes not being met. Other Agreements with Delek In addition to the commercial agreements described above, the Partnership has entered into the following agreements with Delek: Omnibus Agreement Omnibus Agreement. The Partnership entered into an omnibus agreement with Delek, our general partner, OpCo, Lion Oil Company and certain of the Partnership’s and Delek’s other subsidiaries on November 7, 2012, which was subsequently amended and restated on July 26, 2013, February 10, 2014 and March 31, 2015 in connection with our subsequent acquisitions from Delek (collectively, the "Omnibus Agreement"). The third amendment and restatement occurring on March 31, 2015 provided for the following: (i) revisions of the schedules to include the El Dorado Assets and the Tyler Assets, (ii) revisions of certain provisions and schedules with respect to certain environmental matters, (iii) the addition of DKL Transportation, LLC as a party to the agreement, (iv) the elimination of certain provisions under the Omnibus Agreement that had expired, and (v) updating the annual administrative fee payable by us to Delek for general corporate and administrative services that Delek and its affiliates provide to us to reflect the inflationary increase provided under the Omnibus Agreement, from $3.3 million to $3.4 million , which is prorated and payable monthly. The Partnership entered into an amendment to the third amended and restated omnibus agreement on August 3, 2015, with an effective date of April 1, 2015 (the third amended and restated omnibus agreement between the Partnership, Delek and the general partner, as amended, is referred to as the "Third Restated Omnibus Agreement"). This amendment eliminated a $1.0 million per event deductible that applied to certain asset failures before Delek was required to reimburse the Partnership. During the years ended December 31, 2015 , 2014 and 2013 , we were reimbursed $5.2 million , $1.6 million and $0.8 million , respectively, for certain capital expenditures pursuant to the terms of the Omnibus Agreement. Additionally, we were reimbursed or indemnified, as the case may be, for costs incurred in excess of certain amounts for environmental matters pursuant to the terms of the Omnibus Agreement. We incurred costs of $1.0 million and $0.6 million related to these matters during the years ended December 31, 2014 and 2013 . Operation and Management Services Agreement Our general partner operates our business on our behalf and is entitled under our partnership agreement to be reimbursed for the cost of providing those services. Prior to the Tyler Acquisition, we and our general partner entered into an operation and management services agreement with Delek, pursuant to which our general partner uses employees of Delek to provide operation and management services with respect to our pipelines, storage and terminalling facilities and related assets. We and/or our general partner reimbursed Delek for such services under the operation and management services agreement for the period beginning November 7, 2012 and ending July 26, 2013 , at which time our general partner and Delek Logistics Services Company terminated the operation and management services agreement in connection with the Tyler Acquisition. We and our subsidiaries paid Delek approximately $5.9 million pursuant to this agreement during the year ended December 31, 2013 . Subsequent to the termination of the agreement, we continued to reimburse our general partner for the services it provides to us under our partnership agreement. We reimbursed our general partner $22.8 million , $12.3 million and $6.5 million pursuant to the partnership agreement during the years ended December 31, 2015 , 2014 and 2013 , respectively. Other Agreements Paline Pipeline System Capacity Reservation . Prior to the Partnership's acquisition of Paline Pipeline Company, LLC, Paline had entered into a contract with an unrelated third party for such company to exclusively use 100% of the southbound capacity of our Paline Pipeline. This agreement expired by its terms on December 31, 2014. During the year ended December 31, 2013 , our customer did not pay 100% of the full monthly fee for the lease of capacity on the Paline Pipeline System. Pursuant to the Omnibus Agreement, Delek indemnified us $0.9 million during the year ended December 31, 2013 for lost service fees attributable to the failure of our customer to pay the full monthly fee pursuant to the agreement. We were not indemnified for lost service fees during the years ended December 31, 2015 and 2014 , as we received the entire monthly amount payable to us from our customer during these periods. Predecessors' Transactions Related-party transactions of the Predecessors were settled through division equity. Revenues from affiliates consist of revenues from gathering, pipeline transportation, storage, wholesale marketing and products terminalling services to Delek and its affiliates based on regulated tariff rates or contractually based fees. Costs related specifically to us have been identified and included in the accompanying consolidated statements of income and comprehensive income. Prior to the Acquisitions from Delek, we were not allocated certain corporate costs. These costs were primarily allocated based on a percentage of salaries expense and property, plant and equipment costs. In the opinion of management, the methods for allocating these costs are reasonable. It is not practicable to estimate the costs that would have been incurred by us if we had been operated on a stand-alone basis. Summary of Transactions Revenues from affiliates consist of revenues from gathering, pipeline transportation, storage, wholesale marketing and products terminalling services provided primarily to Delek and its affiliates based on regulated tariff rates or contractually based fees, as well as product sales to Alon USA Energy, Inc., an equity method investee of Delek. Affiliate operating expenses are primarily comprised of amounts we reimburse Delek, or our general partner, as the case may be, for the services provided to us under our partnership agreement. These expenses could also include reimbursement and indemnification amounts from Delek, as provided under the Third Restated Omnibus Agreement. Additionally, the Partnership is required to reimburse Delek for direct or allocated costs and expenses incurred by Delek on behalf of the Partnership and for charges Delek incurred for the management and operation of our logistics assets, including an annual fee for various centralized corporate services, which are included in general and administrative services. In addition to these transactions, we purchase finished products and bulk biofuels from Delek, the costs of which are included in cost of goods sold. A summary of revenue and expense transactions with Delek and its affiliates, including expenses directly charged and allocated to our Predecessors, are as follows (in thousands): Year Ended December 31, 2015 2014 2013 Revenues $ 152,564 $ 114,583 $ 78,173 Cost of Goods Sold $ 105,461 $ 56,045 $ 80,129 Operating and maintenance expenses (1) $ 31,636 $ 20,889 $ 16,331 General and administrative expenses (2) $ 6,356 $ 5,799 $ 4,010 (1) Operating and maintenance expenses include costs allocated to our Predecessors for operating support provided by Delek, including certain labor related costs, property and liability insurance costs and certain other operating expenses. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $1.4 million for the year ended December 31, 2013 . With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were $0.4 million and $1.4 million for the years ended December 31, 2014 and 2013 , respectively. With respect to the Logistics Assets, the costs that were allocated to us by Delek were $0.2 million , $0.7 million , and $0.3 million for the years ended December 31, 2015 , 2014 and 2013 , respectively. (2) General and administrative expenses include costs allocated to our Predecessors for general and administrative support provided by Delek, including services such as corporate management, risk management, accounting and human resources. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $0.5 million for the year ended December 31, 2013 . With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were $0.1 million and $0.7 million for the years ended December 31, 2014 and 2013 , respectively. No costs were allocated to the Logistics Assets Predecessor by Delek for the years ended December 31, 2015 , 2014 and 2013 . Quarterly Cash Distribution Our common and general partner unitholders and the holders of IDRs are entitled to receive quarterly distributions of available cash as it is determined by the board of directors of our general partner in accordance with the terms and provisions of our partnership agreement. During the years ended December 31, 2015 , 2014 and 2013 , we paid quarterly cash distributions, of which $35.9 million and $28.1 million and $21.5 million respectively, were paid to Delek and our general partner. On January 25, 2016 , our general partner's board of directors declared a quarterly cash distribution totaling $16.1 million , based on the available cash as of the date of determination for the end of the fourth quarter of 2015 , which was paid on February 12, 2016 to unitholders of record on February 5, 2016 . The distribution included $9.7 million , paid to both Delek and our general partner, including the distribution as holder of the IDRs.

Net Income Per Unit (Notes)

Net Income Per Unit (Notes)	12 Months Ended
	Dec. 31, 2015
Net Income Per Unit [Abstract]
Net Income Per Unit [Text Block]	Net Income Per Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and IDRs. The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement, which are declared and paid following the close of each quarter. Net income per unit is only calculated for periods after the Offering as no units were outstanding prior to November 7, 2012. Earnings in excess of distributions are allocated to our general partner and limited partners based on their respective ownership interests. Payments made to our unitholders are determined in relation to actual distributions declared and are not based on the net income allocations used in the calculation of net income per unit. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. At present, the only potentially dilutive units outstanding consist of unvested phantom units. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding. Our distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below represents total cash distributions applicable to the period in which the distributions are earned. The calculation of net income per unit is as follows (dollars in thousands, except per unit amounts): Year Ended December 31, 2015 2014 2013 Net income attributable to partners $ 66,848 $ 71,997 $ 47,830 Less: General partner's distribution (including IDRs) (1) 5,013 1,883 785 Less: Limited partners' distribution 27,439 23,152 19,292 Less: Subordinated partner's distribution 26,878 22,799 19,199 Earnings in excess of distributions $ 7,518 $ 24,163 $ 8,554 General partner's earnings: Distributions (including IDRs) (1) $ 5,013 $ 1,883 $ 785 Allocation of earnings in excess of distributions 150 483 172 Total general partner's earnings $ 5,163 $ 2,366 $ 957 Limited partners' earnings on common units: Distributions $ 27,439 $ 23,152 $ 19,292 Allocation of earnings in excess of distributions 3,721 11,933 4,198 Total limited partners' earnings on common units $ 31,160 $ 35,085 $ 23,490 Limited partners' earnings on subordinated units: Distributions $ 26,878 $ 22,799 $ 19,199 Allocation of earnings in excess of distributions 3,647 11,747 4,184 Total limited partner's earnings on subordinated units $ 30,525 $ 34,546 $ 23,383 Weighted average limited partner units outstanding: Common units - (basic) 12,237,154 12,171,548 12,025,249 Common units - (diluted) 12,356,914 12,302,629 12,148,774 Subordinated units - Delek (basic and diluted) 11,999,258 11,999,258 11,999,258 Net income per limited partner unit: Common - (basic) $ 2.55 $ 2.88 $ 1.95 Common - (diluted) $ 2.52 $ 2.85 $ 1.93 Subordinated - (basic and diluted) $ 2.54 $ 2.88 $ 1.95 (1) General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs.

Major Customer (Notes)

Major Customer (Notes)	12 Months Ended
	Dec. 31, 2015
Major Customer [Abstract]
Major Customer [Text Block]	Major Customers Sunoco LP accounted for 16.2% , 23.3% and 17.7% of our total revenues for the years ended December 31, 2015 , 2014 and 2013 , respectively. Delek, directly or indirectly, accounted for 25.9% , 13.6% and 8.6% of our total revenues for the years ended December 31, 2015 , 2014 and 2013 , respectively.

Inventory (Notes)

Inventory (Notes)	12 Months Ended
	Dec. 31, 2015
Inventory, Net [Abstract]
Inventory	Inventory Inventories consisted of $10.5 million and $10.3 million of refined petroleum products as of December 31, 2015 and December 31, 2014 , respectively. Cost of inventory is stated at the lower of cost or market with cost determined on a FIFO basis.

Property, Plant and Equipment (

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	Property, Plant and Equipment Property, plant and equipment, at cost, consist of the following (in thousands): December 31, 2015 2014 Land and land improvements $ 4,253 $ 2,953 Building and building improvements 1,886 1,169 Pipelines, tanks and terminals 299,101 268,339 Asset retirement obligation assets 2,073 2,073 Other equipment 4,270 3,764 Construction in process 14,064 29,790 325,647 308,088 Less: accumulated depreciation (71,799 ) (53,309 ) $ 253,848 $ 254,779 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2015 and 2014 are as follows (in thousands): As of and For the Year Ended December 31, 2015 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 266,169 $ 59,478 $ 325,647 Less: Accumulated depreciation (50,542 ) (21,257 ) (71,799 ) Property, plant and equipment, net $ 215,627 $ 38,221 $ 253,848 Depreciation expense $ 15,011 $ 3,618 $ 18,629 As of and For the Year Ended December 31, 2014 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 242,490 $ 65,598 $ 308,088 Less: Accumulated depreciation (36,776 ) (16,533 ) (53,309 ) Property, plant and equipment, net $ 205,714 $ 49,065 $ 254,779 Depreciation expense $ 10,712 $ 3,247 $ 13,959

Goodwill (Notes)

Goodwill (Notes)	12 Months Ended
	Dec. 31, 2015
Goodwill [Abstract]
Goodwill Disclosure [Text Block]	Goodwill Goodwill represents the excess of the aggregate purchase price over the fair value of the identifiable net assets acquired. Goodwill acquired in a purchase business combination is recorded at fair value and is not amortized. Our goodwill relates to the west Texas assets contributed to us by Delek Marketing & Supply, LLC ("Delek Marketing") in connection with our initial public offering (the "Offering") and to the purchase price allocation of certain of our acquisitions. We perform an annual assessment of whether goodwill retains its value. This assessment is done more frequently if indicators of potential impairment exist. We performed our annual goodwill impairment review in the fourth quarter of 2015 , 2014 and 2013 . We performed a discounted cash flows test, using a market participant weighted average cost of capital, and estimated minimal growth rates for revenue, gross profit, and capital expenditures based on history and our best estimate of future forecasts. We also estimated the fair values using a multiple of expected future cash flows such as those used by third party analysts. In 2015 , 2014 and 2013 the annual impairment review resulted in the determination that no impairment of goodwill had occurred. A summary of our goodwill accounts is as follows (in thousands): Wholesale Marketing and Terminalling Pipelines and Transportation Total Balance, December 31, 2012 $ 7,499 $ 2,955 $ 10,454 Acquisitions — 1,200 1,200 Balance, December 31, 2013 7,499 4,155 11,654 Balance, December 31, 2014 7,499 4,155 11,654 Acquisitions — 549 $ 549 Balance, December 31, 2015 $ 7,499 $ 4,704 $ 12,203

Other Intangibles (Notes)

Other Intangibles (Notes)	12 Months Ended
	Dec. 31, 2015
Other Intangible Assets Disclosure [Abstract]
Intangible Assets Disclosure [Text Block]	Other Intangible Assets Our identifiable intangible assets are are as follows (in thousands): Useful Accumulated As of December 31, 2015 Life Gross Amortization Net Intangible assets subject to amortization: Supply contracts (Gross) 11.5 $ 12,227 $ (10,012 ) $ 2,215 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 13,267 — 13,267 Total $ 25,494 $ (10,012 ) $ 15,482 Useful Accumulated As of December 31, 2014 Life Gross Amortization Net Intangible assets subject to amortization: Supply contracts (Gross) 11.5 $ 12,227 $ (8,949 ) $ 3,278 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 13,242 — 13,242 Total $ 25,469 $ (8,949 ) $ 16,520 Amortization of intangible assets was $1.1 million during each of the years ended December 31, 2015 , 2014 and 2013 and is included in depreciation and amortization on the accompanying consolidated statements of income and comprehensive income. Amortization expense is estimated to be $1.1 million per year for the years ended 2016 through 2017. We expect to incur $0.1 million of amortization expense in 2018, at which point our supply contracts will be fully amortized.

Long-Term Obligations and Short

Long-Term Obligations and Short-Term Note Payable (Notes)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Debt Disclosure [Text Block]	Long-Term Obligations Second Amended and Restated Credit Agreement We entered into a senior secured revolving credit agreement on November 7, 2012 with Fifth Third Bank, as administrative agent, and a syndicate of lenders. The agreement was amended and restated on July 9, 2013 (the "Amended and Restated Credit Agreement") and was most recently amended and restated on December 30, 2014 (the "Second Amended and Restated Credit Agreement"). Under the terms of the Second Amended and Restated Credit Agreement, the lender commitments were increased from $400.0 million to $700.0 million . The Second Amended and Restated Credit Agreement also contains an accordion feature whereby the Partnership can increase the size of the credit facility to an aggregate of $800.0 million , subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent. While the majority of the terms of the Second Amended and Restated Credit Agreement are substantially unchanged from the predecessor facility, among other things, changes were made to certain negative covenants, the financial covenants and the interest rate pricing grid. The Second Amended and Restated Credit Agreement contains an option for Canadian dollar denominated borrowings. Borrowings denominated in U.S. dollars bear interest at either a U.S. dollar prime rate , plus an applicable margin, or the London Interbank Offered Rate ("LIBOR"), plus an applicable margin, at the election of the borrowers. Borrowings denominated in Canadian dollars bear interest at either a Canadian dollar prime rate , plus an applicable margin, or the Canadian Dealer Offered Rate ("CDOR"), plus an applicable margin, at the election of the borrowers. The applicable margin in each case varies based upon the Partnership's most recent leverage ratio calculation delivered to the lenders, as called for and defined under the terms of the credit facility. At December 31, 2015 , the weighted average interest rate for our borrowings under the facility was approximately 2.8% . Additionally, the Second Amended and Restated Credit Agreement requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of December 31, 2015 , this fee was 0.40% per year. The obligations under the Second Amended and Restated Credit Agreement remain secured by first priority liens on substantially all of the Partnership's and its subsidiaries' tangible and intangible assets. Additionally, Delek Marketing continues to provide a limited guaranty of the Partnership's obligations under the Second Amended and Restated Credit Agreement. Delek Marketing's guaranty is (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek US in favor of Delek Marketing (the "Holdings Note") and (ii) secured by Delek Marketing's pledge of the Holdings Note to our lenders under the Second Amended and Restated Credit Agreement. As of December 31, 2015 , the principal amount of the Holdings Note was $102.0 million , plus unpaid interest accrued since the issuance date. The Second Amended and Restated Credit Agreement matures on December 30, 2019. As of December 31, 2015 , we had approximately $351.6 million outstanding borrowings under the Second Amended and Restated Credit Agreement. Additionally, we had in place letters of credit totaling $1.5 million , primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn under these letters of credit at December 31, 2015 . Amounts available under the Second Amended and Restated Credit Agreement as of December 31, 2015 were approximately $346.9 million . Principal maturities of the Partnership's existing third party debt instruments for the next five years and thereafter are as follows as of December 31, 2015 (in thousands): 2016 2017 2018 2019 2020 Thereafter Total Second Amended and Restated Credit Agreement $ — $ — $ — $ 351,600 $ — $ — $ 351,600

Equity (Notes)

Equity (Notes)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Equity We had 9,478,273 common limited partner units held by the public outstanding as of December 31, 2015 . Additionally, as of December 31, 2015 , Delek owned a 59.7% limited partner interest in us, consisting of 2,799,258 common limited partner units and 11,999,258 subordinated limited partner units as well as a 95.4% interest in our general partner, which owns the entire 2.0% general partner interest consisting of 495,445 general partner units. Affiliates who are also members of our general partner's management and board of directors own the remaining 4.6% interest in our general partner. The table below summarizes the changes in the number of units outstanding through December 31, 2015 (in units). There were no units outstanding prior to the Offering in November 2012. Common - Public Common - Delek Subordinated General Partner Total Units issued in the Offering in November 2012 9,200,000 2,799,258 11,999,258 489,766 24,488,282 Balance at December 31, 2012 9,200,000 2,799,258 11,999,258 489,766 24,488,282 GP units issued to maintain 2% interest — — — 3,127 3,127 Unit-based compensation awards (1) 153,240 — — — 153,240 Balance at December 31, 2013 9,353,240 2,799,258 11,999,258 492,893 24,644,649 GP units issued to maintain 2% interest — — — 1,304 1,304 Unit-based compensation awards (1) 63,949 — — — 63,949 Balance at December 31, 2014 9,417,189 2,799,258 11,999,258 494,197 24,709,902 GP units issued to maintain 2% interest — — — 1,248 1,248 Unit-based compensation awards (1) 61,084 — — — 61,084 Balance at December 31, 2015 9,478,273 2,799,258 11,999,258 495,445 24,772,234 (1) Unit-based compensation awards are presented net of 21,144 , 5,539 and 31,083 units withheld for taxes as of December 31, 2015 , 2014 and 2013 , respectively. Issuance of Additional Securities Our partnership agreement authorizes us to issue an unlimited number of additional partnership securities for the consideration and on the terms and conditions determined by our general partner without the approval of the unitholders. Costs associated with the issuance of securities are allocated to all unitholders' capital accounts based on their ownership interest at the time of issuance. Allocations of Net Income Our partnership agreement contains provisions for the allocation of net income and loss to the unitholders and our general partner. For purposes of maintaining partner capital accounts, the partnership agreement specifies that items of income and loss shall be allocated among the partners in accordance with their respective percentage interest. Normal allocations according to percentage interests are made after giving effect to priority income allocations in an amount equal to incentive cash distributions allocated 100% to our general partner. The following table presents the allocation of the general partner's interest in net income (in thousands, except percentage of ownership interest): Year Ended December 31, 2015 2014 2013 Net income attributable to partners $ 66,848 $ 71,997 $ 47,830 Less: General partner's IDRs (3,904 ) (945 ) — Net income available to partners $ 62,944 $ 71,052 $ 47,830 General partner's ownership interest 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income 1,259 1,421 957 General partner's IDRs 3,904 945 — Total general partner's interest in net income $ 5,163 $ 2,366 $ 957 Incentive Distribution Rights The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and our unitholders in any available cash from operating surplus that we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that (i) our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest, (ii) our general partner has not transferred its IDRs, and (iii) there are no arrearages on common units. Target Quarterly Distribution per Unit Marginal Percentage Interest in Distributions Target Amount Unitholders General Partner Minimum Quarterly Distribution $ 0.37500 98.0 % 2.0 % First Target Distribution above $ 0.37500 98.0 % 2.0 % up to $ 0.43125 Second Target Distribution above $ 0.43125 85.0 % 15.0 % up to $ 0.46875 Third Target Distribution above $ 0.46875 75.0 % 25.0 % up to $ 0.56250 Thereafter thereafter $ 0.56250 50.0 % 50.0 % Cash distributions Our partnership agreement sets forth the calculation to be used to determine the amount and priority of cash distributions that our common and subordinated unitholders and general partner will receive. Our distributions earned with respect to a given period are declared subsequent to quarter end. The table below summarizes the quarterly distributions related to our quarterly financial results: Quarter Ended Total Quarterly Distribution Per Limited Partner Unit Total Quarterly Distribution Per Limited Partner Unit, Annualized Total Cash Distribution, including IDRs (in thousands) Date of Distribution Unitholders Record Date December 31, 2013 $ 0.415 $ 1.66 $ 10,228 February 13, 2014 February 4, 2014 March 31, 2014 $ 0.425 $ 1.70 $ 10,474 May 14, 2014 May 6, 2014 June 30, 2014 $ 0.475 $ 1.90 $ 11,910 August 14, 2014 August 7, 2014 September 30, 2014 $ 0.490 $ 1.96 $ 12,394 November 14, 2014 November 6, 2014 December 31, 2014 $ 0.510 $ 2.04 $ 13,056 February 13, 2015 February 6, 2015 March 31, 2015 $ 0.530 $ 2.12 $ 13,702 May 14, 2015 May 4, 2015 June 30, 2015 $ 0.550 $ 2.20 $ 14,368 August 14, 2015 August 6, 2015 September 30, 2015 $ 0.570 $ 2.28 $ 15,136 November 13, 2015 November 6, 2015 December 31, 2015 $ 0.590 $ 2.36 $ 16,124 February 12, 2016 February 5, 2016 Following the February 12, 2016 payment of the cash distribution attributable to the fourth quarter of 2015 , and confirmation by the board of directors of our general partner based on the recommendation of the conflicts committee, on February 25, 2016 , the requirements under the partnership agreement for the conversion of all subordinated units into common units were satisfied and the subordination period ended. As a result, in the first quarter of 2016 , each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and will participate pro rata with the other common units in distributions of available cash. The allocation of total quarterly cash distributions made to general and limited partners for the years ended December 31, 2015 , 2014 and 2013 is set forth in the table below. Our distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below represents total cash distributions applicable to the period in which the distributions are earned (in thousands, except per unit amounts): Year Ended December 31, 2015 2014 2013 General partner's distributions: General partner's distributions $ 1,109 $ 938 $ 785 General partner's IDRs 3,904 945 — Total general partner's distributions 5,013 1,883 785 Limited partners' distributions: Common 27,439 23,152 19,292 Subordinated 26,878 22,799 19,199 Total limited partners' distributions 54,317 45,951 38,491 Total cash distributions $ 59,330 $ 47,834 $ 39,276 Cash distributions per limited partner unit $ 2.240 $ 1.900 $ 1.600

Equity Based Compensation (Note

Equity Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2015
Equity Based Compensation [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	Equity Based Compensation The Delek Logistics GP, LLC 2012 Long-Term Incentive Plan (the "LTIP") was adopted by the Delek Logistics GP, LLC Board of Directors in connection with the completion of the Offering in November 2012. The LTIP provides for officers, directors and employees of our general partner or its affiliates, and any consultants, affiliates of our general partner or other individuals who perform services for us. The LTIP consists of unit options, restricted units, phantom units, unit appreciation rights, distribution equivalent rights, other unit-based awards and unit awards. The LTIP limits the number of common units that may be delivered pursuant to awards under the plan to 612,207 units. The LTIP is administered by the Conflicts Committee of the Board of Directors of our general partner. We incurred approximately $0.4 million , $0.3 million , and $0.5 million of unit-based compensation expense related to the Partnership during the years ended December 31, 2015 , 2014 , and 2013 respectively. These amounts are included in general and administrative expenses in the accompanying consolidated statements of income and comprehensive income. The fair value of phantom unit awards under the LTIP is determined based on the closing price of our common limited partner units on the grant date. The estimated fair value of our phantom units is amortized over the vesting period using the straight line method. All awards made through June 9, 2015 vest over a five -year service period unless such awards are amended in accordance with the LTIP. Beginning June 10, 2015, all awards made to only non-employee directors vest over a three -year service period unless such awards are amended in accordance with the LTIP. The total fair value of phantom units vested was $1.9 million , $1.6 million and $4.2 million during the years ended December 31, 2015 , 2014 and 2013 , respectively. As of December 31, 2015 , there was $1.0 million of total unrecognized compensation cost related to non-vested equity-based compensation arrangements, which is expected to be recognized over a weighted-average period of 1.8 years. A summary of our unit award activity for the years ended December 31, 2015 , 2014 and 2013 , is set forth below: Number of Phantom Units Weighted-Average Grant Price Non-vested December 31, 2012 494,883 22.65 Granted 7,500 34.12 Vested (184,323 ) 22.68 Forfeited (43,108 ) 22.65 Non-vested December 31, 2013 274,952 22.94 Granted 10,000 35.46 Vested (69,488 ) 23.08 Non-vested December 31, 2014 215,464 $ 23.48 Granted 11,836 $ 39.73 Vested (82,228 ) $ 23.55 Non-vested December 31, 2015 145,072 $ 24.76

Equity Method Investments (Note

Equity Method Investments (Notes)	12 Months Ended
	Dec. 31, 2015
Equity Method Investments [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	Equity Method Investments In March 2015, the Partnership, through its indirect wholly owned subsidiary DKL Caddo, LLC ("DKL Caddo"), became a member of Caddo Pipeline LLC ("CP LLC") by entering into an amended and restated limited liability company agreement (the “Caddo LLC Agreement”) with Plains Pipeline, L.P., an affiliate of Plains All American Pipeline, L.P. ("Plains"). CP LLC was formed to plan, develop, construct, own, operate and maintain a pipeline system and ancillary assets originating near Longview, Texas and extending to Shreveport, Louisiana (the "Caddo Pipeline System"). Pursuant to the terms of the Caddo LLC Agreement, DKL Caddo and Plains each own a 50% membership interest in CP LLC. Pursuant to separate agreements, Plains will have primary responsibility for the construction of the Caddo Pipeline System and, upon its completion, Plains will also have primary responsibility for its day-to-day operations. In March 2015, the Partnership, through its indirect wholly owned subsidiary, DKL RIO, LLC ("DKL RIO"), became a member of Rangeland RIO Pipeline, LLC ("Rangeland RIO") by entering into an amended and restated limited liability company agreement (the "Rangeland LLC Agreement") with Rangeland Energy II, LLC ("Rangeland"). Rangeland RIO was formed to develop, construct, operate and maintain a crude oil pipeline extending from Loving County, Texas to Midland, Texas (the "RIO Pipeline"). Pursuant to the terms of the Rangeland LLC Agreement, DKL RIO owns 33% of Rangeland RIO, and Rangeland owns 67% . Rangeland will have primary responsibility for the construction of the RIO Pipeline and, upon its completion, Rangeland will also have primary responsibility for its day-to-day operations. The total projected investment in these two entities is approximately $96.0 million and is expected to be financed through a combination of cash from operations and borrowings under the Second Amended and Restated Credit Agreement. As of December 31, 2015 , we have invested $41.3 million in these joint ventures, which are accounted for using the equity method. We do not consolidate any part of the assets or liabilities of our equity investees. Our share of net income or loss will increase or decrease, as applicable, the carrying value of our investments in unconsolidated affiliates. With respect to CP LLC and Rangeland RIO, we determined that these entities do not represent variable interest entities and consolidation was not required. We have the ability to exercise influence over each of these joint ventures through our participation in the management committees, which make all significant decisions. However, since all significant decisions require the consent of the other investor(s) without regard to economic interest, we have determined that we have joint control and have applied the equity method of accounting. Our investment in these joint ventures is reflected in our pipelines and transportation segment. Summarized FInancial Information Combined summarized financial information for our equity investees is shown below: December 31, 2015 Current Assets $ 11,705 Noncurrent Assets $ 87,467 Current liabilities $ 4,797 Noncurrent liabilities $ — Year Ended December 31, 2015 Revenues $ — Gross profit $ — Net loss $ (1,967 )

Segment Data (Notes)

Segment Data (Notes)	12 Months Ended
	Dec. 31, 2015
Segment Data [Abstract]
Segment Data	Segment Data We aggregate our operating units into two reportable reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. • The assets and investments reported in the pipelines and transportation segment provide crude oil gathering, and crude oil, intermediate and finished products transportation and storage services to Delek's refining operations and independent third parties. • The wholesale marketing and terminalling segment provides marketing and terminalling services to Delek's refining operations and independent third parties. Our operating segments adhere to the accounting polices used for our consolidated financial statements, as described in Note 1 . Our operating segments are managed separately because each segment requires different industry knowledge, technology and marketing strategies. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on segment contribution margin. Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization. Our historical financial statements have been retrospectively adjusted as appropriate to reflect the results of operations attributable to the Logistics Assets, the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented. The results of the El Dorado Terminal and the Tyler Terminal are included in the wholesale marketing and terminalling segment. The results of the Logistics Assets, the El Dorado Tank Assets and the Tyler Tank Assets are included in the pipelines and transportation segment. The results of the El Dorado Terminal and the Tyler Terminal are included in the wholesale marketing and terminalling segment. The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in thousands): Year Ended December 31, 2015 2014 2013 Pipelines and Transportation Net Sales: Affiliate $ 102,551 $ 80,683 $ 51,878 Third-Party 28,828 10,665 8,359 Total Pipelines and Transportation 131,379 91,348 60,237 Operating costs and expenses: Cost of goods sold 19,607 4,294 764 Operating expenses (1) (2) 33,751 31,979 27,728 Segment contribution margin $ 78,021 $ 55,075 $ 31,745 Capital spending (excluding business combinations) (1) (2) $ 16,030 $ 5,804 $ 22,696 Wholesale Marketing and Terminalling Net Sales: Affiliate $ 50,013 $ 33,900 $ 26,295 Third-Party 408,277 716,005 820,896 Total Wholesale Marketing and Terminalling 458,290 749,905 847,191 Operating costs and expenses: Cost of goods sold 416,697 692,927 810,600 Operating expenses 11,172 7,486 8,175 Segment contribution margin $ 30,421 $ 49,492 $ 28,416 Capital spending (excluding business combinations) $ 6,397 $ 3,364 $ 3,041 Consolidated Net Sales: Affiliate $ 152,564 $ 114,583 $ 78,173 Third-Party 437,105 726,670 829,255 Total Consolidated 589,669 841,253 907,428 Operating costs and expenses: Cost of goods sold 436,304 697,221 811,364 Operating expenses (1) (2) 44,923 39,465 35,903 Contribution margin 108,442 104,567 60,161 General and administrative expenses 11,384 10,616 7,526 Depreciation and amortization 19,692 15,022 13,738 Loss on asset disposals 104 83 166 Operating income $ 77,262 $ 78,846 $ 38,731 Capital spending (excluding business combinations) (1) (2) $ 22,427 $ 9,168 $ 25,737 (1) Includes operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015 . (2) Adjusted to include operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015 . The following table summarizes the total assets for each segment as of December 31, 2015 and 2014 (in thousands). Year Ended December 31, 2015 2014 (1) Pipelines and Transportation 283,553 230,293 Wholesale Marketing and Terminalling 91,735 100,993 Total Assets $ 375,288 $ 331,286 (1) Adjusted to include the historical balances of the Logistics Assets Predecessor.

Fair Value Measurements (Notes)

Fair Value Measurements (Notes)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements	Fair Value Measurements The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments . We apply the provisions of ASC 820, which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to our interest rate and commodity derivatives that are measured at fair value on a recurring basis. The standard also requires that we assess the impact of nonperformance risk on our derivatives. Nonperformance risk is not considered material at this time. ASC 820 requires disclosures that categorize assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting our assumptions about pricing by market participants. Over the counter ("OTC") commodity swaps and interest rate swaps and caps are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, spot prices, interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2. The fair value hierarchy for our financial assets accounted for at fair value on a recurring basis at December 31, 2015 and 2014 was as follows: (in thousands): As of December 31, 2015 Level 1 Level 2 Level 3 Total Assets Interest rate derivatives $ — $ — $ — $ — OTC commodity swaps $ — $ 171 $ — $ 171 Total assets — 171 — 171 Liabilities OTC commodity swaps — (45 ) — (45 ) Net Assets $ — $ 126 $ — $ 126 As of December 31, 2014 Level 1 Level 2 Level 3 Total Assets Interest rate derivatives $ — $ 24 $ — $ 24 OTC commodity swaps — 456 — 456 Total assets — 480 — 480 Liabilities OTC commodity swaps — (61 ) — (61 ) Net assets $ — $ 419 $ — $ 419 The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. Derivative assets and liabilities with the same counterparty are not netted where the legal right of offset exists. This differs from the presentation in the financial statements, which reflects our policy under the guidance of ASC 815-10-45, wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty where the legal right of offset exists. Our policy under the guidance of ASC 815-10-45 is to net the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and offset these values against any cash collateral associated with these derivative positions. As of December 31, 2015 , $0.8 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2014 , no cash collateral was held by counterparty brokerage firms.

Derivative Instruments (Notes)

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments [Abstract]
Derivative Instruments	Derivative Instruments From time to time, we enter into forward fuel contracts to limit the exposure to price fluctuations for physical purchases of finished products in the normal course of business. We use derivatives to reduce normal operating and market risks with a primary objective in derivative instrument use being the reduction of the impact of market price volatility on our results of operations. Typically, we enter into forward fuel contracts with major financial institutions in which we fix the purchase price of finished grade fuel for a predetermined number of units with fulfillment terms of less than 90 days. From time to time, we may also enter into interest rate hedging agreements to limit floating interest rate exposure under the Second Amended and Restated Credit Agreement. Our initial credit facility required us to maintain interest rate hedging arrangements on at least 50% of the amount funded on November 7, 2012 under the credit facility, which was required to be in place for at least a three-year period beginning no later than March 7, 2013 . Accordingly, effective February 25, 2013 , we entered into interest rate hedges in the form of a LIBOR interest rate cap for a term of three years for a total notional amount of $45.0 million , thereby meeting the requirements in effect at that time. These requirements were eliminated in connection with the Amended and Restated Credit Agreement in July 2013, but the interest rate hedge remains in place in accordance with its terms. The following table presents the fair value of our derivative instruments, as of December 31, 2015 and 2014 . The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including any cash collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below may differ from the amounts presented in our consolidated balance sheets. During the years ended December 31, 2015 and 2014 , we did not elect hedge accounting treatment for these derivative positions. As a result, all changes in fair value are marked to market in the accompanying consolidated statements of income and comprehensive income. December 31, 2015 December 31, 2014 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives not designated as hedging instruments: Interest rate derivatives Other long term assets $ — $ — $ 24 $ — OTC commodity swaps (1) Other current assets 171 (45 ) 456 (61 ) Total gross value of derivatives $ 171 $ (45 ) $ 480 $ (61 ) Less: Counterparty netting and cash collateral (2) (706 ) (45 ) 61 (61 ) Total net fair value of derivatives $ 877 $ — $ 419 $ — (1) As of December 31, 2015 , we had open derivative contracts representing 171,000 barrels of refined petroleum products. As of December 31, 2014 , we had 142,000 open derivative contracts. (2) As of December 31, 2015 , $0.8 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2014 , no cash collateral was held by counterparty brokerage firms. Recognized gains (losses) associated with derivatives not designated as hedging instruments for the years ended December 31, 2015 and 2014 were as follows (in thousands): Year Ended December 31, Derivative Type Income Statement Location 2015 2014 2013 Interest rate derivatives Interest expense $ (24 ) $ (92 ) $ (106 ) OTC commodity swaps Cost of goods sold 441 3,083 (614 ) Total $ 417 $ 2,991 $ (720 )

Income Taxes (Notes)

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes For tax purposes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under our partnership agreement. The Partnership is not a taxable entity for federal income tax purposes. While most states do not impose an entity level tax on partnership income, the Partnership is subject to entity level tax in both Tennessee and Texas. The Partnership does not file a separate Texas income tax return. Our results of operations are included in Delek’s consolidated return. However, the provisions of ASC 740 have been followed as if we were a stand-alone entity. As a result, the Partnership must record deferred income taxes for the differences between book and tax bases of its assets and liabilities based on those states' enacted tax rates and laws that will be in effect when the differences are expected to reverse. The total non-current deferred tax assets and liabilities were $0.1 million and $(0.2) million as of December 31, 2015 and December 31, 2014 , respectively. The majority component of our non-current deferred tax asset (liability) as of December 31, 2015 and December 31, 2014 was depreciation and amortization. The difference between the actual income tax expense and the tax expense computed by applying the statutory federal income tax rate to income before income taxes is attributable to the following (in thousands): Year Ended December 31, 2015 2014 2013 State income taxes 171 492 794 Other items (366 ) (360 ) (37 ) Income tax (benefit) expense $ (195 ) $ 132 $ 757 Income tax (benefit) expense is as follows (in thousands): Year Ended December 31, 2015 2014 2013 Current $ (209 ) $ 241 $ 448 Deferred 14 (109 ) 309 Total $ (195 ) $ 132 $ 757 Delek files a consolidated Texas income tax return and current income tax payments for the Partnership are paid by Delek US. Therefore, any current income tax payable is included in accounts receivable/payable from related parties. As of December 31, 2015 and 2014 , income taxes (receivable) payable of $(0.2) million and $0.6 million , respectively, were included in accounts payable to related parties in the accompanying consolidated balance sheets. Taxes that are determined on a consolidated basis apply the “benefits for loss” allocation method; thus, tax attributes are realized when used in the combined tax return to the extent that they have been subject to a valuation allowance. We recognize accrued interest and penalties related to unrecognized tax benefits as an adjustment to the current provision for income taxes. There were no uncertain tax positions recorded as of December 31, 2015 , 2014 or 2013 and there were no interest or penalties recognized related to uncertain tax positions for the years ended December 31, 2015 , 2014 or 2013 . We have examined uncertain tax positions for any material changes in the next 12 months and none are expected.

Commitments and Contingencies (

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies [Abstract]
Commitments and Contingencies	Commitments and Contingencies Litigation In the ordinary conduct of our business, we are from time to time subject to lawsuits, investigations and claims, including environmental claims and employee-related matters. Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, including civil penalties or other enforcement actions, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our business, financial condition or results of operations. Environmental Health and Safety We are subject to extensive and periodically changing federal, state and local laws and regulations relating to the protection of the environment, health and safety. Among other things, these laws and regulations govern the emission of discharge of pollutants into or onto the land, air and water, the handling and disposal of solid and hazardous wastes, the remediation of contamination and the protection of workers and the public. Compliance with existing and anticipated environmental laws and regulations increases our overall cost of business, including our capital costs to develop, maintain, operate and upgrade equipment and facilities. Numerous permits or other authorizations are required under these laws for the operation of our terminals, pipelines, and related operations, and may be subject to revocation, modification and renewal. These laws and permits may become the basis for future claims and lawsuits involving environmental and safety matters, which could include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed of, or that relate to pre-existing conditions for which we have assumed or have assigned responsibility. We believe that our current operations are in substantial compliance with existing environmental, health and safety requirements. However, these laws and regulations are subject to changes by regulatory authorities, or to changes in the interpretation of such laws and regulations, by regulatory or judicial authorities, and continued and future compliance with such laws and regulations may require us to incur significant expenditures. Violation of environmental laws, regulations and permits can result in the imposition of significant administrative, civil and criminal penalties, injunctions limiting our operations, investigatory or remedial liabilities or construction bans or delays in the construction of additional facilities or equipment. Additionally, a release of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured, subject us to substantial expenses, including costs to respond to, contain and remediate a release, to comply with applicable laws and regulations and to resolve claims by third parties for personal injury, property damage, or natural resources damages. These impacts could directly and indirectly affect our business. We cannot currently determine the amounts of such future impacts. There have been and will continue to be ongoing discussions about environmental and safety matters between us and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures. Crude Oil Releases We have detected several crude oil releases involving our assets, including, but not limited to, the following releases: • In April 2015, a crude oil release of an estimated 130 barrels of crude oil was discovered from a gathering line in a remote area near Fouke, Arkansas (the "Fouke Release"); • In April 2014, a release of about 400 barrels of crude oil occurred from a gathering line near Haynesville, Louisiana (the "Haynesville Release"); • In October 2013, a release of less than 50 barrels of crude oil was discovered in a creek in a remote area near Macedonia in Columbia County, Arkansas (the "Macedonia Release"); • In March 2013, a a release of approximately 5,900 barrels of crude oil occurred from a pumping facility at our Magnolia Station located west of the El Dorado refinery (the "Magnolia Release"). Cleanup operations and site maintenance and remediation efforts on these releases have been substantially completed. However, we may incur additional expenses as a result of further scrutiny by regulatory authorities and continued compliance with laws and regulations to which our assets are subject. As we are unable to estimate these additional expenses, we have accrued $0.1 million , $0.2 million and $1.0 million for the Fouke Release, the Haynesville Release and the Magnolia Release, respectively, as of December 31, 2015 for such expenses. A nominal amount was accrued as of December 31, 2015 for the Macedonia Release. In June 2015, the United States Department of Justice (the "DOJ") notified the Partnership that it was evaluating an enforcement action on behalf of the EPA with regard to potential Clean Water Act violations arising from the March 2013 release at Magnolia Station. The DOJ visited the Magnolia Station in July 2015 and we continue to work with them and respond to their information requests. However, no specific claim for penalties or affirmative relief has been made at this time. During the year ended December 31, 2015 , we were reimbursed for the costs incurred in connection with the Fouke Release pursuant to the terms of the Third Restated Omnibus Agreement (as defined in Note 4). During the year ended December 31, 2014 , we incurred costs of $1.0 million related to the Haynesville Release and during the year ended December 31, 2013 , we incurred costs of $0.3 million for each of the Magnolia Release and the Macedonia Release. These costs are included in operating expenses in our consolidated statements of income and comprehensive income. We do not believe the total costs associated with these events, whether alone or in the aggregate, including any fines or penalties and net of partial insurance reimbursement, will have a material adverse effect upon our business, financial condition or results of operations, as Delek is required, pursuant to the terms of the Third Restated Omnibus Agreement (as defined in Note 4 ), to indemnify certain costs in excess of $0.3 million with respect to the releases at our Magnolia Station and near Macedonia, Arkansas and reimburse us for costs in excess of $1.0 million with respect to the release near Haynesville, Louisiana. Contracts and Agreements The majority of the petroleum products we sell in west Texas are purchased from Noble Petro, Inc. ("Noble Petro"). Under the terms of a supply contract (the "Abilene Contract") with Noble Petro, we have the right to purchase up to 20,350 bpd of petroleum products at the Abilene, Texas terminal, which we own, for sales and exchange with third parties at the Abilene and San Angelo terminals. We lease the Abilene and San Angelo, Texas terminals to Noble Petro, under a separate Terminal and Pipeline Lease and Operating Agreement, with a term that runs concurrent with that of the Abilene Contract. The Abilene Contract expires on December 31, 2017 and does not include any options for renewal. We also purchase spot barrels from various third parties and from Delek for sale to wholesale customers in west Texas. Letters of Credit As of December 31, 2015 , we had in place letters of credit totaling $1.5 million under the Second Amended and Restated Credit Agreement, primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn under these letters of credit at December 31, 2015 . Operating Leases We lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term, to renew the leases. None of these lease arrangements include fixed rental rate increases. Lease expense for all operating leases for the years ended December 31, 2015 , 2014 and 2013 totaled $1.1 million , $0.7 million and $0.7 million , respectively. The following is an estimate of our future minimum lease payments for operating leases having remaining noncancelable terms in excess of one year as of December 31, 2015 (in thousands): 2016 $ 4,991 2017 4,893 2018 2,184 2019 253 2020 189 Thereafter 9 Total future minimum rentals $ 12,519

Selected Quarterly Financial Da

Selected Quarterly Financial Data (Notes)	12 Months Ended
	Dec. 31, 2015
Selected Quarterly Financial Information [Abstract]
Quarterly Financial Information [Text Block]	Selected Quarterly Financial Data (Unaudited) Quarterly financial information for the years ended December 31, 2015 and 2014 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). For the Three Month Periods Ended March 31, 2015 (1) June 30, 2015 September 30, 2015 December 31, 2015 Net sales $ 143,512 $ 172,134 $ 165,092 $ 108,931 Operating income $ 16,414 $ 21,139 $ 21,847 $ 17,862 Net income $ 14,003 $ 18,311 $ 18,602 $ 15,295 Limited partners' interest in net income $ 13,753 $ 17,202 $ 17,219 $ 13,511 Net income per limited partner unit: Common (basic) $ 0.57 $ 0.71 $ 0.71 $ 0.56 Common (diluted) $ 0.56 $ 0.70 $ 0.70 $ 0.55 Subordinated - Delek (basic and diluted) $ 0.57 $ 0.71 $ 0.71 $ 0.56 (1) The information presented includes the results of operations of the Logistics Assets Predecessor. For the Three Month Periods Ended March 31, 2014 (1) June 30, 2014 (1) September 30, 2014 (1) December 31, 2014 (1) Net sales $ 203,527 $ 236,343 $ 228,036 $ 173,347 Operating income $ 15,682 $ 24,111 $ 17,242 $ 21,811 Net income $ 13,552 $ 21,488 $ 14,839 $ 20,179 Limited partners' interest in net income $ 14,379 $ 21,134 $ 14,487 $ 19,631 Net income per limited partner unit: Common (basic) $ 0.60 $ 0.88 $ 0.60 $ 0.81 Common (diluted) $ 0.59 $ 0.87 $ 0.59 $ 0.80 Subordinated - Delek (basic and diluted) $ 0.60 $ 0.87 $ 0.60 $ 0.81 (1) The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.

Subsequent Events (Notes)

Subsequent Events (Notes)	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events Distribution Declaration On January 25, 2016 , our general partner's board of directors declared a quarterly cash distribution of $0.590 per share, paid on February 12, 2016 , to unitholders of record on February 5, 2016 . Expirations of Subordination Period As a result of the cash distribution paid on February 12, 2016 and confirmation by the board of directors of our general partner based on the recommendation of the conflicts committee, the subordination period with respect to the Partnership’s 11,999,258 subordinated units expired on February 25, 2016 , and each of the outstanding subordinated units converted into common units. The converted units will participate pro rata with the other common units in distributions of available cash.

General General (Policies)

General General (Policies)	12 Months Ended
	Dec. 31, 2015
General [Abstract]
Combination of Entities under Common Control, Policy [Policy Text Block]	The Tyler Acquisition, the El Dorado Acquisition, the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition are hereinafter collectively referred to as the "Acquisitions from Delek." The Acquisitions from Delek were accounted for as transfers between entities under common control. As entities under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. Accordingly, the accompanying financial statements and related notes of the Partnership have been retrospectively adjusted to include (i) the historical results of the Tyler Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through July 26, 2013 (the "Tyler Predecessor"), (ii) the historical results of the El Dorado Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through February 10, 2014 (the "El Dorado Predecessor"), (iii) the historical results of the El Dorado Assets, as owned and operated by Delek, for all periods presented through March 31, 2015 (the "El Dorado Assets Predecessor") and (iv) the historical results of the Tyler Assets, as owned and operated by Delek, for all periods presented through March 31, 2015 (the "Tyler Assets Predecessor"). The El Dorado Assets Predecessor, together with the Tyler Assets Predecessor, are hereinafter collectively referred to as the "Logistics Assets Predecessor." We refer to the historical results of the Tyler Predecessor, the El Dorado Predecessor, the El Dorado Assets Predecessor and the Tyler Assets Predecessor collectively as our "Predecessors." See Note 3 for further information regarding the El Dorado Acquisition and the Tyler Acquisition.

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation Our consolidated financial statements include the accounts of the Partnership and its subsidiaries as well as our Predecessors. All intercompany accounts and transactions have been eliminated. The financial statements of our Predecessors have been prepared from the separate records maintained by Delek and may not necessarily be indicative of the conditions that would have existed or the results of operations if our Predecessors had been operated as an unaffiliated entity. Our Predecessors did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services. Transfers between entities under common control are accounted for as if the transfer occurred at the beginning of the period, and prior years are retrospectively adjusted to furnish comparative information. As an entity under common control with Delek, we record the assets that Delek has contributed to us on our balance sheet at Delek's historical basis instead of fair value.
Subsequent Events, Policy [Policy Text Block]	We have evaluated subsequent events through the filing of this Annual Report on Form 10-K. Any material subsequent events that occurred during this time have been properly recognized or disclosed in our financial statements. The preparation of financial statements in conformity with U.S. generally accepted accounting principles (“U.S. GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Reclassification, Policy [Policy Text Block]	Reclassifications Certain prior period amounts have been reclassified in order to conform to the current year presentation.
Segment Reporting, Policy [Policy Text Block]	Segment Reporting We are an energy business focused on crude oil, intermediate and refined products pipeline and storage activities and wholesale marketing, terminalling and offloading activities. Management reviews operating results in two reportable segments: (i) pipelines and transportation and (ii) wholesale marketing and terminalling. The pipelines and transportation segment provides crude oil gathering, transportation and storage services to Delek's refining operations and independent third parties. The wholesale marketing and terminalling segment provides marketing, wholesale marketing and terminalling services to Delek's refining operations and independent third parties. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each of its reportable segments based on the segment contribution margin. Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization. Segment reporting is more fully discussed in Note 15 .
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents We maintain cash and cash equivalents in accounts with large, U.S. financial institutions. All highly liquid investments purchased with an original maturity of three months or less are considered to be cash equivalents.
Trade and Other Accounts Receivable, Policy [Policy Text Block]	Accounts Receivable Accounts receivable primarily consists of trade receivables generated in the ordinary course of business. We perform on-going credit evaluations of our customers and generally do not require collateral on accounts receivable. All accounts receivable amounts are considered to be fully collectible. Accordingly, no allowance has been established as of December 31, 2015 and 2014 .
Inventory, Policy [Policy Text Block]	Inventory Inventory consists of refined products, which are stated at the lower of cost or market with cost determined on a first-in, first-out ("FIFO") basis.
Property, Plant and Equipment, Policy [Policy Text Block]	Property, Plant and Equipment Assets acquired in conjunction with acquisitions are recorded at estimated fair market value in accordance with the purchase method of accounting as prescribed in Financial Accounting Standards Board ("FASB") Statement of Financial Accounting Standards Codification ("ASC") 805, Business Combinations ("ASC 805"). Other acquisitions of property and equipment are carried at cost. Betterments, renewals and extraordinary repairs that extend the life of an asset are capitalized. Maintenance and repairs are charged to expense as incurred. Depreciation is computed using the straight-line method over management’s estimated useful lives of the related assets, except for automotive equipment, which is depreciated using a declining-balance method. The estimated useful lives are as follows: Years Building and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15
Goodwill and Intangible Assets, Intangible Assets, Policy [Policy Text Block]	Intangible Assets Intangible assets consist of long-term supply contracts and indefinite-lived rights of way. We amortize the definite-lived long-term supply contracts on a straight-line basis over the estimated useful life of 11.5 years. The amortization expense is included in depreciation and amortization in the accompanying consolidated financial statements.
Impairment or Disposal of Long-Lived Assets, Including Intangible Assets, Policy [Policy Text Block]	Property, Plant and Equipment and Intangibles Impairment Property, plant and equipment and definite life intangibles are evaluated for impairment whenever indicators of impairment exist. In accordance with ASC 360, Property, Plant and Equipment and ASC 350, Intangibles - Goodwill and Other, we evaluate the realizability of these long-lived assets as events occur that might indicate potential impairment. In doing so, we assess whether the carrying amount of the asset is unrecoverable by estimating the sum of the future cash flows expected to result from the asset, undiscounted and without interest charges. If the carrying amount is more than the recoverable amount, an impairment charge must be recognized based on the fair value of the asset.
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	Goodwill and Potential Impairment Goodwill in an acquisition represents the excess of the aggregate purchase price over the fair value of the identifiable net assets. Our goodwill is recorded at original fair value and is not amortized. Goodwill is subject to annual assessment to determine if an impairment of value has occurred and we perform this review annually in the fourth quarter. We could also be required to evaluate our goodwill if, prior to our annual assessment, we experience disruptions in our business, have unexpected significant declines in operating results, or sustain a permanent market capitalization decline. If an asset’s carrying amount exceeds its fair value, the impairment assessment leads to the testing of the implied fair value of the asset’s goodwill to its carrying amount. If the implied fair value is less than the carrying amount, a goodwill impairment charge is recorded. Our annual assessment of goodwill did not result in an impairment charge during the years ended December 31, 2015 , 2014 , or 2013 .
Equity Method Investments, Policy [Policy Text Block]	Equity Method Investments For equity investments that are not required to be consolidated under the variable or voting interest model, we evaluate the level of influence we are able to exercise over an entity’s operations to determine whether to use the equity method of accounting. Our judgment regarding the level of control over an equity method investment includes considering key factors such as our ownership interest, participation in policy-making and other significant decisions and material intercompany transactions. Amounts recognized for equity method investments are included in equity method investments in our combined consolidated balance sheet and adjusted for our shares of the net earnings and losses of the investee and cash distributions, which are separately stated in our combined consolidated statement of operations and our combined consolidated statement of cash flows. We evaluate our equity method investments for impairment whenever events or changes in circumstances indicate that the carrying amounts of such investments may be impaired. A loss is recorded in earnings in the current period if a decline in the value of an equity method investment is determined to be other than temporary.
Derivatives, Policy [Policy Text Block]	Derivatives We record all derivative financial instruments, including forward fuel contracts, at estimated fair value in accordance with the provisions of ASC 815, Derivatives and Hedging ("ASC 815"). Changes in the fair value of the derivative instruments are recognized in operations, unless we elect to apply the hedge accounting treatment permitted under the provisions of ASC 815 allowing such changes to be classified as other comprehensive income. We validate the fair value of all derivative financial instruments on a periodic basis, utilizing exchange pricing and/or price index developers such as Platts or Argus. During the years ended December 31, 2015 , 2014 , and 2013 , we did not elect to apply hedge accounting treatment to our derivative positions and, therefore, all changes in fair value are reflected in the statements of income and comprehensive income. Our policy under the guidance of ASC 815-10-45, Derivatives and Hedging—Other Presentation Matters ("ASC 815-10-45"), is to net the fair value amounts recognized for multiple derivative instruments executed with the same counterparty and offset these values against any cash collateral associated with these derivative positions. See Note 17 for further discussion.
Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value of Financial Instruments The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of our assets and liabilities that fall under the scope of ASC 825, Financial Instruments ("ASC 825"). We apply the provisions of ASC 820, Fair Value Measurements and Disclosure ("ASC 820"), in our presentation and disclosures regarding fair value, which pertain to certain financial assets and liabilities measured at fair value in the balance sheet on a recurring basis. ASC 820 defines fair value, establishes a framework for measuring fair value and expands disclosures about such measurements that are permitted or required under other accounting pronouncements. See Note 16 for further discussion. We apply the provisions of ASC 825 as it pertains to the fair value option. This standard permits the election to carry financial instruments and certain other items similar to financial instruments at fair value on the balance sheet, with all changes in fair value reported in earnings. By electing the fair value option in conjunction with a derivative, an entity can achieve an accounting result similar to a fair value hedge without having to comply with complex hedge accounting rules. As of December 31, 2015 or 2014 , we did not make the fair value election for any financial instruments not already carried at fair value in accordance with other standards.
Self Insurance Reserve [Policy Text Block]	Self-Insurance Reserves We have no employees. Rather, we are managed by the directors and officers of our general partner. However, Delek employees providing services to the Partnership are covered under Delek’s insurance programs. Delek has workers' compensation and liability insurance with varying retentions and deductibles with limits that management considers adequate.
Regulatory Environmental Costs, Policy [Policy Text Block]	Environmental Expenditures We have historically accrued environmental and clean-up related costs of a non-capital nature when it is both probable that a liability has been incurred and the amount can be reasonably estimated. Environmental liabilities represent the current estimated costs to investigate and remediate contamination at our properties. This estimate is based on internal and third-party assessments of the extent of the contamination, the selected remediation technology and review of applicable environmental regulations, typically considering estimated activities and costs for the next 15 years, unless a specific longer range estimate is practicable. Accruals for estimated costs from environmental remediation obligations generally are recognized no later than completion of the remedial feasibility study and include, but are not limited to, costs to perform remedial actions and costs of machinery and equipment that are dedicated to the remedial actions and that does not have an alternative use. Such accruals are adjusted as further information develops or circumstances change. We discount environmental liabilities to their present value if payments are fixed and determinable. Expenditures for equipment necessary for environmental issues relating to ongoing operations are capitalized. Estimated recoveries of costs from other parties are recorded on an undiscounted basis as assets when their realization is deemed probable.
Asset Retirement Obligations, Policy [Policy Text Block]	Asset Retirement Obligations We recognize liabilities which represent the fair value of a legal obligation to perform asset retirement activities, including those that are conditional on a future event, when the amount can be reasonably estimated. These obligations are related to the required cleanout of our pipelines and terminal tanks, and removal of certain above-grade portions of our pipelines situated on right-of-way property. In order to determine fair value, management must make certain estimates and assumptions including, among other things, projected cash flows, a credit-adjusted risk-free rate and an assessment of market conditions that could significantly impact the estimated fair value of the asset retirement obligation.
Sales Use and Excise Taxes, Policy [Policy Text Block]	Revenue Recognition Revenues for products sold are recorded at the point of sale upon delivery of product, which is the point at which title to the product is transferred, and when payment has either been received or collection is reasonably assured. Service revenues are recognized as crude oil, intermediate and refined products are shipped through, delivered by or stored in our pipelines, trucks, terminals and storage facility assets, as applicable. We do not recognize product sales revenues for these services, as title on the product never passes to us. All service revenues are based on regulated tariff rates or contractual rates.
Cost of Sales, Policy [Policy Text Block]	Cost of Goods Sold and Operating Expenses Cost of goods sold includes all costs of refined products, additives and related transportation. It also includes costs associated with the operation of our trucking assets. We do not recognize product cost of sales related to our shipping, delivering and storage services, as title to the product never passes to us. Operating expenses include the costs associated with the operation of owned terminals and other logistics assets, terminalling expense at third-party locations and pipeline maintenance costs.
Revenue Recognition Accounting Policy, Gross and Net Revenue Disclosure [Policy Text Block]	Sales, Use and Excise Taxes Our policy is to exclude sales, use and excise taxes from revenue when we are an agent of the taxing authority, in accordance with ASC 605-45, Revenue Recognition—Principal Agent Considerations .
Debt, Policy [Policy Text Block]	Deferred Financing Costs Deferred financing costs are included in other non-current assets in the accompanying consolidated balance sheets and represent expenses related to issuing and amending our revolving credit facility. These amounts are amortized ratably over the remaining term of our revolving credit facility and are included in interest expense in the accompanying consolidated statements of income and comprehensive income.
Lease, Policy [Policy Text Block]	Operating Leases We lease certain equipment and have surface leases under various operating lease arrangements, most of which provide the option, after the initial lease term, to renew the leases. None of these lease arrangements include fixed rental rate increases.
Income Tax, Policy [Policy Text Block]	Income Taxes We are not a taxable entity for federal income tax purposes or the income taxes of those states that follow the federal income tax treatment of partnerships. Instead, for purposes of these income taxes, each partner of the Partnership is required to take into account its share of income, gain, loss and deduction in computing its federal and state income tax liabilities, regardless of whether cash distributions are made to such partner by the Partnership. The taxable income reportable to each partner takes into account differences between the tax basis and fair market value of our assets, the acquisition price of such partner's units and the taxable income allocation requirements under our partnership agreement. We are subject to income taxes in certain states that do not follow the federal tax treatment of Partnerships. These income taxes are accounted for under the provisions of ASC 740, Income Taxes (ASC 740). This statement generally requires DKL to record deferred income taxes for the differences between the book and tax bases of its assets and liabilities, which are measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. Deferred income tax expense or benefit represents the net change during the year in our deferred income tax assets and liabilities, exclusive of the amounts held in other comprehensive income. U.S. GAAP requires management to evaluate uncertain tax positions taken by the Partnership. The financial statement effects of a tax position are recognized when the position is more likely than not, based on the technical merits, to be sustained upon examination by the Internal Revenue Service. Management has analyzed the tax positions taken by the Partnership, and has concluded that there are no uncertain positions taken or expected to be taken. The Partnership is subject to routine audits by taxing jurisdictions; however, there are currently no audits for any tax periods in progress.
Equity based Compensation Policy [Policy Text Block]	Equity Based Compensation Our general partner provides equity-based compensation to officers, directors and employees of our general partner or its affiliates, and certain consultants, affiliates of our general partner or other individuals who perform services for us, which includes unit options, restricted units, phantom units, unit appreciation rights, distribution equivalent rights, other unit-based awards and unit awards. Phantom units are measured based on the fair market value of the underlying stock on the date of grant. The fair value of our phantom units is determined based on the closing price of our common units on the grant date. The estimated fair value of our phantom units is amortized over the vesting period using the straight line method. All awards made through June 9, 2015 vest over a five-year service period unless such awards are amended in accordance with the LTIP. Beginning June 10, 2015, all awards made to only non-employee directors vest over a three-year service period unless such awards are amended in accordance with the LTIP. It is our practice to issue new units when phantom units vest.
Net income per unit, Policy [Policy Text Block]	Net Income per Limited Partner Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and incentive distribution rights ("IDRs"). The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. At present, the only potentially dilutive units outstanding consist of unvested phantom units. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding. We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and IDRs. The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement, which are declared and paid following the close of each quarter.
Comprehensive Income, Policy [Policy Text Block]	Comprehensive Income Comprehensive income for the years ended December 31, 2015 , 2014 , and 2013 was equivalent to net income.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements In November 2015, the FASB issued guidance that requires deferred income tax liabilities and assets to be classified as noncurrent in a classified balance sheet, rather than being classified as current or noncurrent based on the classification of the related asset or liability for financial reporting, as previously required by the guidance. This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years and can be early adopted for any interim or annual financial statements that have not yet been issued. We prospectively adopted this guidance in the fourth quarter of 2015 and all deferred income tax liabilities and assets are now classified as noncurrent in our consolidated balance sheet as of December 31, 2015 . The adoption did not have a material impact on our business, financial position or results of operations. In September 2015, the FASB issued guidance that eliminates the requirement for an acquirer in a business combination to account for measurement-period adjustments retrospectively. Instead, acquirers must recognize measurement-period adjustments during the period in which they determine the amounts, including the effect on earnings of any amounts they would have recorded in previous periods if the accounting had been completed at the acquisition date. This guidance is effective for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years and can be early adopted for any interim or annual financial statements that have not yet been issued. We have prospectively adopted this guidance as of the fourth quarter of 2015 and the adoption did not have a material impact on our business, financial position or results of operations. In July 2015, the FASB issued guidance requiring entities to measure FIFO or average cost inventory at the lower of cost and net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. This guidance does not change the measurement of inventory measured using last-in, first-out or the retail inventory method. This guidance is effective for fiscal years beginning after December 15, 2016, and interim periods within those fiscal years and can be early adopted at the beginning of any interim or annual period for which financial statements have not yet been issued. We expect to adopt this guidance on or before the effective date, and we do not anticipate that the adoption will have a material impact on our business, financial position or results of operations. In April 2015, the FASB issued guidance which requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. Prior to the issuance of this guidance, debt issuance costs were required to be presented in the balance sheet as an asset. In August 2015, the FASB issued further clarification regarding an SEC staff announcement related to this guidance which permits entities to defer and present debt issuance costs associated with line-of-credit arrangements as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. Upon adoption, the guidance requires prior period financial statements to be retrospectively adjusted. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, with early adoption permitted. We adopted this guidance on December 31, 2015 and this adoption did not have a material impact on our business, financial position or results of operations. In April 2015, the FASB issued guidance regarding the effects on historical earnings per unit of master limited partnership dropdown transactions. This ASU specifies that for purposes of calculating historical earnings per unit under the two-class method, the earnings of a transferred business before the date of a dropdown transaction should be allocated entirely to the general partner and, therefore, the previously reported earnings per unit of the limited partners would not change as a result of the dropdown transaction. This guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015, and shall be applied retrospectively to each period presented. We expect to adopt this guidance as of the effective date and we do not anticipate that the adoption will have a material impact on our business, financial position or results of operations. In May 2014, the FASB issued guidance regarding “Revenue from Contracts with Customers,” to clarify the principles for recognizing revenue. The core principle of the new guidance is that an entity 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 guidance also requires improved interim and annual disclosures that enable the users of financial statements to better understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The new guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period, and can be adopted either retrospectively to each prior reporting period presented using a practical expedient as allowed by the new guidance or retrospectively with a cumulative effect adjustment to retained earnings as of the date of initial application. Early adoption is not permitted. We are currently evaluating the impact that adopting this new standard will have on our business, financial position or

Net Income Per Unit Net Income

Net Income Per Unit Net Income per Unit (Policies)	12 Months Ended
	Dec. 31, 2015
Net Income Per Unit [Abstract]
Net income per unit, Policy [Policy Text Block]	Net Income per Limited Partner Unit We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and incentive distribution rights ("IDRs"). The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement. Diluted net income per unit applicable to common limited partners includes the effects of potentially dilutive units on our common units. At present, the only potentially dilutive units outstanding consist of unvested phantom units. Basic and diluted net income per unit applicable to subordinated limited partners are the same because there are no potentially dilutive subordinated units outstanding. We use the two-class method when calculating the net income per unit applicable to limited partners because we have more than one participating class of securities. Our participating securities consist of common units, subordinated units, general partner units and IDRs. The two-class method is based on the weighted-average number of common units outstanding during the period. Basic net income per unit applicable to limited partners (including subordinated unitholders) is computed by dividing limited partners’ interest in net income, after deducting our general partner’s 2% interest and IDRs by the weighted-average number of outstanding common and subordinated units. Our net income is allocated to our general partner and limited partners in accordance with their respective partnership percentages after giving effect to priority income allocations for IDRs to our general partner, which is the holder of the IDRs pursuant to our partnership agreement, which are declared and paid following the close of each quarter.

Equity Equity (Policies)

Equity Equity (Policies)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Allocation of Net Income [Policy Text Block]	Our partnership agreement contains provisions for the allocation of net income and loss to the unitholders and our general partner. For purposes of maintaining partner capital accounts, the partnership agreement specifies that items of income and loss shall be allocated among the partners in accordance with their respective percentage interest. Normal allocations according to percentage interests are made after giving effect to priority income allocations in an amount equal to incentive cash distributions allocated 100% to our general partner.

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurement, Policy [Policy Text Block]	ASC 820 requires disclosures that categorize assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting our assumptions about pricing by market participants. Over the counter ("OTC") commodity swaps and interest rate swaps and caps are generally valued using industry-standard models that consider various assumptions, including quoted forward prices, spot prices, interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2.

Accounting Policies (Tables)

Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Property, Plant and Equipment [Table Text Block]	Depreciation is computed using the straight-line method over management’s estimated useful lives of the related assets, except for automotive equipment, which is depreciated using a declining-balance method. The estimated useful lives are as follows: Years Building and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 Property, plant and equipment, at cost, consist of the following (in thousands): December 31, 2015 2014 Land and land improvements $ 4,253 $ 2,953 Building and building improvements 1,886 1,169 Pipelines, tanks and terminals 299,101 268,339 Asset retirement obligation assets 2,073 2,073 Other equipment 4,270 3,764 Construction in process 14,064 29,790 325,647 308,088 Less: accumulated depreciation (71,799 ) (53,309 ) $ 253,848 $ 254,779 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2015 and 2014 are as follows (in thousands): As of and For the Year Ended December 31, 2015 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 266,169 $ 59,478 $ 325,647 Less: Accumulated depreciation (50,542 ) (21,257 ) (71,799 ) Property, plant and equipment, net $ 215,627 $ 38,221 $ 253,848 Depreciation expense $ 15,011 $ 3,618 $ 18,629 As of and For the Year Ended December 31, 2014 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 242,490 $ 65,598 $ 308,088 Less: Accumulated depreciation (36,776 ) (16,533 ) (53,309 ) Property, plant and equipment, net $ 205,714 $ 49,065 $ 254,779 Depreciation expense $ 10,712 $ 3,247 $ 13,959
Schedule of Change in Asset Retirement Obligation [Table Text Block]	The reconciliation of the beginning and ending carrying amounts of asset retirement obligations as of December 31, 2015 and 2014 is as follows (in thousands): December 31, 2015 2014 Beginning balance $ 3,319 $ 3,087 Liabilities settled (64 ) — Accretion expense 251 232 Ending balance $ 3,506 $ 3,319

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2015
Business Acquisition [Line Items]
Business Combination, Financial Information [Table Text Block]	Consolidated Balance Sheet as of December 31, 2014 Delek Logistics Partners, LP El Dorado Assets Predecessor Tyler Assets Predecessor December 31, 2014 (In thousands) ASSETS Current Assets: Cash and cash equivalents $ 1,861 $ — $ — $ 1,861 Accounts receivable 27,986 — — 27,986 Inventory 10,316 — — 10,316 Deferred tax assets 28 — — 28 Other current assets 768 — — 768 Total current assets 40,959 — — 40,959 Property, plant and equipment: Property, plant and equipment 288,045 8,267 11,776 308,088 Less: accumulated depreciation (52,992 ) (317 ) — (53,309 ) Property, plant and equipment, net 235,053 7,950 11,776 254,779 Goodwill 11,654 — — 11,654 Intangible assets, net 16,520 — — 16,520 Other non-current assets 7,374 — — 7,374 Total assets $ 311,560 $ 7,950 $ 11,776 $ 331,286 LIABILITIES AND EQUITY Current liabilities: Accounts payable $ 17,929 $ — $ — $ 17,929 Accounts payable to related parties 628 — — 628 Excise and other taxes payable 5,443 — — 5,443 Tank inspection liabilities 2,829 — — 2,829 Pipeline release liabilities 1,899 — — 1,899 Accrued expenses and other current liabilities 1,588 — 1,588 Total current liabilities 30,316 — — 30,316 Non-current liabilities: Revolving credit facility 251,750 — — 251,750 Asset retirement obligations 3,319 — — 3,319 Deferred tax liabilities 231 — — 231 Other non-current liabilities 5,889 — — 5,889 Total non-current liabilities 261,189 — — 261,189 Equity: Predecessors division equity — 7,950 11,776 19,726 Common unitholders - public (9,417,189 units issued and outstanding) 194,737 — — 194,737 Common unitholders - Delek (2,799,258 units issued and outstanding) (241,112 ) — — (241,112 ) Subordinated unitholders - Delek (11,999,258 units issued and outstanding) 73,515 — — 73,515 General Partner unitholders - Delek (494,197 units issued and outstanding) (7,085 ) — — (7,085 ) Total equity 20,055 7,950 11,776 39,781 Total liabilities and equity $ 311,560 $ 7,950 $ 11,776 $ 331,286 Consolidated Statements of Income Delek Logistics Partners, LP El Dorado Assets Predecessor Tyler Assets Year Ended December 31, 2015 (In thousands) Net Sales $ 589,669 $ — $ — $ 589,669 Operating costs and expenses: Cost of goods sold 436,304 — — 436,304 Operating expenses 44,756 167 — 44,923 General and administrative expenses 11,384 — — 11,384 Depreciation and amortization 19,222 372 98 19,692 Loss on asset disposals 104 — — 104 Total operating costs and expenses 511,770 539 98 512,407 Operating income (loss) 77,899 (539 ) (98 ) 77,262 Interest expense, net 10,658 — — 10,658 Loss on equity method investments 588 — — 588 Total non-operating expenses 11,246 — — 11,246 Income (loss) before income tax benefit 66,653 (539 ) (98 ) 66,016 Income tax benefit (195 ) — — (195 ) Net income (loss) 66,848 (539 ) (98 ) 66,211 Less: loss attributable to Predecessors — (539 ) (98 ) (637 ) Net income attributable to partners $ 66,848 $ — $ — $ 66,848 Delek Logistics Partners, LP El Dorado Assets Predecessor Year Ended December 31, 2014 (1) (In thousands) Net Sales $ 841,253 $ — $ 841,253 Operating costs and expenses: Cost of goods sold 697,221 — 697,221 Operating expenses 38,003 679 39,465 General and administrative expenses 10,570 — 10,616 Depreciation and amortization 14,591 317 15,022 Loss on asset disposals 83 — 83 Total operating costs and expenses 760,468 996 762,407 Operating income (loss) 80,785 (996 ) 78,846 Interest expense, net 8,656 — 8,656 Income (loss) before income tax expense 72,129 (996 ) 70,190 Income tax expense 132 — 132 Net income (loss) 71,997 (996 ) 70,058 Less: loss attributable to Predecessors — (996 ) (1,939 ) Net income attributable to partners $ 71,997 $ — $ 71,997 Delek Logistics Partners, LP El Dorado Assets Predecessor Year Ended December 31, 2013 (1) (In thousands) Net Sales $ 907,428 $ — $ 907,428 Operating costs and expenses: Cost of goods sold 811,364 — 811,364 Operating expenses 35,640 263 35,903 General and administrative expenses 7,526 — 7,526 Depreciation and amortization 13,738 — 13,738 Loss on asset disposals 166 — 166 Total operating costs and expenses 868,434 263 868,697 Operating income (loss) 38,994 (263 ) 38,731 Interest expense, net 4,570 — 4,570 Income (loss) before income tax expense 34,424 (263 ) 34,161 Income tax expense 757 — 757 Net income (loss) 33,667 (263 ) 33,404 Less: loss attributable to Predecessors (14,163 ) (263 ) (14,426 ) Net income attributable to partners $ 47,830 $ — $ 47,830 (1) There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013 , as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]	The following table summarizes the allocation of the aggregate purchase price for each of the third party acquisitions described above (in thousands): FTT Assets (1) Greenville-Mount Pleasant Assets (2) North Little Rock Terminal Hopewell Property, plant and equipment $ 10,790 $ 4,829 $ 4,990 $ 3,538 Intangible assets — 5,171 10 984 Goodwill (3) 549 — — 1,200 Inventory — 1,125 — — Accounts Receivable 1,767 — — — Accounts Payable (1,181 ) — — — Total $ 11,925 $ 11,125 $ 5,000 $ 5,722 (1) During the fourth quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed in connection with working capital adjustments and an additional $0.4 million of consideration paid for additional assets. (2) During the third quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed. (3) All goodwill is expected to be deductible for tax purposes.
Business Acquisition, Pro Forma Information [Table Text Block]	Third Parties Below are the unaudited pro forma consolidated results of operations of the Partnership for the years ended December 31, 2014 and 2013 , as if our 2014 acquisitions had occurred on January 1, 2013 (in thousands): Year Ended December 31, 2014 Year Ended December 31, 2013 As Reported Pro Forma As Reported Pro Forma FTT Assets: Net Sales $ 841,253 $ 854,842 $ 907,428 $ 921,017 Net income $ 70,058 $ 70,824 $ 33,404 $ 34,170 Greenville-Mount Pleasant Assets: Net Sales $ 841,253 $ 841,943 $ 907,428 $ 908,118 Net income $ 70,058 $ 69,621 $ 33,404 $ 32,967 Below are the unaudited pro forma consolidated results of operations of the Partnership for the year ended December 31, 2013 , as if our 2013 acquisitions had occurred on January 1, 2012 (in thousands): Year Ended December 31, 2013 As Reported Pro Forma North Little Rock Terminal: Net Sales $ 907,428 $ 908,867 Net income $ 33,404 $ 34,695 Hopewell: Net Sales $ 907,428 $ 908,382 Net income $ 33,404 $ 33,718 The following amounts associated with the El Dorado Assets and the Tyler Assets subsequent to March 31, 2015 , are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands): Year Ended December 31, 2015 El Dorado Assets Total operating revenues $ 4,449 Net income attributable to the Partnership $ 3,277 Costs associated with the acquisition $ 235 Tyler Assets Total operating revenues $ 1,620 Net income attributable to the Partnership $ 1,035 Costs associated with the acquisition $ 240

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
Related Party Transaction [Line Items]
Commercial Agreements [Table Text Block]	Asset/Operation Initiation Date Initial/Maximum Term (years) (1) Service Minimum Throughput Commitment (bpd) Fee (/bbl) Lion Pipeline System and SALA Gathering System: Crude Oil Pipelines (non-gathered) November 2012 5 / 15 Crude oil and refined products transportation 46,000 (2) $ 0 .97 (3) Refined Products Pipelines November 2012 5 / 15 40,000 $ 0.11 SALA Gathering System November 2012 5 / 15 Crude oil gathering 14,000 $ 2.56 (3) East Texas Crude Logistics System: Crude Oil Pipelines November 2012 5 / 15 Crude oil transportation and storage 35,000 $ 0.45 (4) Storage November 2012 5 / 15 N/A $ 284,090/month East Texas Marketing November 2012 10 (5) Marketing products for Tyler Refinery 50,000 $ 0.621/bbl (5) Big Sandy Terminal: (6) Refined Products Transportation November 2012 5 / 15 Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery 5,000 $ 0.57 Terminalling November 2012 5 / 15 5,000 $ 0.57 Storage November 2012 5 / 15 N/A $ 56,768/month Tyler Throughput and Tankage: Refined Products Throughput July 2013 8 / 16 Dedicated Terminalling and storage 50,000 $ 0.35 Storage July 2013 8 / 16 N/A $ 829,902/month Memphis Pipeline October 2013 5 Refined Products Transportation 10,959 $ 1.38/bbl El Dorado Throughput and Tankage: Refined Products Throughput February 2014 8 / 16 Dedicated terminalling and storage 11,000 $ 0.50/bbl Storage February 2014 8 / 16 N/A $1,309,085/month El Dorado Assets Throughput: Light Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (7) $ 1.00 Heavy Crude Throughput March 2015 9/15 Dedicated Offloading Services N/A (7) $ 2.25 (1) Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof. (2) Excludes volumes gathered on the SALA Gathering System. (3) Volumes gathered on the SALA Gathering System will not be subject to an additional fee for transportation on our Lion Pipeline System to the El Dorado Refinery. (4) For any volumes in excess of 50,000 bpd, the throughput fee will be $0.682 /bbl. (5) Following the primary term, the marketing agreement automatically renews for successive one-year terms unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. An additional fee of 50% of the margin on products sold is also paid pursuant to the agreement. The fee shall not be less than $175,000 nor greater than $500,000 per quarter. (6) On July 19, 2013, we acquired the Hopewell Pipeline in order to effectively connect it with the Big Sandy Pipeline and thereby return the Big Sandy Terminal to operation. In connection with the acquisition, on July 25, 2013, we and Delek entered into the Amended and Restated Services Agreement (Big Sandy Terminal and Pipeline), which amended and restated the terminalling services agreement for the Big Sandy Terminal originally entered into in connection with the Offering. (7) The throughput agreement provides for a minimum throughput fee of $1.5 million per quarter for throughput of a combination of light and heavy crude.
Schedule of Related Party Transactions [Table Text Block]	A summary of revenue and expense transactions with Delek and its affiliates, including expenses directly charged and allocated to our Predecessors, are as follows (in thousands): Year Ended December 31, 2015 2014 2013 Revenues $ 152,564 $ 114,583 $ 78,173 Cost of Goods Sold $ 105,461 $ 56,045 $ 80,129 Operating and maintenance expenses (1) $ 31,636 $ 20,889 $ 16,331 General and administrative expenses (2) $ 6,356 $ 5,799 $ 4,010 (1) Operating and maintenance expenses include costs allocated to our Predecessors for operating support provided by Delek, including certain labor related costs, property and liability insurance costs and certain other operating expenses. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $1.4 million for the year ended December 31, 2013 . With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were $0.4 million and $1.4 million for the years ended December 31, 2014 and 2013 , respectively. With respect to the Logistics Assets, the costs that were allocated to us by Delek were $0.2 million , $0.7 million , and $0.3 million for the years ended December 31, 2015 , 2014 and 2013 , respectively. (2) General and administrative expenses include costs allocated to our Predecessors for general and administrative support provided by Delek, including services such as corporate management, risk management, accounting and human resources. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $0.5 million for the year ended December 31, 2013 . With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were $0.1 million and $0.7 million for the years ended December 31, 2014 and 2013 , respectively. No costs were allocated to the Logistics Assets Predecessor by Delek for the years ended December 31, 2015 , 2014 and 2013 .

Net Income Per Unit (Tables)

Net Income Per Unit (Tables)	12 Months Ended
	Dec. 31, 2015
Net Income Per Unit [Abstract]
Net Income Per Unit [Table Text Block]	The calculation of net income per unit is as follows (dollars in thousands, except per unit amounts): Year Ended December 31, 2015 2014 2013 Net income attributable to partners $ 66,848 $ 71,997 $ 47,830 Less: General partner's distribution (including IDRs) (1) 5,013 1,883 785 Less: Limited partners' distribution 27,439 23,152 19,292 Less: Subordinated partner's distribution 26,878 22,799 19,199 Earnings in excess of distributions $ 7,518 $ 24,163 $ 8,554 General partner's earnings: Distributions (including IDRs) (1) $ 5,013 $ 1,883 $ 785 Allocation of earnings in excess of distributions 150 483 172 Total general partner's earnings $ 5,163 $ 2,366 $ 957 Limited partners' earnings on common units: Distributions $ 27,439 $ 23,152 $ 19,292 Allocation of earnings in excess of distributions 3,721 11,933 4,198 Total limited partners' earnings on common units $ 31,160 $ 35,085 $ 23,490 Limited partners' earnings on subordinated units: Distributions $ 26,878 $ 22,799 $ 19,199 Allocation of earnings in excess of distributions 3,647 11,747 4,184 Total limited partner's earnings on subordinated units $ 30,525 $ 34,546 $ 23,383 Weighted average limited partner units outstanding: Common units - (basic) 12,237,154 12,171,548 12,025,249 Common units - (diluted) 12,356,914 12,302,629 12,148,774 Subordinated units - Delek (basic and diluted) 11,999,258 11,999,258 11,999,258 Net income per limited partner unit: Common - (basic) $ 2.55 $ 2.88 $ 1.95 Common - (diluted) $ 2.52 $ 2.85 $ 1.93 Subordinated - (basic and diluted) $ 2.54 $ 2.88 $ 1.95 (1) General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs.

Property, Plant and Equipment37

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment [Table Text Block]	Depreciation is computed using the straight-line method over management’s estimated useful lives of the related assets, except for automotive equipment, which is depreciated using a declining-balance method. The estimated useful lives are as follows: Years Building and building improvements 15-40 Pipelines, tanks and terminals 15-40 Asset retirement obligation assets 15-50 Other equipment 3-15 Property, plant and equipment, at cost, consist of the following (in thousands): December 31, 2015 2014 Land and land improvements $ 4,253 $ 2,953 Building and building improvements 1,886 1,169 Pipelines, tanks and terminals 299,101 268,339 Asset retirement obligation assets 2,073 2,073 Other equipment 4,270 3,764 Construction in process 14,064 29,790 325,647 308,088 Less: accumulated depreciation (71,799 ) (53,309 ) $ 253,848 $ 254,779 Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2015 and 2014 are as follows (in thousands): As of and For the Year Ended December 31, 2015 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 266,169 $ 59,478 $ 325,647 Less: Accumulated depreciation (50,542 ) (21,257 ) (71,799 ) Property, plant and equipment, net $ 215,627 $ 38,221 $ 253,848 Depreciation expense $ 15,011 $ 3,618 $ 18,629 As of and For the Year Ended December 31, 2014 Pipelines and Transportation Wholesale Marketing and Terminalling Consolidated Property, plant and equipment $ 242,490 $ 65,598 $ 308,088 Less: Accumulated depreciation (36,776 ) (16,533 ) (53,309 ) Property, plant and equipment, net $ 205,714 $ 49,065 $ 254,779 Depreciation expense $ 10,712 $ 3,247 $ 13,959

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2015
Goodwill [Abstract]
Schedule of Goodwill [Table Text Block]	A summary of our goodwill accounts is as follows (in thousands): Wholesale Marketing and Terminalling Pipelines and Transportation Total Balance, December 31, 2012 $ 7,499 $ 2,955 $ 10,454 Acquisitions — 1,200 1,200 Balance, December 31, 2013 7,499 4,155 11,654 Balance, December 31, 2014 7,499 4,155 11,654 Acquisitions — 549 $ 549 Balance, December 31, 2015 $ 7,499 $ 4,704 $ 12,203

Other Intangibles (Tables)

Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2015
Other Intangible Assets Disclosure [Abstract]
Schedule of Intangible Assets [Table Text Block]	Useful Accumulated As of December 31, 2015 Life Gross Amortization Net Intangible assets subject to amortization: Supply contracts (Gross) 11.5 $ 12,227 $ (10,012 ) $ 2,215 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 13,267 — 13,267 Total $ 25,494 $ (10,012 ) $ 15,482 Useful Accumulated As of December 31, 2014 Life Gross Amortization Net Intangible assets subject to amortization: Supply contracts (Gross) 11.5 $ 12,227 $ (8,949 ) $ 3,278 Intangible assets not subject to amortization: Rights-of-way assets Indefinite 13,242 — 13,242 Total $ 25,469 $ (8,949 ) $ 16,520

Long-Term Obligations and Sho40

Long-Term Obligations and Short-Term Note Payable (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Schedule of Maturities of Long-term Debt [Table Text Block]	Principal maturities of the Partnership's existing third party debt instruments for the next five years and thereafter are as follows as of December 31, 2015 (in thousands): 2016 2017 2018 2019 2020 Thereafter Total Second Amended and Restated Credit Agreement $ — $ — $ — $ 351,600 $ — $ — $ 351,600

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2015
Distribution Made to Limited Partner [Line Items]
Schedule of Capital Units [Table Text Block]	The table below summarizes the changes in the number of units outstanding through December 31, 2015 (in units). There were no units outstanding prior to the Offering in November 2012. Common - Public Common - Delek Subordinated General Partner Total Units issued in the Offering in November 2012 9,200,000 2,799,258 11,999,258 489,766 24,488,282 Balance at December 31, 2012 9,200,000 2,799,258 11,999,258 489,766 24,488,282 GP units issued to maintain 2% interest — — — 3,127 3,127 Unit-based compensation awards (1) 153,240 — — — 153,240 Balance at December 31, 2013 9,353,240 2,799,258 11,999,258 492,893 24,644,649 GP units issued to maintain 2% interest — — — 1,304 1,304 Unit-based compensation awards (1) 63,949 — — — 63,949 Balance at December 31, 2014 9,417,189 2,799,258 11,999,258 494,197 24,709,902 GP units issued to maintain 2% interest — — — 1,248 1,248 Unit-based compensation awards (1) 61,084 — — — 61,084 Balance at December 31, 2015 9,478,273 2,799,258 11,999,258 495,445 24,772,234 (1) Unit-based compensation awards are presented net of 21,144 , 5,539 and 31,083 units withheld for taxes as of December 31, 2015 , 2014 and 2013 , respectively.
Schedule Of Calculation Of Net Income Applicable To Partners [Table Text Block]	The following table presents the allocation of the general partner's interest in net income (in thousands, except percentage of ownership interest): Year Ended December 31, 2015 2014 2013 Net income attributable to partners $ 66,848 $ 71,997 $ 47,830 Less: General partner's IDRs (3,904 ) (945 ) — Net income available to partners $ 62,944 $ 71,052 $ 47,830 General partner's ownership interest 2.0 % 2.0 % 2.0 % General partner's allocated interest in net income 1,259 1,421 957 General partner's IDRs 3,904 945 — Total general partner's interest in net income $ 5,163 $ 2,366 $ 957
Schedule of Incentive Distributions Made to Managing Members or General Partners by Distribution [Table Text Block]	The following table illustrates the percentage allocations of available cash from operating surplus between the unitholders and our general partner based on the specified target distribution levels. The amounts set forth under “Marginal Percentage Interest in Distributions” are the percentage interests of our general partner and our unitholders in any available cash from operating surplus that we distribute up to and including the corresponding amount in the column “Total Quarterly Distribution per Unit Target Amount.” The percentage interests shown for our unitholders and our general partner for the minimum quarterly distribution are also applicable to quarterly distribution amounts that are less than the minimum quarterly distribution. The percentage interests set forth below for our general partner include its 2.0% general partner interest and assume that (i) our general partner has contributed any additional capital necessary to maintain its 2.0% general partner interest, (ii) our general partner has not transferred its IDRs, and (iii) there are no arrearages on common units. Target Quarterly Distribution per Unit Marginal Percentage Interest in Distributions Target Amount Unitholders General Partner Minimum Quarterly Distribution $ 0.37500 98.0 % 2.0 % First Target Distribution above $ 0.37500 98.0 % 2.0 % up to $ 0.43125 Second Target Distribution above $ 0.43125 85.0 % 15.0 % up to $ 0.46875 Third Target Distribution above $ 0.46875 75.0 % 25.0 % up to $ 0.56250 Thereafter thereafter $ 0.56250 50.0 % 50.0 %
Schedule of Distributions Made to Members or Limited Partners, by Distribution [Table Text Block]	The table below summarizes the quarterly distributions related to our quarterly financial results: Quarter Ended Total Quarterly Distribution Per Limited Partner Unit Total Quarterly Distribution Per Limited Partner Unit, Annualized Total Cash Distribution, including IDRs (in thousands) Date of Distribution Unitholders Record Date December 31, 2013 $ 0.415 $ 1.66 $ 10,228 February 13, 2014 February 4, 2014 March 31, 2014 $ 0.425 $ 1.70 $ 10,474 May 14, 2014 May 6, 2014 June 30, 2014 $ 0.475 $ 1.90 $ 11,910 August 14, 2014 August 7, 2014 September 30, 2014 $ 0.490 $ 1.96 $ 12,394 November 14, 2014 November 6, 2014 December 31, 2014 $ 0.510 $ 2.04 $ 13,056 February 13, 2015 February 6, 2015 March 31, 2015 $ 0.530 $ 2.12 $ 13,702 May 14, 2015 May 4, 2015 June 30, 2015 $ 0.550 $ 2.20 $ 14,368 August 14, 2015 August 6, 2015 September 30, 2015 $ 0.570 $ 2.28 $ 15,136 November 13, 2015 November 6, 2015 December 31, 2015 $ 0.590 $ 2.36 $ 16,124 February 12, 2016 February 5, 2016 Following the February 12, 2016 payment of the cash distribution attributable to the fourth quarter of 2015 , and confirmation by the board of directors of our general partner based on the recommendation of the conflicts committee, on February 25, 2016 , the requirements under the partnership agreement for the conversion of all subordinated units into common units were satisfied and the subordination period ended. As a result, in the first quarter of 2016 , each of the Partnership's 11,999,258 outstanding subordinated units converted into common units and will participate pro rata with the other common units in distributions of available cash. The allocation of total quarterly cash distributions made to general and limited partners for the years ended December 31, 2015 , 2014 and 2013 is set forth in the table below. Our distributions earned with respect to a given period are declared subsequent to quarter end. Therefore, the table below represents total cash distributions applicable to the period in which the distributions are earned (in thousands, except per unit amounts): Year Ended December 31, 2015 2014 2013 General partner's distributions: General partner's distributions $ 1,109 $ 938 $ 785 General partner's IDRs 3,904 945 — Total general partner's distributions 5,013 1,883 785 Limited partners' distributions: Common 27,439 23,152 19,292 Subordinated 26,878 22,799 19,199 Total limited partners' distributions 54,317 45,951 38,491 Total cash distributions $ 59,330 $ 47,834 $ 39,276 Cash distributions per limited partner unit $ 2.240 $ 1.900 $ 1.600

Equity Based Compensation (Tabl

Equity Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Equity Based Compensation [Abstract]
Schedule of Share-based Compensation, Phantom Units Award Activity [Table Text Block]	A summary of our unit award activity for the years ended December 31, 2015 , 2014 and 2013 , is set forth below: Number of Phantom Units Weighted-Average Grant Price Non-vested December 31, 2012 494,883 22.65 Granted 7,500 34.12 Vested (184,323 ) 22.68 Forfeited (43,108 ) 22.65 Non-vested December 31, 2013 274,952 22.94 Granted 10,000 35.46 Vested (69,488 ) 23.08 Non-vested December 31, 2014 215,464 $ 23.48 Granted 11,836 $ 39.73 Vested (82,228 ) $ 23.55 Non-vested December 31, 2015 145,072 $ 24.76

Equity Method Investments (Tabl

Equity Method Investments (Tables)	12 Months Ended
	Dec. 31, 2015
Equity Method Investments [Abstract]
Equity Method Investments [Table Text Block]	Combined summarized financial information for our equity investees is shown below: December 31, 2015 Current Assets $ 11,705 Noncurrent Assets $ 87,467 Current liabilities $ 4,797 Noncurrent liabilities $ — Year Ended December 31, 2015 Revenues $ — Gross profit $ — Net loss $ (1,967 )

Segment Data (Tables)

Segment Data (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting Information [Line Items]
Schedule of Segment Reporting Information, by Segment [Table Text Block]	The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in thousands): Year Ended December 31, 2015 2014 2013 Pipelines and Transportation Net Sales: Affiliate $ 102,551 $ 80,683 $ 51,878 Third-Party 28,828 10,665 8,359 Total Pipelines and Transportation 131,379 91,348 60,237 Operating costs and expenses: Cost of goods sold 19,607 4,294 764 Operating expenses (1) (2) 33,751 31,979 27,728 Segment contribution margin $ 78,021 $ 55,075 $ 31,745 Capital spending (excluding business combinations) (1) (2) $ 16,030 $ 5,804 $ 22,696 Wholesale Marketing and Terminalling Net Sales: Affiliate $ 50,013 $ 33,900 $ 26,295 Third-Party 408,277 716,005 820,896 Total Wholesale Marketing and Terminalling 458,290 749,905 847,191 Operating costs and expenses: Cost of goods sold 416,697 692,927 810,600 Operating expenses 11,172 7,486 8,175 Segment contribution margin $ 30,421 $ 49,492 $ 28,416 Capital spending (excluding business combinations) $ 6,397 $ 3,364 $ 3,041 Consolidated Net Sales: Affiliate $ 152,564 $ 114,583 $ 78,173 Third-Party 437,105 726,670 829,255 Total Consolidated 589,669 841,253 907,428 Operating costs and expenses: Cost of goods sold 436,304 697,221 811,364 Operating expenses (1) (2) 44,923 39,465 35,903 Contribution margin 108,442 104,567 60,161 General and administrative expenses 11,384 10,616 7,526 Depreciation and amortization 19,692 15,022 13,738 Loss on asset disposals 104 83 166 Operating income $ 77,262 $ 78,846 $ 38,731 Capital spending (excluding business combinations) (1) (2) $ 22,427 $ 9,168 $ 25,737 (1) Includes operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015 . (2) Adjusted to include operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015 . The following table summarizes the total assets for each segment as of December 31, 2015 and 2014 (in thousands). Year Ended December 31, 2015 2014 (1) Pipelines and Transportation 283,553 230,293 Wholesale Marketing and Terminalling 91,735 100,993 Total Assets $ 375,288 $ 331,286 (1) Adjusted to include the historical balances of the Logistics Assets Predecessor.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements [Abstract]
Fair Value, Assets Measured on Recurring Basis [Table Text Block]	The fair value hierarchy for our financial assets accounted for at fair value on a recurring basis at December 31, 2015 and 2014 was as follows: (in thousands): As of December 31, 2015 Level 1 Level 2 Level 3 Total Assets Interest rate derivatives $ — $ — $ — $ — OTC commodity swaps $ — $ 171 $ — $ 171 Total assets — 171 — 171 Liabilities OTC commodity swaps — (45 ) — (45 ) Net Assets $ — $ 126 $ — $ 126 As of December 31, 2014 Level 1 Level 2 Level 3 Total Assets Interest rate derivatives $ — $ 24 $ — $ 24 OTC commodity swaps — 456 — 456 Total assets — 480 — 480 Liabilities OTC commodity swaps — (61 ) — (61 ) Net assets $ — $ 419 $ — $ 419

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	The following table presents the fair value of our derivative instruments, as of December 31, 2015 and 2014 . The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including any cash collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below may differ from the amounts presented in our consolidated balance sheets. During the years ended December 31, 2015 and 2014 , we did not elect hedge accounting treatment for these derivative positions. As a result, all changes in fair value are marked to market in the accompanying consolidated statements of income and comprehensive income. December 31, 2015 December 31, 2014 Derivative Type Balance Sheet Location Assets Liabilities Assets Liabilities Derivatives not designated as hedging instruments: Interest rate derivatives Other long term assets $ — $ — $ 24 $ — OTC commodity swaps (1) Other current assets 171 (45 ) 456 (61 ) Total gross value of derivatives $ 171 $ (45 ) $ 480 $ (61 ) Less: Counterparty netting and cash collateral (2) (706 ) (45 ) 61 (61 ) Total net fair value of derivatives $ 877 $ — $ 419 $ — (1) As of December 31, 2015 , we had open derivative contracts representing 171,000 barrels of refined petroleum products. As of December 31, 2014 , we had 142,000 open derivative contracts. (2) As of December 31, 2015 , $0.8 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2014 , no cash collateral was held by counterparty brokerage firms.
Derivative Instruments, Gain (Loss) [Table Text Block]	ains (losses) associated with derivatives not designated as hedging instruments for the years ended December 31, 2015 and 2014 were as follows (in thousands): Year Ended December 31, Derivative Type Income Statement Location 2015 2014 2013 Interest rate derivatives Interest expense $ (24 ) $ (92 ) $ (106 ) OTC commodity swaps Cost of goods sold 441 3,083 (614 ) Total $ 417 $ 2,991 $ (720 )

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The difference between the actual income tax expense and the tax expense computed by applying the statutory federal income tax rate to income before income taxes is attributable to the following (in thousands): Year Ended December 31, 2015 2014 2013 State income taxes 171 492 794 Other items (366 ) (360 ) (37 ) Income tax (benefit) expense $ (195 ) $ 132 $ 757
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax (benefit) expense is as follows (in thousands): Year Ended December 31, 2015 2014 2013 Current $ (209 ) $ 241 $ 448 Deferred 14 (109 ) 309 Total $ (195 ) $ 132 $ 757

Commitments and Contingencies48

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]	The following is an estimate of our future minimum lease payments for operating leases having remaining noncancelable terms in excess of one year as of December 31, 2015 (in thousands): 2016 $ 4,991 2017 4,893 2018 2,184 2019 253 2020 189 Thereafter 9 Total future minimum rentals $ 12,519

Selected Quarterly Financial 49

Selected Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2015
Selected Quarterly Financial Information [Abstract]
Schedule of Quarterly Financial Information [Table Text Block]	Quarterly financial information for the years ended December 31, 2015 and 2014 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). For the Three Month Periods Ended March 31, 2015 (1) June 30, 2015 September 30, 2015 December 31, 2015 Net sales $ 143,512 $ 172,134 $ 165,092 $ 108,931 Operating income $ 16,414 $ 21,139 $ 21,847 $ 17,862 Net income $ 14,003 $ 18,311 $ 18,602 $ 15,295 Limited partners' interest in net income $ 13,753 $ 17,202 $ 17,219 $ 13,511 Net income per limited partner unit: Common (basic) $ 0.57 $ 0.71 $ 0.71 $ 0.56 Common (diluted) $ 0.56 $ 0.70 $ 0.70 $ 0.55 Subordinated - Delek (basic and diluted) $ 0.57 $ 0.71 $ 0.71 $ 0.56 (1) The information presented includes the results of operations of the Logistics Assets Predecessor. For the Three Month Periods Ended March 31, 2014 (1) June 30, 2014 (1) September 30, 2014 (1) December 31, 2014 (1) Net sales $ 203,527 $ 236,343 $ 228,036 $ 173,347 Operating income $ 15,682 $ 24,111 $ 17,242 $ 21,811 Net income $ 13,552 $ 21,488 $ 14,839 $ 20,179 Limited partners' interest in net income $ 14,379 $ 21,134 $ 14,487 $ 19,631 Net income per limited partner unit: Common (basic) $ 0.60 $ 0.88 $ 0.60 $ 0.81 Common (diluted) $ 0.59 $ 0.87 $ 0.59 $ 0.80 Subordinated - Delek (basic and diluted) $ 0.60 $ 0.87 $ 0.60 $ 0.81 (1) The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.

General (Details)

General (Details)	Mar. 31, 2015bbl / purebbl	Feb. 10, 2014	Jul. 26, 2013
Tyler Terminal and Tank Assets [Member]
Business Acquisition [Line Items]
Number of Storage Tanks			96
El Dorado Terminal and Tank Assets [Member]
Business Acquisition [Line Items]
Number of Storage Tanks		158
Tyler Assets [Member]
Business Acquisition [Line Items]
Aggregate Shell Capacity (barrels)	350,000
Light Crude Oil | El Dorado Assets [Member]
Business Acquisition [Line Items]
Total Throughput Capacity (bpd)	25,000
Heavy Crude Oil | El Dorado Assets [Member]
Business Acquisition [Line Items]
Total Throughput Capacity (bpd)	12,000

Accounting Policies Accounts Re

Accounting Policies Accounts Receivable (Details)	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Concentration Risk [Line Items]
Allowance for Doubtful Accounts Receivable	$ 0	$ 0
Accounts Receivable [Member] | Customer Concentration Risk [Member] | Largest customer [Member]
Concentration Risk [Line Items]
Number of Customers	1
Concentration Risk, Percentage	15.20%	21.00%

Accounting Policies Inventory (

Accounting Policies Inventory (Details) - Supplier Concentration Risk [Member] - Inventory purchased [Member] - Wholesale Marketing and Terminalling	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Concentration Risk [Line Items]
Concentration Risk, Percentage	62.60%	69.00%	96.10%
Number Of Suppliers	1	1	2
Delek US [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	24.90%

Accounting Policies Property, P

Accounting Policies Property, Plant and Equipment (Details)	12 Months Ended
	Dec. 31, 2015
Minimum [Member] | Building and Pipeline Improvements [Member]
Estimated useful life (years)	15 years
Minimum [Member] | Pipelines, tanks and terminals
Estimated useful life (years)	15 years
Minimum [Member] | Asset retirement obligation assets
Estimated useful life (years)	15 years
Minimum [Member] | Other equipment
Estimated useful life (years)	3 years
Maximum [Member] | Building and Pipeline Improvements [Member]
Estimated useful life (years)	40 years
Maximum [Member] | Pipelines, tanks and terminals
Estimated useful life (years)	40 years
Maximum [Member] | Asset retirement obligation assets
Estimated useful life (years)	50 years
Maximum [Member] | Other equipment
Estimated useful life (years)	15 years

Accounting Policies Intangible

Accounting Policies Intangible Assets (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Supply contracts [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months	11 years 6 months

Accounting Policies Asset Retir

Accounting Policies Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 3,319	[1]	$ 3,087
Liabilities settled	(64)		0
Accretion expense	251	[2]	232	[3]	$ 224	[3]
Ending balance	$ 3,506		$ 3,319	[1]	$ 3,087
[1]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Accounting Policies Net income

Accounting Policies Net income per limited partner unit (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accounting Policies [Abstract]
General partner's ownership interest	2.00%	2.00%	2.00%

Acquisitions El Dorado and Tyle

Acquisitions El Dorado and Tyler Acquisitions (Details) - USD ($) $ in Thousands	Mar. 31, 2015	Feb. 10, 2014	Jul. 26, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
El Dorado Assets [Member]
Business Acquisition [Line Items]
Cash paid for acquisition	$ 42,500
Historical carrying value of assets	7,600
Total operating revenues				$ 4,449
Net income attributable to the Partnership				3,277
Tyler Assets [Member]
Business Acquisition [Line Items]
Cash paid for acquisition	19,400
Historical carrying value of assets	$ 11,600
Total operating revenues				1,620
Net income attributable to the Partnership				1,035
El Dorado Terminal and Tank Assets [Member]
Business Acquisition [Line Items]
Cash paid for acquisition		$ 95,900				$ 94,800
Tyler Terminal and Tank Assets [Member]
Business Acquisition [Line Items]
Cash paid for acquisition			$ 94,800	61,900	$ 95,900
General and Administrative Expense [Member] | El Dorado Assets [Member]
Business Acquisition [Line Items]
Costs associated with the acquisition				235
General and Administrative Expense [Member] | Tyler Assets [Member]
Business Acquisition [Line Items]
Costs associated with the acquisition				$ 240

Acquisitions El Dorado and Ty58

Acquisitions El Dorado and Tyler Terminals and Tank Assets Financial Results (Details) - USD ($) $ in Thousands		3 Months Ended														12 Months Ended
		Dec. 31, 2015		Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	[5]	Dec. 31, 2014		Sep. 30, 2014	[6]	Jun. 30, 2014	[6]	Mar. 31, 2014	[6]	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Current assets:
Cash and cash equivalents		$ 0	[1]					$ 1,861	[1],[2],[3]							$ 0	[1]	$ 1,861	[1],[2],[3]	$ 924	[3]	$ 23,452	[3]
Accounts receivable		35,049						27,986	[2]							35,049		27,986	[2]
Inventory		10,451						10,316	[2]							10,451		10,316	[2]
Deferred tax assets		0						28	[2]							0		28	[2]
Other current assets		1,540						768	[2]							1,540		768	[2]
Total current assets		47,040						40,959	[2]							47,040		40,959	[2]
Property, Plant and Equipment [Abstract]
Property, plant and equipment		325,647						308,088	[2]							325,647		308,088	[2]
Less: accumulated depreciation		(71,799)						(53,309)	[2]							(71,799)		(53,309)	[2]
Property, plant and equipment, net		253,848						254,779	[2]							253,848		254,779	[2]
Goodwill		12,203						11,654	[2]							12,203		11,654	[2]	11,654		10,454
Intangible assets, net		15,482						16,520	[2]							15,482		16,520	[2]
Other non-current assets		6,037						7,374	[2]							6,037		7,374	[2]
Total assets		375,288						331,286	[2],[4]							375,288		331,286	[2],[4]
Current liabilities:
Accounts payable		6,850						17,929	[2]							6,850		17,929	[2]
Accounts payable to related parties								628										628
Excise and other taxes payable		4,871						5,443	[2]							4,871		5,443	[2]
Tank inspection liabilities		1,890						2,829	[2]							1,890		2,829	[2]
Pipeline release liabilities		1,393						1,899	[2]							1,393		1,899	[2]
Accrued expenses and other current liabilities		1,694						1,588	[2]							1,694		1,588	[2]
Total current liabilities		20,690						30,316	[2]							20,690		30,316	[2]
Non-current liabilities:
Revolving credit facility		351,600						251,750	[2]							351,600		251,750	[2]
Asset retirement obligations		3,506						3,319	[2]							3,506		3,319	[2]	3,087
Deferred tax liabilities		0						231	[2]							0		231	[2]
Other non-current liabilities		10,510						5,889	[2]							10,510		5,889	[2]
Total non-current liabilities		365,616						261,189	[2]							365,616		261,189	[2]
Equity:
Total (deficit) equity		(11,018)						39,781	[2]							(11,018)		39,781	[2]	105,208		166,733
Total liabilities and equity		375,288						331,286	[2]							375,288		331,286	[2]
Consolidated Statements of Income
Net sales		108,931		$ 165,092	$ 172,134	$ 143,512		173,347	[6]	$ 228,036		$ 236,343		$ 203,527		589,669	[7]	841,253	[8],[9]	907,428	[8],[9]
Operating costs and expenses:
Cost of goods sold																436,304	[7]	697,221	[8],[9]	811,364	[8],[9]
Operating expenses	[10],[11]															44,923	[7]	39,465	[8],[9]	35,903	[8],[9]
General and administrative expenses																11,384	[7]	10,616	[8],[9]	7,526	[8],[9]
Depreciation and amortization																19,692	[1],[7]	15,022	[3],[8],[9]	13,738	[3],[8],[9]
Loss on asset disposals																104	[1],[7]	83	[3],[8],[9]	166	[3],[8],[9]
Total operating costs and expenses																512,407	[7]	762,407	[8],[9]	868,697	[8],[9]
Operating income (loss)		17,862		$ 21,847	$ 21,139	$ 16,414		21,811	[6]	$ 17,242		$ 24,111		$ 15,682		77,262	[7]	78,846	[8],[9]	38,731	[8],[9]
Interest expense, net																10,658	[7]	8,656	[8],[9]	4,570	[8],[9]
Loss on equity method investments																588	[1],[7]	0	[3],[8]	0	[3],[8]
Total non-operating (income) expenses																11,246	[7]	8,656	[8]	4,570	[8]
Income (loss) before income tax expense (benefit)																66,016	[7]	70,190	[8],[9]	34,161	[8],[9]
Income tax (benefit) expense																(195)	[7]	132	[8],[9]	757	[8],[9]
Net income (loss)																66,211		70,058	[9]	33,404	[9]
Less: loss attributable to Predecessors																(637)	[7]	(1,939)	[8],[9]	(14,426)	[8],[9]
Net income attributable to partners																66,848	[7]	71,997	[8],[9]	47,830	[8],[9]
Delek Logistics Partners, LP
Current assets:
Cash and cash equivalents								1,861										1,861
Accounts receivable								27,986										27,986
Inventory								10,316										10,316
Deferred tax assets								28										28
Other current assets								768										768
Total current assets								40,959										40,959
Property, Plant and Equipment [Abstract]
Property, plant and equipment								288,045										288,045
Less: accumulated depreciation								(52,992)										(52,992)
Property, plant and equipment, net								235,053										235,053
Goodwill								11,654										11,654
Intangible assets, net								16,520										16,520
Other non-current assets								7,374										7,374
Total assets								311,560										311,560
Current liabilities:
Accounts payable								17,929										17,929
Accounts payable to related parties								628										628
Excise and other taxes payable								5,443										5,443
Tank inspection liabilities								2,829										2,829
Pipeline release liabilities								1,899										1,899
Accrued expenses and other current liabilities								1,588										1,588
Total current liabilities								30,316										30,316
Non-current liabilities:
Revolving credit facility								251,750										251,750
Asset retirement obligations								3,319										3,319
Deferred tax liabilities								231										231
Other non-current liabilities								5,889										5,889
Total non-current liabilities								261,189										261,189
Equity:
Total (deficit) equity								20,055										20,055
Total liabilities and equity								311,560										311,560
Consolidated Statements of Income
Net sales																589,669		841,253		907,428
Operating costs and expenses:
Cost of goods sold																436,304		697,221		811,364
Operating expenses																44,756		38,003		35,640
General and administrative expenses																11,384		10,570		7,526
Depreciation and amortization																19,222		14,591		13,738
Loss on asset disposals																104		83		166
Total operating costs and expenses																511,770		760,468		868,434
Operating income (loss)																77,899		80,785		38,994
Interest expense, net																10,658		8,656		4,570
Loss on equity method investments																588
Total non-operating (income) expenses																11,246
Income (loss) before income tax expense (benefit)																66,653		72,129		34,424
Income tax (benefit) expense																(195)		132		757
Net income (loss)																66,848		71,997		33,667
Less: loss attributable to Predecessors																0		0		(14,163)
Net income attributable to partners																66,848		71,997		47,830
Predecessor | El Dorado Assets [Member]
Current assets:
Cash and cash equivalents								0										0
Accounts receivable								0										0
Inventory								0										0
Deferred tax assets								0										0
Other current assets								0										0
Total current assets								0										0
Property, Plant and Equipment [Abstract]
Property, plant and equipment								8,267										8,267
Less: accumulated depreciation								(317)										(317)
Property, plant and equipment, net								7,950										7,950
Goodwill								0										0
Intangible assets, net								0										0
Other non-current assets								0										0
Total assets								7,950										7,950
Current liabilities:
Accounts payable								0										0
Accounts payable to related parties								0										0
Excise and other taxes payable								0										0
Tank inspection liabilities								0										0
Pipeline release liabilities								0										0
Accrued expenses and other current liabilities								0										0
Total current liabilities								0										0
Non-current liabilities:
Revolving credit facility								0										0
Asset retirement obligations								0										0
Deferred tax liabilities								0										0
Other non-current liabilities								0										0
Total non-current liabilities								0										0
Equity:
Total (deficit) equity								7,950										7,950
Total liabilities and equity								7,950										7,950
Consolidated Statements of Income
Net sales																		0		0
Operating costs and expenses:
Cost of goods sold																		0		0
Operating expenses																167		679		263
General and administrative expenses																0		0		0
Depreciation and amortization																372		317		0
Loss on asset disposals																0		0		0
Total operating costs and expenses																539		996		263
Operating income (loss)																(539)		(996)		(263)
Interest expense, net																0		0		0
Loss on equity method investments																0
Total non-operating (income) expenses																0
Income (loss) before income tax expense (benefit)																(539)		(996)		(263)
Income tax (benefit) expense																0		0		0
Net income (loss)																(539)		(996)		(263)
Less: loss attributable to Predecessors																(539)		(996)		(263)
Net income attributable to partners																0		0		0
Predecessor | Tyler Assets [Member]
Current assets:
Cash and cash equivalents								0										0
Accounts receivable								0										0
Inventory								0										0
Deferred tax assets								0										0
Other current assets								0										0
Total current assets								0										0
Property, Plant and Equipment [Abstract]
Property, plant and equipment								11,776										11,776
Less: accumulated depreciation								0										0
Property, plant and equipment, net								11,776										11,776
Goodwill								0										0
Intangible assets, net								0										0
Other non-current assets								0										0
Total assets								11,776										11,776
Current liabilities:
Accounts payable								0										0
Accounts payable to related parties								0										0
Excise and other taxes payable								0										0
Tank inspection liabilities								0										0
Pipeline release liabilities								$ 0										$ 0
Accrued expenses and other current liabilities
Total current liabilities								$ 0										$ 0
Non-current liabilities:
Revolving credit facility								0										0
Asset retirement obligations								0										0
Deferred tax liabilities								0										0
Other non-current liabilities								0										0
Total non-current liabilities								0										0
Equity:
Total (deficit) equity								11,776										11,776
Total liabilities and equity								11,776										11,776
Consolidated Statements of Income
Net sales																0
Operating costs and expenses:
Cost of goods sold																0
Operating expenses																0
General and administrative expenses																0
Depreciation and amortization																98
Loss on asset disposals																0
Total operating costs and expenses																98
Operating income (loss)																(98)
Interest expense, net																0
Loss on equity method investments																0
Total non-operating (income) expenses																0
Income (loss) before income tax expense (benefit)																(98)
Income tax (benefit) expense																0
Net income (loss)																(98)
Less: loss attributable to Predecessors																(98)
Net income attributable to partners																0
Predecessor division equity
Equity:
Total (deficit) equity		0						19,726	[2]							0		19,726	[2]	43,167		62,308
Operating costs and expenses:
Less: loss attributable to Predecessors																(637)		(1,939)		(14,426)
Net income attributable to partners																0		0		0
Predecessor division equity | Delek Logistics Partners, LP
Equity:
Total (deficit) equity								0										0
Predecessor division equity | Predecessor | El Dorado Assets [Member]
Equity:
Total (deficit) equity								7,950										7,950
Predecessor division equity | Predecessor | Tyler Assets [Member]
Equity:
Total (deficit) equity								11,776										11,776
General partner - Delek; 495,445 units issued and outstanding at December 31, 2015 (494,197 at December 31, 2014)
Equity:
Total (deficit) equity		(7,192)						(7,085)	[2]							(7,192)		(7,085)	[2]	(4,504)		(49)
Operating costs and expenses:
Less: loss attributable to Predecessors																0
Net income attributable to partners																5,163		1,440		957
General partner - Delek; 495,445 units issued and outstanding at December 31, 2015 (494,197 at December 31, 2014) | Delek Logistics Partners, LP
Equity:
Total (deficit) equity								(7,085)										(7,085)
General partner - Delek; 495,445 units issued and outstanding at December 31, 2015 (494,197 at December 31, 2014) | Predecessor | El Dorado Assets [Member]
Equity:
Total (deficit) equity								0										0
General partner - Delek; 495,445 units issued and outstanding at December 31, 2015 (494,197 at December 31, 2014) | Predecessor | Tyler Assets [Member]
Equity:
Total (deficit) equity								0										0
Common unitholders - public; 9,478,273 units issued and outstanding at December 31, 2015 (9,417,189 at December 31, 2014) | Limited Partner [Member]
Equity:
Total (deficit) equity		198,401						194,737	[2]							198,401		194,737	[2]	183,839		178,728
Operating costs and expenses:
Less: loss attributable to Predecessors																0
Net income attributable to partners																24,039		27,386		18,035
Common unitholders - public; 9,478,273 units issued and outstanding at December 31, 2015 (9,417,189 at December 31, 2014) | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total (deficit) equity								194,737										194,737
Common unitholders - public; 9,478,273 units issued and outstanding at December 31, 2015 (9,417,189 at December 31, 2014) | Limited Partner [Member] | Predecessor | El Dorado Assets [Member]
Equity:
Total (deficit) equity								0										0
Common unitholders - public; 9,478,273 units issued and outstanding at December 31, 2015 (9,417,189 at December 31, 2014) | Limited Partner [Member] | Predecessor | Tyler Assets [Member]
Equity:
Total (deficit) equity								0										0
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2015 (2,799,258 at December 31, 2014) | Limited Partner [Member]
Equity:
Total (deficit) equity		$ (280,828)						(241,112)	[2]							(280,828)		(241,112)	[2]	(176,680)		$ (127,129)
Operating costs and expenses:
Less: loss attributable to Predecessors																0
Net income attributable to partners																$ 7,121		8,166		$ 5,455
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2015 (2,799,258 at December 31, 2014) | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total (deficit) equity								(241,112)										(241,112)
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2015 (2,799,258 at December 31, 2014) | Limited Partner [Member] | Predecessor | El Dorado Assets [Member]
Equity:
Total (deficit) equity								0										0
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2015 (2,799,258 at December 31, 2014) | Limited Partner [Member] | Predecessor | Tyler Assets [Member]
Equity:
Total (deficit) equity								0										0
Subordinated Units [Member] | Limited Partner [Member]
Equity:
Total (deficit) equity								73,515										73,515
Subordinated Units [Member] | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total (deficit) equity								73,515										73,515
Subordinated Units [Member] | Limited Partner [Member] | Predecessor | El Dorado Assets [Member]
Equity:
Total (deficit) equity								0										0
Subordinated Units [Member] | Limited Partner [Member] | Predecessor | Tyler Assets [Member]
Equity:
Total (deficit) equity								$ 0										$ 0
[1]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	Adjusted to include the historical balances of the Logistics Assets Predecessor.
[5]	The information presented includes the results of operations of the Logistics Assets Predecessor.
[6]	The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.
[7]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[8]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[9]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[10]	Adjusted to include operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.
[11]	Includes operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.

Acquisitions from Third Parties

Acquisitions from Third Parties (Details)	Oct. 02, 2014bbl	Oct. 24, 2013bbl / purebbl	Dec. 17, 2014
FTT Assets
Business Acquisition [Line Items]
Number of trucks acquired			123
Number of trailers acquired			205
Mount Pleasant Terminal [Member]
Business Acquisition [Line Items]
Storage capacity (barrels)	200,000
Greenville Terminal [Member]
Business Acquisition [Line Items]
Storage capacity (barrels)	325,000
North Little Rock Terminal
Business Acquisition [Line Items]
Storage capacity (barrels)		140,000
Total Throughput Capacity (bpd)		10,000

Acquisitions Purchase Price All

Acquisitions Purchase Price Allocation (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 17, 2014	Oct. 01, 2014	Oct. 24, 2013	Jul. 19, 2013
FTT Assets
Business Acquisition [Line Items]
Property, Plant and Equipment	[1]		$ 10,790
Intangible Assets	[1]		0
Goodwill	[1],[2]		549
Inventory	[1]		0
Accounts Receivable	[1]		1,767
Accounts Payable	[1]		(1,181)
Total	[1]		$ 11,925
Footnote [Abstract]
Additional Consideration Transferred		$ 400
Greenville-Mount Pleasant Assets
Business Acquisition [Line Items]
Property, Plant and Equipment	[3]			$ 4,829
Intangible Assets	[3]			5,171
Goodwill	[2],[3]			0
Inventory	[3]			1,125
Accounts Receivable	[3]			0
Accounts Payable	[3]			0
Total	[3]			$ 11,125
North Little Rock Terminal
Business Acquisition [Line Items]
Property, Plant and Equipment					$ 4,990
Intangible Assets					10
Goodwill	[2]				0
Inventory					0
Accounts Receivable					0
Accounts Payable					0
Total					$ 5,000
Hopewell
Business Acquisition [Line Items]
Property, Plant and Equipment						$ 3,538
Intangible Assets						984
Goodwill	[2]					1,200
Inventory						0
Accounts Receivable						0
Accounts Payable						0
Total						$ 5,722
[1]	During the fourth quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed in connection with working capital adjustments and an additional $0.4 million of consideration paid for additional assets.
[2]	All goodwill is expected to be deductible for tax purposes.
[3]	During the third quarter of 2015, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed.

Acquisitions Pro Forma Infromat

Acquisitions Pro Forma Infromation (Details) - USD ($) $ in Thousands

3 Months Ended

12 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

[1]

Dec. 31, 2014

[2]

Sep. 30, 2014

[2]

Jun. 30, 2014

[2]

Mar. 31, 2014

[2]

Dec. 31, 2015

[3]

Dec. 31, 2014

Dec. 31, 2013

Business Acquisition [Line Items]

Net sales

$ 108,931

$ 165,092

$ 172,134

$ 143,512

$ 173,347

$ 228,036

$ 236,343

$ 203,527

$ 589,669

$ 841,253

[4],[5]

$ 907,428

[4],[5]

Net income

$ 15,295

$ 18,602

$ 18,311

$ 14,003

$ 20,179

$ 14,839

$ 21,488

$ 13,552

$ 66,211

[6]

70,058

[4],[7]

33,404

[4],[7]

FTT Assets

Business Acquisition [Line Items]

Net sales

854,842

921,017

Net income

70,824

34,170

Greenville-Mount Pleasant Assets

Business Acquisition [Line Items]

Net sales

841,943

908,118

Net income

$ 69,621

32,967

North Little Rock Terminal

Business Acquisition [Line Items]

Net sales

908,867

Net income

34,695

Hopewell

Business Acquisition [Line Items]

Net sales

908,382

Net income

$ 33,718

[1]

The information presented includes the results of operations of the Logistics Assets Predecessor.

[2]

The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.

[3]

The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

[4]

Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

[5]

There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.

[6]

Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

[7]

Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Related Party Transactions Comm

Related Party Transactions Commercial Agreements (Details)		Mar. 31, 2015USD ($)	Mar. 31, 2015$ / bbl	Feb. 28, 2014USD ($)bbl / pure$ / bbl	Oct. 31, 2013bbl / pure$ / bbl	Jul. 31, 2013USD ($)bbl / pure$ / bbl	Nov. 30, 2012USD ($)bbl / pure$ / bbl	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
East Texas Crude Logistics System [Member]
Footnote [Abstract]
Throughput Volume Subject to Additional Fee (bpd)							50,000
Throughput Commitment Rate, Additional for Excess Barrels (dollars per barrel)							0.682
East Texas Marketing [Member] | Minimum [Member]
Footnote [Abstract]
Profit Sharing Incentive Fee Revenue, Quarterly Amount | $							$ 175,000
East Texas Marketing [Member] | Maximum [Member]
Footnote [Abstract]
Profit Sharing Incentive Fee Revenue, Quarterly Amount | $							$ 500,000
Delek [Member]
Footnote [Abstract]
General and administrative expenses | $	[1]							$ 6,356,000	$ 5,799,000	$ 4,010,000
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)	[2]						46,000
Throughput Commitment Tariff Rate (dollars per barrel)	[3]						0.97
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)							40,000
Throughput Commitment Tariff Rate (dollars per barrel)							0.11
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | SALA Gathering System
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)							14,000
Throughput Commitment Tariff Rate (dollars per barrel)	[3]						2.56
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Minimum [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)							5 years
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Minimum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)							5 years
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Minimum [Member] | SALA Gathering System
Related Party Transaction [Line Items]
Term Of Agreement (years)							5 years
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Maximum [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]						15 years
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Maximum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]						15 years
Delek [Member] | Lion Pipeline System and SALA Gathering System [Member] | Maximum [Member] | SALA Gathering System
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]						15 years
Delek [Member] | East Texas Crude Logistics System [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)							35,000
Throughput Commitment Tariff Rate (dollars per barrel)	[5]						0.45
Delek [Member] | East Texas Crude Logistics System [Member] | Storage
Related Party Transaction [Line Items]
Minimum Monthly Storage Fee Revenue, Amount | $							$ 284,090
Delek [Member] | East Texas Crude Logistics System [Member] | Minimum [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)							5 years
Delek [Member] | East Texas Crude Logistics System [Member] | Minimum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)							5 years
Delek [Member] | East Texas Crude Logistics System [Member] | Maximum [Member] | Crude Oil Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]						15 years
Delek [Member] | East Texas Crude Logistics System [Member] | Maximum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]						15 years
Delek [Member] | East Texas Marketing [Member]
Related Party Transaction [Line Items]
Term Of Agreement (years)	[6]						10 years
Minimum Throughput Commitment (bpd)							50,000
Throughput Commitment Tariff Rate (dollars per barrel)	[6]						0.6210
Delek [Member] | Big Sandy Terminal [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)	[7]						5,000
Throughput Commitment Tariff Rate (dollars per barrel)	[7]						0.57
Delek [Member] | Big Sandy Terminal [Member] | Big Sandy Terminal
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)	[7]						5,000
Throughput Commitment Tariff Rate (dollars per barrel)	[7]						0.57
Delek [Member] | Big Sandy Terminal [Member] | Storage
Related Party Transaction [Line Items]
Minimum Monthly Storage Fee Revenue, Amount | $	[7]						$ 56,768
Delek [Member] | Big Sandy Terminal [Member] | Minimum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[7]						5 years
Delek [Member] | Big Sandy Terminal [Member] | Minimum [Member] | Big Sandy Terminal
Related Party Transaction [Line Items]
Term Of Agreement (years)	[7]						5 years
Delek [Member] | Big Sandy Terminal [Member] | Minimum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)	[7]						5 years
Delek [Member] | Big Sandy Terminal [Member] | Maximum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4],[7]						15 years
Delek [Member] | Big Sandy Terminal [Member] | Maximum [Member] | Big Sandy Terminal
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4],[7]						15 years
Delek [Member] | Big Sandy Terminal [Member] | Maximum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4],[7]						15 years
Delek [Member] | Tyler Terminal Throughput and Tankage [Member]
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)						50,000
Throughput Commitment Tariff Rate (dollars per barrel)						0.35
Delek [Member] | Tyler Terminal Throughput and Tankage [Member] | Storage
Related Party Transaction [Line Items]
Minimum Monthly Storage Fee Revenue, Amount | $						$ 829,902
Delek [Member] | Tyler Terminal Throughput and Tankage [Member] | Minimum [Member]
Related Party Transaction [Line Items]
Term Of Agreement (years)						8 years
Delek [Member] | Tyler Terminal Throughput and Tankage [Member] | Minimum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)						8 years
Delek [Member] | Tyler Terminal Throughput and Tankage [Member] | Maximum [Member]
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]					16 years
Delek [Member] | Tyler Terminal Throughput and Tankage [Member] | Maximum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]					16 years
Delek [Member] | Memphis Pipeline [Member]
Related Party Transaction [Line Items]
Term Of Agreement (years)	[6]				5 years
Minimum Throughput Commitment (bpd)					10,959
Throughput Commitment Tariff Rate (dollars per barrel)	[6]				1.38
Delek [Member] | El Dorado Throughput and Tankage [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Minimum Throughput Commitment (bpd)				11,000
Throughput Commitment Tariff Rate (dollars per barrel)				0.50
Delek [Member] | El Dorado Throughput and Tankage [Member] | Storage
Related Party Transaction [Line Items]
Minimum Monthly Storage Fee Revenue, Amount | $				$ 1,309,085
Delek [Member] | El Dorado Throughput and Tankage [Member] | Minimum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)				8 years
Delek [Member] | El Dorado Throughput and Tankage [Member] | Minimum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)				8 years
Delek [Member] | El Dorado Throughput and Tankage [Member] | Maximum [Member] | Refined Product Pipeline
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]			16 years
Delek [Member] | El Dorado Throughput and Tankage [Member] | Maximum [Member] | Storage
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]			16 years
Delek [Member] | El Dorado Assets [Member]
Footnote [Abstract]
Minimum throughput fee | $		$ 1,500,000
Delek [Member] | El Dorado Assets [Member] | Light Crude Oil
Related Party Transaction [Line Items]
Throughput Commitment Tariff Rate (dollars per barrel)	[8]		1
Delek [Member] | El Dorado Assets [Member] | Heavy Crude Oil
Related Party Transaction [Line Items]
Throughput Commitment Tariff Rate (dollars per barrel)	[8]		2.25
Delek [Member] | El Dorado Assets [Member] | Minimum [Member] | Light Crude Oil
Related Party Transaction [Line Items]
Term Of Agreement (years)			9 years
Delek [Member] | El Dorado Assets [Member] | Minimum [Member] | Heavy Crude Oil
Related Party Transaction [Line Items]
Term Of Agreement (years)			9 years
Delek [Member] | El Dorado Assets [Member] | Maximum [Member] | Light Crude Oil
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]		15 years
Delek [Member] | El Dorado Assets [Member] | Maximum [Member] | Heavy Crude Oil
Related Party Transaction [Line Items]
Term Of Agreement (years)	[4]		15 years
Delek [Member] | Logistics Assets Predecessor
Footnote [Abstract]
General and administrative expenses | $								$ 0	$ 0	$ 0
[1]	General and administrative expenses include costs allocated to our Predecessors for general and administrative support provided by Delek, including services such as corporate management, risk management, accounting and human resources. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $0.5 million for the year ended December 31, 2013. With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were
[2]	Excludes volumes gathered on the SALA Gathering System.
[3]	Volumes gathered on the SALA Gathering System will not be subject to an additional fee for transportation on our Lion Pipeline System to the El Dorado Refinery.
[4]	Maximum term gives effect to the extension of the commercial agreement pursuant to the terms thereof.
[5]	For any volumes in excess of 50,000 bpd, the throughput fee will be $0.682/bbl.
[6]	Following the primary term, the marketing agreement automatically renews for successive one-year terms unless either party provides notice of non-renewal 10 months prior to the expiration of the then-current term. An additional fee of 50% of the margin on products sold is also paid pursuant to the agreement. The fee shall not be less than $175,000 nor greater than $500,000 per quarter.
[7]	On July 19, 2013, we acquired the Hopewell Pipeline in order to effectively connect it with the Big Sandy Pipeline and thereby return the Big Sandy Terminal to operation. In connection with the acquisition, on July 25, 2013, we and Delek entered into the Amended and Restated Services Agreement (Big Sandy Terminal and Pipeline), which amended and restated the terminalling services agreement for the Big Sandy Terminal originally entered into in connection with the Offering.
[8]	The throughput agreement provides for a minimum throughput fee of $1.5 million per quarter for throughput of a combination of light and heavy crude.

Related Party Transactions Omni

Related Party Transactions Omnibus Agreement (Details) - USD ($) $ in Thousands	Apr. 01, 2015	Mar. 31, 2015	Feb. 26, 2014	Dec. 31, 2015	[1]	Dec. 31, 2014		Dec. 31, 2013
Related Party Transaction [Line Items]
Deductible amount to reimburse the Partnership with respect to certain asset failures	$ 1,000
Reimbursement of capital expenditures by Sponsor				$ 5,220		$ 1,578	[2]	$ 837	[2]
Environmental Remediation Expense						1,000		600
Omnibus Agreement [Member] | Delek US [Member]
Related Party Transaction [Line Items]
Omnibus Agreement Annual Amount		$ 3,400	$ 3,300
Haynesville Crude Oil Release [Member]
Related Party Transaction [Line Items]
Environmental Remediation Expense						$ 1,000		$ 300
[1]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Related Party Transactions Oper

Related Party Transactions Operation and Management Services Agreement (Details) - General Partner - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operation and Management Services Agreement [Member]
Related Party Transaction [Line Items]
Management Fee, Amount Paid			$ 5.9
Partnership Agreement [Member]
Related Party Transaction [Line Items]
Management Fee, Amount Paid	$ 22.8	$ 12.3	$ 6.5

Related Party Transactions Othe

Related Party Transactions Other Agreements (Details) $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Paline Pipeline [Member] | General Partner
Related Party Transaction [Line Items]
Revenue	$ 0.9

Related Party Transactions Summ

Related Party Transactions Summary of Transactions (Details) - Delek [Member] - USD ($)		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Revenue		$ 152,564,000	$ 114,583,000	$ 78,173,000
General and administrative expenses	[1]	6,356,000	5,799,000	4,010,000
Tyler Predecessor
Related Party Transaction [Line Items]
Operating and maintenance expenses				1,400,000
General and administrative expenses				500,000
El Dorado Predecessor
Related Party Transaction [Line Items]
Operating and maintenance expenses			400,000	1,400,000
General and administrative expenses			100,000	700,000
Logistics Assets Predecessor
Related Party Transaction [Line Items]
Operating and maintenance expenses		200,000	700,000	300,000
General and administrative expenses		0	0	0
Cost of goods sold
Related Party Transaction [Line Items]
Operating and maintenance expenses		105,461,000	56,045,000	80,129,000
Operating Expense [Member]
Related Party Transaction [Line Items]
Operating and maintenance expenses	[2]	$ 31,636,000	$ 20,889,000	$ 16,331,000
[1]	General and administrative expenses include costs allocated to our Predecessors for general and administrative support provided by Delek, including services such as corporate management, risk management, accounting and human resources. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $0.5 million for the year ended December 31, 2013. With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were
[2]	Operating and maintenance expenses include costs allocated to our Predecessors for operating support provided by Delek, including certain labor related costs, property and liability insurance costs and certain other operating expenses. With respect to the Tyler Predecessor, the costs that were allocated to us by Delek were $1.4 million for the year ended December 31, 2013. With respect to the El Dorado Predecessor, the costs that were allocated to us by Delek were $0.4 million and $1.4 million for the years ended December 31, 2014 and

Related Party Transactions Quar

Related Party Transactions Quarterly Cash Distributions Paid (Details) - USD ($) $ in Thousands

Jan. 25, 2016

Nov. 13, 2015

Aug. 14, 2015

May. 14, 2015

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

May. 14, 2014

Feb. 13, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Related Party Transaction [Line Items]

Cash Distributions Paid

$ 15,136

$ 14,368

$ 13,702

$ 13,056

$ 12,394

$ 11,910

$ 10,474

$ 10,228

Delek US and General Partner [Member]

Related Party Transaction [Line Items]

Cash Distributions Paid

$ 35,900

$ 28,100

$ 21,500

Subsequent Event [Member]

Related Party Transaction [Line Items]

Cash Distributions Declared

$ 16,124

Subsequent Event [Member] | Delek US and General Partner [Member]

Related Party Transaction [Line Items]

Cash Distributions Declared

$ 9,700

Net Income Per Unit Textual (De

Net Income Per Unit Textual (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net Income Per Unit [Abstract]
General partner's ownership interest	2.00%	2.00%	2.00%

Net Income Per Unit (Details)

Net Income Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended													12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	[4]	Dec. 31, 2014	[5]	Sep. 30, 2014	[5]	Jun. 30, 2014	[5]	Mar. 31, 2014	[5]	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Net income per unit [Line Items]
Net income attributable to partners															$ 66,848	[1]	$ 71,997	[2],[3]	$ 47,830	[2],[3]
Limited partners' distribution															54,317		45,951		38,491
Earnings in excess of distributions															7,518		24,163		8,554
Limited Partner, Common Units [Member]
Net income per unit [Line Items]
Total earnings															31,160		35,085		23,490
Limited Partner, Subordinated Units [Member]
Net income per unit [Line Items]
Total earnings															30,525		34,546		23,383
General Partner
Net income per unit [Line Items]
Total earnings															$ 5,163		$ 2,366		$ 957
Common Units [Member]
Weighted average limited partner units outstanding:
Common units - (basic)															12,237,154	[1]	12,171,548	[2]	12,025,249	[2]
Common units - (diluted)															12,356,914	[1]	12,302,629	[2]	12,148,774	[2]
Net income per limited partner unit:
Common units - (basic)		$ 0.56	$ 0.71	$ 0.71	$ 0.57		$ 0.81		$ 0.60		$ 0.88		$ 0.60		$ 2.55	[1]	$ 2.88	[2]	$ 1.95	[2]
Common units - (diluted)		$ 0.55	$ 0.70	$ 0.70	$ 0.56		$ 0.80		$ 0.59		$ 0.87		$ 0.59		2.52	[1]	$ 2.85	[2]	$ 1.93	[2]
First target distribution [Member] | Maximum [Member]
Footnote [Abstract]
Distribution Payment Targets															$ 0.43125
General Partner
Net income per unit [Line Items]
Net income attributable to partners															$ 5,163		$ 1,440		$ 957
General partner's distribution	[6]														5,013		1,883		785
Earnings in excess of distributions															150		483		172
Limited Partner [Member] | Common Units [Member]
Net income per unit [Line Items]
Limited partners' distribution															27,439		23,152		19,292
Earnings in excess of distributions															$ 3,721		$ 11,933		$ 4,198
Weighted average limited partner units outstanding:
Common units - (basic)															12,237,154		12,171,548		12,025,249
Common units - (diluted)															12,356,914		12,302,629		12,148,774
Net income per limited partner unit:
Common units - (basic)															$ 2.55		$ 2.88		$ 1.95
Common units - (diluted)															$ 2.52		$ 2.85		$ 1.93
Limited Partner [Member] | Subordinated Units [Member]
Net income per unit [Line Items]
Limited partners' distribution															$ 26,878		$ 22,799		$ 19,199
Earnings in excess of distributions															$ 3,647		$ 11,747		$ 4,184
Weighted average limited partner units outstanding:
Subordinated units - Delek (basic and diluted)															11,999,258		11,999,258		11,999,258
Net income per limited partner unit:
Subordinated units - Delek (basic and diluted)															$ 2.54		$ 2.88		$ 1.95
[1]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[4]	The information presented includes the results of operations of the Logistics Assets Predecessor.
[5]	The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.
[6]	General partner distributions (including IDRs) consist of the 2% general partner interest and IDRs, which represent the right of the general partner to receive increasing percentages of quarterly distributions of available cash from operating surplus in excess of $0.43125 per unit per quarter. See Note 12 for further discussion related to IDRs.

Major Customer (Details)

Major Customer (Details) - Sales Revenue, Net [Member] - Customer Concentration Risk [Member]	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Sunoco [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	16.20%	23.30%	17.70%
Delek [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	25.90%	13.60%	8.60%

Inventory Narrative (Details)

Inventory Narrative (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Inventory [Abstract]
Inventory	$ 10,451	$ 10,316	[1]
[1]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Property, Plant and Equipment72

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 325,647	$ 308,088	[1]
Less: accumulated depreciation	(71,799)	(53,309)	[1]
Property, plant and equipment, net	253,848	254,779	[1]
Depreciation expense	18,629	13,959
Pipelines and Transportation
Property, Plant and Equipment [Line Items]
Property, plant and equipment	266,169	242,490
Less: accumulated depreciation	(50,542)	(36,776)
Property, plant and equipment, net	215,627	205,714
Depreciation expense	15,011	10,712
Wholesale Marketing and Terminalling
Property, Plant and Equipment [Line Items]
Property, plant and equipment	59,478	65,598
Less: accumulated depreciation	(21,257)	(16,533)
Property, plant and equipment, net	38,221	49,065
Depreciation expense	3,618	3,247
Land and land improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	4,253	2,953
Building and building improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,886	1,169
Pipelines, tanks and terminals
Property, Plant and Equipment [Line Items]
Property, plant and equipment	299,101	268,339
Asset retirement obligation assets
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,073	2,073
Other equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	4,270	3,764
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 14,064	$ 29,790
[1]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Goodwill Narrative (Details)

Goodwill Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Abstract]
Goodwill, Impairment Loss	$ 0	$ 0	$ 0

Goodwill (Details)

Goodwill (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2013
Goodwill [Roll Forward]
Beginning Balance	$ 11,654	[1]	$ 10,454
Acquisitions	549		1,200
Ending Balance	12,203		11,654
Wholesale Marketing and Terminalling
Goodwill [Roll Forward]
Beginning Balance	7,499		7,499
Acquisitions	0		0
Ending Balance	7,499		7,499
Pipelines and Transportation
Goodwill [Roll Forward]
Beginning Balance	4,155		2,955
Acquisitions	549		1,200
Ending Balance	$ 4,704		$ 4,155
[1]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Other Intangibles (Details)

Other Intangibles (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Other Intangible Assets [Line Items]
Accumulated Amortization	$ (10,012)	$ (8,949)
Intangible assets, gross	25,494	25,469
Intangible assets, net	15,482	16,520	[1]
Rights-of-Way [Member]
Other Intangible Assets [Line Items]
Rights-of-way assets	$ 13,267	$ 13,242
Supply contracts [Member]
Other Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months	11 years 6 months
Intangible Assets, Gross	$ 12,227	$ 12,227
Accumulated Amortization	(10,012)	(8,949)
Intangible assets, net	2,215	3,278
Amortization expense	1,100	$ 1,100		$ 1,100
Amortization Expense, 2016	1,100
Amortization Expense, 2017	1,100
Amortization Expense, 2018	$ 100
[1]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Long-Term Obligations and Sho76

Long-Term Obligations and Short-Term Note Payable Long Term Obligations (Details) - Revolving Credit Facility [Member] - Fifth Third Bank [Member] - USD ($) $ in Thousands	Dec. 30, 2014	Dec. 31, 2015	Jul. 09, 2013
Line of Credit [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity	$ 700,000		$ 400,000
Maximum Borrowing Capacity under Accordion Feature	$ 800,000
Weighted Average Interest Rate		2.80%
Unused Capacity, Commitment Fee Percentage		0.40%
Holdings Note outstanding amount		$ 102,000
Line of Credit Facility, Amount Outstanding		351,600
Available borrowing capacity		346,900
Letter of Credit [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding		0
Letters of Credit		$ 1,500
United States of America, Dollars | Prime Rate [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	U.S. dollar prime rate
United States of America, Dollars | London Interbank Offered Rate (LIBOR) [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	London Interbank Offered Rate
Canada, Dollars | Canadian prime rate [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	Canadian dollar prime rate
Canada, Dollars | Canadian Dealer Offered Rate (CDOR) [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	Canadian Dealer Offered Rate

Long-Term Obligations and Sho77

Long-Term Obligations and Short-Term Note Payable Maturities of Long-term debt (Details) $ in Thousands	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
2,016	$ 0
2,017	0
2,018	0
2,019	351,600
2,020	0
Thereafter	0
Revolving Credit Facility [Member] | Fifth Third Bank [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Total	$ 351,600

Equity (Details)

Equity (Details) - shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Limited Partners' Capital Account [Line Items]
Delek's Limited Parter Interest	59.70%
General partner's ownership interest	2.00%	2.00%	2.00%
General Partner's units	495,445	494,197
Common - Public
Limited Partners' Capital Account [Line Items]
Limited Partners' Capital Account, Units Outstanding	9,478,273	9,417,189
Common - Delek
Limited Partners' Capital Account [Line Items]
Limited Partners' Capital Account, Units Outstanding	2,799,258	2,799,258
Subordinated Units [Member]
Limited Partners' Capital Account [Line Items]
Limited Partners' Capital Account, Units Outstanding	11,999,258
Delek US [Member]
Limited Partners' Capital Account [Line Items]
Delek's ownership interest in General Partner	95.40%
Other Affiliates [Member]
Limited Partners' Capital Account [Line Items]
Delek's ownership interest in General Partner	4.60%

Equity Units Rollforward (Detai

Equity Units Rollforward (Details) - shares		1 Months Ended	12 Months Ended
		Nov. 30, 2012	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Partners' Capital [Roll Forward]
Units issued in the Offering in November 2012		24,488,282
Balance			24,709,902	24,644,649	24,488,282
GP units issued to maintain 2% interest			1,248	1,304	3,127
Unit-based compensation awards	[1]		61,084	63,949	153,240
Balance			24,772,234	24,709,902	24,644,649
Footnote [Abstract]
Units withheld for taxes			21,144	5,539	31,083
Common - Public
Increase (Decrease) in Partners' Capital [Roll Forward]
Units issued in the Offering in November 2012		9,200,000
Balance			9,417,189	9,353,240	9,200,000
GP units issued to maintain 2% interest			0	0	0
Unit-based compensation awards	[1]		61,084	63,949	153,240
Balance			9,478,273	9,417,189	9,353,240
Common - Delek
Increase (Decrease) in Partners' Capital [Roll Forward]
Units issued in the Offering in November 2012		2,799,258
Balance			2,799,258	2,799,258	2,799,258
GP units issued to maintain 2% interest			0	0	0
Unit-based compensation awards	[1]		0	0	0
Balance			2,799,258	2,799,258	2,799,258
Subordinated
Increase (Decrease) in Partners' Capital [Roll Forward]
Units issued in the Offering in November 2012		11,999,258
Balance			11,999,258	11,999,258	11,999,258
GP units issued to maintain 2% interest			0	0	0
Unit-based compensation awards	[1]		0	0	0
Balance			11,999,258	11,999,258	11,999,258
General Partner
Increase (Decrease) in Partners' Capital [Roll Forward]
Units issued in the Offering in November 2012		489,766
Balance			494,197	492,893	489,766
GP units issued to maintain 2% interest			1,248	1,304	3,127
Unit-based compensation awards	[1]		0	0	0
Balance			495,445	494,197	492,893
[1]	Unit-based compensation awards are presented net of 21,144, 5,539 and 31,083 units withheld for taxes as of December 31, 2015, 2014 and 2013, respectively.

Equity Net income applicable to

Equity Net income applicable to partners (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Equity [Abstract]
Net income attributable to partners	$ 66,848	[1]	$ 71,997	[2],[3]	$ 47,830	[2],[3]
Less: General partner's IDRs	(3,904)		(945)		0
Net income available to partners	$ 62,944		$ 71,052		$ 47,830
General partner's ownership interest	2.00%		2.00%		2.00%
General partner's allocated interest in net income	$ 1,259		$ 1,421		$ 957
General partner's IDRs	3,904		945		0
Total general partner's interest in net income	$ 5,163	[1]	$ 2,366	[2]	$ 957	[2]
[1]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.

Equity Percentage Allocations o

Equity Percentage Allocations of Available Cash from Operating Surplus (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Incentive Distribution Made to Member or Limited Partner [Line Items]
General partner's ownership interest	2.00%	2.00%	2.00%
Minimum quarterly distribution [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.37500
Minimum quarterly distribution [Member] | Limited Partner [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	98.00%
Minimum quarterly distribution [Member] | General Partner
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	2.00%
First target distribution [Member] | Limited Partner [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	98.00%
First target distribution [Member] | General Partner
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	2.00%
First target distribution [Member] | Minimum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.37500
First target distribution [Member] | Maximum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.43125
Second target distribution [Member] | Limited Partner [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	85.00%
Second target distribution [Member] | General Partner
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	15.00%
Second target distribution [Member] | Minimum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.43125
Second target distribution [Member] | Maximum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.46875
Third target distribution [Member] | Limited Partner [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	75.00%
Third target distribution [Member] | General Partner
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	25.00%
Third target distribution [Member] | Minimum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.46875
Third target distribution [Member] | Maximum [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	0.56250
Thereafter [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	$ 0.56250
Thereafter [Member] | Limited Partner [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	50.00%
Thereafter [Member] | General Partner
Incentive Distribution Made to Member or Limited Partner [Line Items]
Marginal percentage interest in distributions	50.00%

Equity Cash distributions (Deta

Equity Cash distributions (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 25, 2016	Nov. 13, 2015	Aug. 14, 2015	May. 14, 2015	Feb. 13, 2015	Nov. 14, 2014	Aug. 14, 2014	May. 14, 2014	Feb. 13, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Distribution Made to Limited Partner [Line Items]
Quarterly cash distribution (dollars per unit)		$ 0.570	$ 0.550	$ 0.530	$ 0.510	$ 0.490	$ 0.475	$ 0.425	$ 0.415
Distribution Made To Member Or Limited Partner Distributions Paid Annualized Per Unit		$ 2.28	$ 2.20	$ 2.12	$ 2.04	$ 1.96	$ 1.90	$ 1.70	$ 1.66
Cash Distributions Paid		$ 15,136	$ 14,368	$ 13,702	$ 13,056	$ 12,394	$ 11,910	$ 10,474	$ 10,228
General partner's distributions										$ 1,109	$ 938	$ 785
General partner's IDRs										3,904	945	0
Total general partner's distributions										5,013	1,883	785
Limited partners' distribution										54,317	45,951	38,491
Total cash distributions										$ 59,330	$ 47,834	$ 39,276
Cash distributions per limited partner unit										$ 2.240	$ 1.900	$ 1.600
Subsequent Event [Member]
Distribution Made to Limited Partner [Line Items]
Cash Distributions Declared	$ 16,124
Cash distributions per limited partner unit	$ 0.590
Distribution Made To Limited Partner Distributions Declared Annualized Per Unit	$ 2.36
Limited Partner [Member] | Common
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution										$ 27,439	$ 23,152	$ 19,292
Limited Partner [Member] | Subordinated
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution										$ 26,878	$ 22,799	$ 19,199

Equity Based Compensation Narra

Equity Based Compensation Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Number of units authorized	612,207
Total fair value of vested units	$ 1.9	$ 1.6	$ 4.2
Unrecognized compensation costs	$ 1
Unrecognized compensation costs, weighted-average period for recognition	1 year 10 months
Selling, General and Administrative Expenses [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Unit-based compensation expense	$ 0.4	$ 0.3	$ 0.5
Pre-June 9, 2015 [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Awards requisite service period (years)	5 years
Post June 10, 2015 [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Awards requisite service period (years)	3 years

Equity Based Compensation Unit

Equity Based Compensation Unit Award Activity Summary (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Unit Award Activity [Roll Forward]
Non-vested, number of phantom units, beginning of year (shares)	215,464	274,952	494,883
Granted, number of phantom units (shares)	11,836	10,000	7,500
Vested, number of phantom units (shares)	(82,228)	(69,488)	(184,323)
Forfeited, number of phantom unit (shares)			(43,108)
Non-vested, number of phantom units, end of year (shares)	145,072	215,464	274,952
Unit award activity, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested, weighted-average grant price, beginning of year (usd per share)	$ 23.48	$ 22.94	$ 22.65
Granted, weighted-average grant price (usd per share)	39.73	35.46	34.12
Vested, weighted average grant price (usd per share)	23.55	23.08	22.68
Forfeited, weighted average grant price (usd per share)			22.65
Non-vested, weighted-average grant price, end of year (usd per share)	$ 24.76	$ 23.48	$ 22.94

Equity Method Investments (Deta

Equity Method Investments (Details) - USD ($) $ in Millions	Dec. 31, 2015	Mar. 31, 2015
Schedule of Equity Method Investments [Line Items]
Other Commitment	$ 96
Equity Method Investment, Aggregate Cost	$ 41.3
CP LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%
Equity Method Investment, Ownership Percentage by Other Investor		50.00%
Rangeland Rio [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		33.00%
Equity Method Investment, Ownership Percentage by Other Investor		67.00%

Equity Method Investments Summa

Equity Method Investments Summarized Financial Information (Details) - Alon USA Energy, Inc. [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Current Assets	$ 11,705
Noncurrent Assets	87,467
Current liabilities	4,797
Noncurrent liabilities	0
Revenues	0
Gross profit	0
Net loss	$ (1,967)

Segment Data (Details)

Segment Data (Details) - USD ($) $ in Thousands		3 Months Ended													12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	[4]	Dec. 31, 2014		Sep. 30, 2014	[5]	Jun. 30, 2014	[5]	Mar. 31, 2014	[5]	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Segment Reporting Information [Line Items]
Affiliate	[1]														$ 152,564	[2]	$ 114,583	[3]	$ 78,173	[3]
Third Party															437,105	[2]	726,670	[3]	829,255	[3]
Total Pipelines and Transportation		$ 108,931	$ 165,092	$ 172,134	$ 143,512		$ 173,347	[5]	$ 228,036		$ 236,343		$ 203,527		589,669	[2]	841,253	[3],[6]	907,428	[3],[6]
Operating costs and expenses:
Cost of goods sold															436,304	[2]	697,221	[3],[6]	811,364	[3],[6]
Operating expenses	[7],[8]														44,923	[2]	39,465	[3],[6]	35,903	[3],[6]
Segment Contribution Margin															108,442		104,567		60,161
General and administrative expenses															11,384	[2]	10,616	[3],[6]	7,526	[3],[6]
Depreciation and amortization															19,692	[2],[9]	15,022	[3],[6],[10]	13,738	[3],[6],[10]
Loss on asset disposals															104	[2],[9]	83	[3],[6],[10]	166	[3],[6],[10]
Operating income		17,862	$ 21,847	$ 21,139	$ 16,414		21,811	[5]	$ 17,242		$ 24,111		$ 15,682		77,262	[2]	78,846	[3],[6]	38,731	[3],[6]
Capital spending (excluding business combinations)	[7],[8]														22,427		9,168		25,737
Total assets		375,288					331,286	[11],[12]							375,288		331,286	[11],[12]
Pipelines and Transportation
Segment Reporting Information [Line Items]
Affiliate															102,551		80,683		51,878
Third Party															28,828		10,665		8,359
Total Pipelines and Transportation															131,379		91,348		60,237
Operating costs and expenses:
Cost of goods sold															19,607		4,294		764
Operating expenses	[7],[8]														33,751		31,979		27,728
Segment Contribution Margin															78,021		55,075		31,745
Capital spending (excluding business combinations)	[7],[8]														16,030		5,804		22,696
Total assets		283,553					230,293	[11]							283,553		230,293	[11]
Wholesale Marketing and Terminalling
Segment Reporting Information [Line Items]
Affiliate															50,013		33,900		26,295
Third Party															408,277		716,005		820,896
Total Pipelines and Transportation															458,290		749,905		847,191
Operating costs and expenses:
Cost of goods sold															416,697		692,927		810,600
Operating expenses															11,172		7,486		8,175
Segment Contribution Margin															30,421		49,492		28,416
Capital spending (excluding business combinations)															6,397		3,364		$ 3,041
Total assets		$ 91,735					$ 100,993	[11]							$ 91,735		$ 100,993	[11]
[1]	See Note 4 for a description of our affiliate revenue transactions.
[2]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	The information presented includes the results of operations of the Logistics Assets Predecessor.
[5]	The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.
[6]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[7]	Adjusted to include operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.
[8]	Includes operating expenses and capital spending expenditures incurred in connection with the El Dorado Offloading Racks Acquisition and the Tyler Crude Tank Acquisition for the year ended December 31, 2015.
[9]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[10]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[11]	Adjusted to include the historical balances of the Logistics Assets Predecessor.
[12]	Adjusted to include the historical balances of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral	$ 800	$ 0
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	171	480
Net assets	126	419
Fair Value, Measurements, Recurring [Member] | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	0	0
Net assets	0	0
Fair Value, Measurements, Recurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	171	480
Net assets	126	419
Fair Value, Measurements, Recurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	0	0
Net assets	0	0
Fair Value, Measurements, Recurring [Member] | Interest rate derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	24
Fair Value, Measurements, Recurring [Member] | Interest rate derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Fair Value, Measurements, Recurring [Member] | Interest rate derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0
Fair Value, Measurements, Recurring [Member] | Interest rate derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Fair Value, Measurements, Recurring [Member] | OTC commodity swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	171	456
Derivative Liability	(45)	(61)
Fair Value, Measurements, Recurring [Member] | OTC commodity swaps | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Derivative Liability	0	0
Fair Value, Measurements, Recurring [Member] | OTC commodity swaps | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	171
Derivative Liability	(45)
Fair Value, Measurements, Recurring [Member] | OTC commodity swaps | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	0	0
Derivative Liability	0	$ 0
Other Noncurrent Assets [Member] | Derivatives not designated as hedging instrument [Member] | Fair Value, Measurements, Recurring [Member] | Interest rate derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	24
Other Current Assets [Member] | Derivatives not designated as hedging instrument [Member] | Fair Value, Measurements, Recurring [Member] | OTC commodity swaps | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	456
Derivative Liability	$ (61)

Derivative Instruments Narrativ

Derivative Instruments Narrative (Details) $ in Millions	Feb. 25, 2013USD ($)
Derivative Instruments [Abstract]
Derivative, Notional Amount	$ 45

Derivative Instruments (Details

Derivative Instruments (Details) $ in Thousands		Dec. 31, 2015USD ($)bbl	Dec. 31, 2014USD ($)bbl
Footnote [Abstract]
Cash collateral		$ 800	$ 0
Derivatives not designated as hedging instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Assets		171	480
Liabilities		(45)	(61)
Less: Counterparty netting and cash collateral, Assets	[1]	(706)	61
Less: Counterparty netting and cash collateral, Liabilities	[1]	(45)	(61)
Total net fair value of derivative, Assets		877	419
Total net fair value of derivative, Liabilities		$ 0	$ 0
Footnote [Abstract]
Open derivative contracts (barrels) | bbl		171,000	142,000
Other long term assets | Derivatives not designated as hedging instrument [Member] | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Assets		$ 0	$ 24
Liabilities		0	0
Other current assets | Derivatives not designated as hedging instrument [Member] | OTC commodity swaps
Derivative Instruments, Gain (Loss) [Line Items]
Assets	[2]	171	456
Liabilities	[2]	$ (45)	$ (61)
[1]	As of December 31, 2015, $0.8 million of cash collateral was held by counterparty brokerage firms and has been netted with the net derivative positions with each counterparty. As of December 31, 2014, no cash collateral was held by counterparty brokerage firms.
[2]	As of December 31, 2015, we had open derivative contracts representing 171,000 barrels of refined petroleum products. As of December 31, 2014, we had 142,000 open derivative contracts.

Derivative Instruments Income S

Derivative Instruments Income Statement Location (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 417	$ 2,991	$ (720)
Interest Rate Contract [Member] | Interest expense | Derivatives not designated as hedging instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	(24)	(92)	(106)
OTC commodity swaps | Cost of goods sold | Derivatives not designated as hedging instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 441	$ 3,083	$ (614)

Income Taxes Narrative (Details

Income Taxes Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Deferred Tax Assets, Gross, Noncurrent	$ 100,000
Deferred Tax Liabilities, Gross, Noncurrent		$ 200,000
Uncertain tax positions	0	0	$ 0
Uncertain tax positions, Income Tax Penalties and Interest Expense	0	0	$ 0
Accounts payable [Member]
Income taxes (receivable) payable	$ (200,000)	$ (600,000)

Income Taxes Reconciliation of

Income Taxes Reconciliation of Actual Income Tax Expense to Statutory (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Income Tax Disclosure [Abstract]
State income taxes	$ 171		$ 492		$ 794
Other items	(366)		(360)		(37)
Income tax (benefit) expense	$ (195)	[1]	$ 132	[2],[3]	$ 757	[2],[3]
[1]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.

Income Taxes Components of Inco

Income Taxes Components of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Income Tax Disclosure [Abstract]
Current	$ (209)		$ 241		$ 448
Deferred	14	[1]	(109)	[2]	309	[2]
Total	$ (195)	[3]	$ 132	[4],[5]	$ 757	[4],[5]
[1]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[3]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[5]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.

Commitments and Contingencies C

Commitments and Contingencies Crude Oil Releases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Apr. 28, 2015bbl	Apr. 30, 2014bbl	Oct. 31, 2013bbl	Mar. 31, 2013bbl
Loss Contingencies [Line Items]
Environmental Remediation Expense		$ 1	$ 0.6
Haynesville Crude Oil Release [Member]
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl					400
Accrual for Environmental Loss Contingencies	$ 0.2
Environmental Remediation Expense		1	$ 0.3
Maximum Exposure for Environmental Remediation under Omnibus Agreement	1
Magnolia Station Spill [Member]
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl							5,900
Accrual for Environmental Loss Contingencies	1
Maximum Exposure for Environmental Remediation under Omnibus Agreement	0.3
Fouke Junction Crude Oil Release [Member]
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl				130
Accrual for Environmental Loss Contingencies	0.1
Macedonia Crude Oil Release [Member]
Loss Contingencies [Line Items]
Barrels of crude oil released | bbl						50
Maximum Exposure for Environmental Remediation under Omnibus Agreement	0.3
Operating Expense [Member] | Macedonia Crude Oil Release [Member]
Loss Contingencies [Line Items]
Cost incurred for environmental remediation	$ 0	$ 0.3

Commitments and Contingencies96

Commitments and Contingencies Contracts and Agreements (Details)	12 Months Ended
	Dec. 31, 2015bbl / pure
Abilene Contract [Member] | Inventories [Member]
Long-term Purchase Commitment [Line Items]
Maximum Purchases under Supply Contract	20,350

Commitments and Contingencies L

Commitments and Contingencies Letters of Credit (Details) - Fifth Third Bank [Member] - Letter of Credit [Member] - Revolving Credit Facility [Member] $ in Millions	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Letters of Credit	$ 1.5
Line of Credit Facility, Amount Outstanding	$ 0

Commitments and Contingencies O

Commitments and Contingencies Operating Leases (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]
Operating Leases, Rent Expense	$ 1,100	$ 700	$ 700
2,016	4,991
2,017	4,893
2,018	2,184
2,019	253
2,020	189
Thereafter	9
Total future minimum rentals	$ 12,519

Selected Quarterly Financial 99

Selected Quarterly Financial Data (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended													12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	[1]	Dec. 31, 2014	[2]	Sep. 30, 2014	[2]	Jun. 30, 2014	[2]	Mar. 31, 2014	[2]	Dec. 31, 2015	[3]	Dec. 31, 2014	[4]	Dec. 31, 2013	[4]
Selected Quarterly Financial Information [Abstract]
Net sales	$ 108,931	$ 165,092	$ 172,134	$ 143,512		$ 173,347		$ 228,036		$ 236,343		$ 203,527		$ 589,669		$ 841,253	[5]	$ 907,428	[5]
Operating income	17,862	21,847	21,139	16,414		21,811		17,242		24,111		15,682		77,262		78,846	[5]	38,731	[5]
Net income	15,295	18,602	18,311	14,003		20,179		14,839		21,488		13,552		66,211	[6]	70,058	[7]	33,404	[7]
Limited partners' interest in net income	$ 13,511	$ 17,219	$ 17,202	$ 13,753		$ 19,631		$ 14,487		$ 21,134		$ 14,379		$ 61,685		$ 69,631		$ 46,873
Common Units [Member]
Common (basic)	$ 0.56	$ 0.71	$ 0.71	$ 0.57		$ 0.81		$ 0.60		$ 0.88		$ 0.60		$ 2.55		$ 2.88		$ 1.95
Common units - (diluted)	0.55	0.70	0.70	0.56		0.80		0.59		0.87		0.59		2.52		2.85		1.93
Subordinated- Delek
Subordinated units - Delek (basic and diluted)	$ 0.56	$ 0.71	$ 0.71	$ 0.57		$ 0.81		$ 0.60		$ 0.87		$ 0.60		$ 2.54		$ 2.88		$ 1.95
[1]	The information presented includes the results of operations of the Logistics Assets Predecessor.
[2]	The information presented has been adjusted to include the results of operations of the Logistics Assets Predecessor.
[3]	The information presented includes the results of operations of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[4]	Adjusted to include the historical results of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[5]	There were no expenses associated with the Tyler Assets Predecessor included in our consolidated financial statements for the years ended December 31, 2014 and 2013, as the Tyler Assets were not fully constructed and were not placed into service until January 2015. Additionally, prior to the Tyler Crude Tank Acquisition, the Tyler Assets Predecessor did not record revenues for intercompany storage services.
[6]	Includes the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.
[7]	Adjusted to include the historical cash flows of the Logistics Assets Predecessor. See Notes 1 and 3 for further discussion.

Subsequent Events (Details)

Subsequent Events (Details) - $ / shares

Jan. 25, 2016

Nov. 13, 2015

Aug. 14, 2015

May. 14, 2015

Feb. 13, 2015

Nov. 14, 2014

Aug. 14, 2014

May. 14, 2014

Feb. 13, 2014

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2013

Subsequent Event [Line Items]

Quarterly cash distribution declared (dollars per unit)

$ 2.240

$ 1.900

$ 1.600

Limited Partners' Capital Account, Units Outstanding

$ 0.570

$ 0.550

$ 0.530

$ 0.510

$ 0.490

$ 0.475

$ 0.425

$ 0.415

Subsequent Event [Member]

Subsequent Event [Line Items]

Quarterly cash distribution declared (dollars per unit)

$ 0.590