Delek Logistics Partners (DKL) 10-K 26 Feb 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information Document (USD $)	12 Months Ended
	Dec. 31, 2014	Jun. 30, 2014	Feb. 20, 2015
Entity Information [Line Items]
Entity Registrant Name	Delek Logistics Partners, LP
Entity Central Index Key	1552797
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Document Type	10-K
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
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		$324,422,161
Common Units [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding			12,216,447
Subordinated Units [Member]
Entity Information [Line Items]
Common Stock, Shares, Outstanding			11,999,258
General Partner
Entity Information [Line Items]
Common Stock, Shares, Outstanding			494,197

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$1,861	$924	[1],[2]
Accounts receivable	27,956	28,976	[2]
Inventory	10,316	17,512	[2]
Deferred tax assets	28	12	[2]
Other current assets	768	341	[2]
Total current assets	40,929	47,765	[2]
Property, plant and equipment:
Property, plant and equipment	293,525	264,072	[2]
Less: accumulated depreciation	-52,992	-39,566	[2]
Property, plant and equipment, net	240,533	224,506	[2]
Goodwill	11,654	11,654	[2]
Intangible assets, net	11,349	12,374	[2]
Other non-current assets	7,374	5,045	[2]
Total assets	311,839	301,344	[2]
Current liabilities:
Accounts payable	18,208	26,045	[2]
Accounts payable to related parties	628	1,513	[2]
Excise and other taxes payable	5,443	5,700	[2]
Accrued expenses and other current liabilities	1,588	4,732	[2]
Tank inspection liabilities	2,829	1,719	[2]
Pipeline release liabilities	1,899	0	[2]
Total current liabilities	30,595	39,709	[2]
Non-current liabilities:
Revolving credit facility	251,750	164,800	[2]
Asset retirement obligations	3,319	3,087	[2]
Deferred tax liabilities	231	324	[2]
Other non-current liabilities	5,889	6,222	[2]
Total non-current liabilities	261,189	174,433	[2]
Equity:
Total equity	20,055	87,202	[2]
Total liabilities and equity	311,839	301,344	[2]
Predecessor division equity
Equity:
Total equity	0	25,161	[2]
General partner - Delek; 494,197 units issued and outstanding at December 31, 2014 (492,893 at December 31, 2013)
Equity:
Total equity	-7,085	-4,504	[2]
Common unitholders - public; 9,417,189 units issued and outstanding at December 31, 2014 (9,353,240 at December 31, 2013) | Limited Partner [Member]
Equity:
Total equity	194,737	183,839	[2]
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2014 (2,799,258 at December 31, 2013) | Limited Partner [Member]
Equity:
Total equity	-241,112	-176,680	[2]
Subordinated unitholders - Delek; 11,999,258 units issued and outstanding at December 31, 2014 (11,999,258 at December 31, 2013) | Limited Partner [Member]
Equity:
Total equity	$73,515	$59,386	[2]
[1]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parentheticals)	Dec. 31, 2014	Dec. 31, 2013
General Partners' Capital Account, Units Issued	494,197	492,893
General Partners' Capital Account, Units Outstanding	494,197	492,893
Common - Public
Limited Partners' Capital Account, Units Issued	9,417,189	9,353,240
Limited Partners' Capital Account, Units Outstanding	9,417,189	9,353,240
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_Inc

Consolidated Statements of Income and Comprehensive Income (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Net Sales:
Affiliate	$114,583	[1],[2]	$78,173	[1],[2],[3]	$43,614	[3],[4],[5]
Third Party	726,670	[1],[2]	829,255	[1],[2],[3]	978,972	[3],[4],[5]
Net sales	841,253	[4],[5]	907,428	[1],[2],[3]	1,022,586	[1],[2],[3]
Operating costs and expenses:
Cost of goods sold	697,221	[4],[5]	811,364	[1],[2],[3]	959,434	[1],[2],[3]
Operating expenses	38,786	[4],[5]	35,640	[1],[2],[3]	39,420	[1],[2],[3]
General and administrative expenses	10,616	[4],[5]	7,526	[1],[2],[3]	9,856	[1],[2],[3]
Depreciation and amortization	14,705	[4],[5]	13,738	[1],[2],[3],[6]	11,343	[1],[2],[3],[6]
Loss on asset disposals	83	[4],[5]	166	[1],[2],[3],[6]	9	[1],[2],[3],[6]
Total operating costs and expenses	761,411	[3]	868,434	[3]	1,020,062	[3]
Operating income	79,842	[3],[4],[5]	38,994	[1],[2],[3]	2,524	[1],[2],[3]
Interest expense, net	8,656		4,570	[3]	2,682	[3]
Income (loss) before income tax expense (benefit)	71,186		34,424	[3]	-158	[3]
Income tax expense (benefit)	132		757	[3]	-14,024	[3]
Net income	71,054		33,667	[3],[6]	13,866	[3],[6]
Less: (loss) income attributable to Predecessors	-943		-14,163	[3]	5,456	[3]
Net income attributable to partners	71,997	[3]	47,830	[3]	8,410	[3]
Comprehensive income attributable to partners	71,997		47,830	[3]	8,410	[3]
Less: General partner's interest in net income, including incentive distribution rights	-2,366		-957	[3]	-168	[3]
Limited partners' interest in net income	$69,631		$46,873	[3]	$8,242	[3]
Net income per limited partner unit:
Common units - (basic)	$2.88		$1.95		$0.34
Common units - (diluted)	$2.85		$1.93		$0.34
Weighted average limited partner units outstanding:
Common units - (basic)	12,171,548		12,025,249		11,999,258
Common units - (diluted)	12,302,629		12,148,774		11,999,258
Subordinated units - Delek (basic and diluted)	11,999,258		11,999,258		11,999,258
Cash distributions per limited partner unit	$1.90		$1.60	[3]	$0.22	[3]
Common Units [Member]
Net income per limited partner unit:
Common units - (basic)	$2.88		$1.95	[3]	$0.34	[3]
Common units - (diluted)	$2.85		$1.93	[3]	$0.34	[3]
Weighted average limited partner units outstanding:
Common units - (basic)	12,171,548		12,025,249	[3]	11,999,258	[3]
Common units - (diluted)	12,302,629		12,148,774	[3]	11,999,258	[3]
Subordinated- Delek
Net income per limited partner unit:
Subordinated units - Delek (basic and diluted)	$2.88		$1.95	[3]	$0.34	[3]
Weighted average limited partner units outstanding:
Subordinated units - Delek (basic and diluted)	11,999,258		11,999,258	[3]	11,999,258	[3]
[1]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
[2]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[3]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[4]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[5]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
[6]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Consolidated_Statements_of_Par

Consolidated Statements of Partners' Equity (USD $)		Total		Equity of Predecessors	General Partner	Subordinated- Delek	Common - Delek	Common - Public	El Dorado Terminal and Tanks [Member]	Tyler Terminal and Tanks [Member]
						Limited Partner [Member]	Limited Partner [Member]	Limited Partner [Member]
Beginning balance at Dec. 31, 2011		$148,324,000		$148,324,000	$0	$0	$0	$0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Contribution of equity to the Sponsor		-9,430,000		-9,430,000
Income (loss) attributable to Predecessors		5,456,000	[1]	5,456,000
Allocation of net assets contributed to the unitholders		0		-87,090,000	49,891,000	48,753,000	-11,554,000	0
Equity offering, net of issuance costs		175,459,000		0	0	0	0	175,459,000
Cash distributions		-166,535,000		0	-50,000,000	0	-116,535,000	0
Net income attributable to partners		8,410,000	[1]	0	168,000	4,122,000	960,000	3,160,000
Other		118,000		117,000	-108,000	0	0	109,000
Ending balance at Dec. 31, 2012		161,802,000		57,377,000	-49,000	52,875,000	-127,129,000	178,728,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Sponsor contributions of equity to the Predecessor		20,001,000		20,001,000
Income (loss) attributable to Predecessors		-14,163,000	[1]	-14,163,000
Liabilities not assumed by the Partnership		213,000		213,000
Allocation of net assets contributed to the unitholders		0		-38,267,000	765,000	0	37,502,000	0
Cash distributions	[2]	-129,564,000		0	-2,586,000	-16,907,000	-96,848,000	-13,223,000
Sponsorship contribution of fixed assets		520,000		0	10,000	0	510,000	0
Net income attributable to partners		47,830,000	[1]	0	957,000	23,383,000	5,455,000	18,035,000
Unit-based compensation		464,000		0	-3,699,000	0	3,822,000	341,000
Other		99,000		0	98,000	35,000	8,000	-42,000
Footnote [Abstract]
Cash payments for acquisitions									95,900,000
Decrease in equity balance due to acquisitions										56,500,000
Distribution equivalents on vested phantom units		200,000
Ending balance at Dec. 31, 2013	[3]	87,202,000		25,161,000	-4,504,000	59,386,000	-176,680,000	183,839,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Sponsor contributions of equity to the Predecessor		1,006,000		1,006,000	0	0	0	0
Income (loss) attributable to Predecessors		-943,000		-943,000	0	0	0	0
Allocation of net assets contributed to the unitholders		0		-25,224,000	504,000	0	24,720,000	0
Cash distributions	[4]	-141,092,000		0	-3,300,000	-21,658,000	-99,035,000	-17,099,000
Sponsorship contribution of fixed assets		1,566,000		0	32,000	0	1,534,000	0
Net income attributable to partners		71,997,000	[1]	0	1,440,000	35,005,000	8,166,000	27,386,000
Unit-based compensation		274,000		0	-1,302,000	782,000	183,000	611,000
Other		45,000		0	45,000	0	0	0
Footnote [Abstract]
Cash payments for acquisitions										94,800,000
Decrease in equity balance due to acquisitions									70,700,000
Distribution equivalents on vested phantom units		200,000
Ending balance at Dec. 31, 2014		$20,055,000		$0	($7,085,000)	$73,515,000	($241,112,000)	$194,737,000
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	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.
[3]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[4]	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.

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Net income	$71,054		$33,667	[1],[2]	$13,866	[1],[2]
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	14,705	[3],[4]	13,738	[1],[2],[5],[6]	11,343	[1],[2],[5],[6]
Amortization of unfavorable contract liability to revenue	-2,670		-2,623	[1]	-668	[1]
Amortization of deferred financing costs	1,267		1,007	[1]	381	[1]
Accretion of asset retirement obligations	232		224	[1]	194	[1]
Loss on asset disposals	83	[3],[4]	166	[1],[2],[5],[6]	9	[1],[2],[5],[6]
Deferred income taxes	-109		309	[1]	-18,762	[1]
Share-based compensation expense	0		0	[1]	92	[1]
Unit-based compensation expense	274		464	[1]	1	[1]
Changes in assets and liabilities, net of acquisitions:
Accounts receivable	2,892		-1,251	[1]	-5,148	[1]
Inventories and other current assets	7,894		-3,333	[1]	4,917	[1]
Accounts payable and other current liabilities	-6,960		7,472	[1]	-4,401	[1]
Accounts payable - related parties	-885		-8,635	[1]	15,766	[1]
Non-current assets and liabilities, net	-1,857		-4,234	[1]	-478	[1]
Net cash provided by operating activities	85,920		36,971	[1]	17,112	[1]
Cash flows from investing activities:
Business combinations	-22,650		-10,737	[1]	-23,272	[1]
Purchases of property, plant and equipment	-7,132	[3],[4]	-12,662	[1],[5],[6]	-30,816	[1],[5],[6]
Proceeds from sales of property, plant and equipment	0		0	[1]	21	[1]
Net cash used in investing activities	-29,782		-23,399	[1]	-54,067	[1]
Cash flows from financing activities:
Proceeds from issuance of common units, net of underwriters' discount	0		0	[1]	179,676	[1]
Proceeds from issuance of additional units to maintain 2% General Partner interest	45		99	[1]	0	[1]
Distributions to general partner	-1,382		-690	[1]	-50,000	[1]
Distributions to common unitholders - Public	-17,099		-13,223	[1]	0	[1]
Distributions to common unitholders - Delek	-5,053		-3,944	[1]	-116,535	[1]
Distributions to subordinated unitholders	-21,658		-16,907	[1]	0	[1]
Distributions to Delek for contribution of El Dorado Terminal and Tank Assets	-95,900		-94,800	[1]	0	[1]
Proceeds from revolving credit facility	499,750		206,300	[1]	351,900	[1]
Payments of revolving credit facility	-412,800		-131,500	[1]	-292,200	[1]
Tax benefit from exercise of equity-based compensation	0		0	[1]	25	[1]
Offering costs	0		0	[1]	-4,217	[1]
Deferred financing costs paid	-3,688		-2,273	[1]	-3,821	[1]
Predecessor division equity contribution (distribution)	1,006		20,001	[1]	-8,954	[1]
Reimbursement of capital expenditures by Sponsor	1,578		837	[1]	4,498	[1]
Net cash used in financing activities	-55,201		-36,100	[1]	60,372	[1]
Net increase (decrease) in cash and cash equivalents	937		-22,528	[1]	23,417	[1]
Cash and cash equivalents at the beginning of the period	924	[1],[7]	23,452	[1]	35	[1]
Cash and cash equivalents at the end of the period	1,861		924	[1],[7]	23,452	[1]
Cash paid during the period for:
Interest	7,661		3,242	[1]	2,006	[1]
Taxes	18		30	[1]	1,316	[1]
Non-cash financing activities:
Working capital retained by Sponsor	0		213	[1]	63,847	[1]
Sponsor contribution of fixed assets	$1,566		$520	[1]	$476	[1]
[1]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[4]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
[5]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
[6]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[7]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

General_Notes

General (Notes)	12 Months Ended
	Dec. 31, 2014
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, its subsidiaries and its general partner.
	The Partnership is a Delaware limited partnership formed in April 2012 by Delek and its subsidiary Delek Logistics GP, LLC, our general partner.
	The information presented in this Annual Report on Form 10-K contains the combined financial results of Delek Logistics Partners, LP Predecessor (the "DKL Predecessor"), our predecessor for accounting purposes, for periods presented through November 6, 2012, and the consolidated financial results of Delek Logistics, Partners, LP for the period beginning November 7, 2012, the date the Partnership commenced operations. The DKL Predecessor includes the financial results of the initial assets acquired from Delek during the initial public offering (the "Offering") through November 7, 2012. The consolidated balance sheet as of December 31, 2014 presents solely the consolidated financial position of the Partnership.
	On July 26, 2013, the Partnership, through its wholly owned subsidiary Delek Marketing & Supply, LP, 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”).
	The El Dorado Acquisition and the Tyler Acquisition 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 El Dorado Terminal and Tank Assets, as owned and operated by Delek, for all periods presented through February 10, 2014 (the "El Dorado Predecessor") and (ii) 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"). We refer to the historical results of the DKL Predecessor, El Dorado Predecessor and Tyler 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 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, distribute, transport and store refined products in select regions of the southeastern United States and west Texas for Delek and third parties, primarily in support of the Tyler Refinery and the El Dorado Refinery.
	The Partnership generates revenue by charging fees for gathering, transporting and storing crude oil and for 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, 2014
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. For example, our December 31, 2013 balance sheet has been adjusted to increase goodwill by $1.2 million, offset by a corresponding decrease to property, plant and equipment, due to the finalization of the purchase price allocation of our Hopewell acquisition. These reclassifications had no effect on net income or shareholders' equity as previously reported.
	Segment Reporting
	We are an energy business focused on crude oil and refined product pipeline, storage, wholesale marketing and terminalling 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 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 13.
	Cash and Cash Equivalents
	We maintain cash and cash equivalents in accounts with large, national 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, 2014 and 2013.
	One customer accounted for approximately 21.0% of the consolidated accounts receivable balance as of December 31, 2014. Two customers accounted for approximately 27.2% of the consolidated accounts receivable balance as of December 31, 2013.
	Inventory
	Inventory consists of refined products, which are stated at the lower of cost or market on a FIFO basis.
	One vendor in the wholesale marketing and terminalling segment accounted for approximately 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 a total of 96.1% and 76.1% of our consolidated inventory purchases during the years ended December 31, 2013 and 2012, respectively.
	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 pipeline improvements	15-40
	Pipelines and terminals	15-40
	Asset retirement obligation assets	15-50
	Other equipment	15-Mar
	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, 2014, 2013, or 2012.
	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 valuations from third party financial and brokerage institutions. During the years ended December 31, 2014, 2013, and 2012, 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 15 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 14 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, 2014 or 2013, 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 is primarily self-insured for workers' compensation and general liability costs, with varying limits of per claim and aggregate stop loss insurance coverage that management considers adequate. Delek has umbrella liability insurance in an amount determined reasonable by Delek's management.
	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, 2014 and 2013 is as follows (in thousands):
			December 31,
			2014		2013
	Beginning balance		$	3,087	$	3,263
	Liabilities settled		—		(400		)
	Accretion expense		232		224
	Ending balance		$	3,319	$	3,087
	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 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 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. 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.
	Lease expense for all operating leases, including the El Dorado Predecessor and the Tyler Predecessor, totaled $0.7 million, $0.7 million, and $0.6 million for the years ended December 31, 2014, 2013, and 2012, respectively.
	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.
Prior to our Offering, the Predecessor was a corporation included in its parent's consolidated tax return. As such, the Predecessor was subject to both federal and state income taxes and recorded 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.
The Partnership had total tax expense of $0.1 million and $0.8 million in 2014 and 2013, respectively. Subsequent to the Offering, the Partnership had total tax expense of $0.1 million in 2012. The majority of the change in deferred tax assets and liabilities relates to the Predecessor's conversion to a partnership and no longer being subject to federal income tax. The conversion from a taxable corporation to a passthrough resulted in a one-time tax benefit of $18.5 million in 2012.
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. Awards vest over a five-year service period. The phantom unit awards are settled in units.
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. 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 incentive distribution rights 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 incentive distribution rights to our general partner, which is the holder of the incentive distribution rights 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, 2014, 2013, and 2012 was equivalent to net income.
New Accounting Pronouncements
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, 2016, 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 effect that adopting this new standard will have on our consolidated financial statements and related disclosures.

Acquisitions_Notes

Acquisitions (Notes)	12 Months Ended
	Dec. 31, 2014
Acquisitions [Abstract]
Acquisitions	Acquisitions
	Acquisitions from Delek
	El Dorado Terminal and Tankage Acquisition
	On February 10, 2014, the Partnership completed the El Dorado Acquisition and acquired the El Dorado Terminal and Tank Assets. The purchase price paid for the assets acquired was $95.9 million in cash financed with borrowings under the Partnership's amended and restated senior secured revolving credit facility.
	The assets acquired in the El Dorado Acquisition consist of:
	•	The El Dorado Terminal. The refined products terminal located at the El Dorado Refinery, which consists of a truck loading rack with three loading bays supplied by pipeline from storage tanks located at the El Dorado Refinery, along with certain ancillary assets. Total throughput capacity for the El Dorado Terminal is approximately 26,700 barrels per day ("bpd").
	•	The El Dorado Tank Assets. 158 storage tanks and certain ancillary assets (such as pumps and piping) located adjacent to the El Dorado Refinery with an aggregate shell capacity of approximately 2.5 million barrels.
	Delek retained any current assets and current liabilities related to the El Dorado Terminal and Tank Assets as of the date of the El Dorado Acquisition. The only historical balance sheet items that transferred to the Partnership in the El Dorado Acquisition were property, plant and equipment assets, tank inspection liabilities and asset retirement obligations, which were recorded by us at historical cost.
	In connection with the El Dorado Acquisition, the Partnership and Delek entered into (i) an asset purchase agreement, (ii) the Second Omnibus Amendment (as defined in Note 18—Related Party Transactions), (iii) a throughput and tankage agreement with respect to the El Dorado Terminal and Tank Assets, (iv) a lease and access agreement, and (v) a site services agreement. See Note 18 for additional information regarding these agreements.
	Tyler Acquisition
	On July 26, 2013, the Partnership completed the Tyler Acquisition and acquired the Tyler Terminal and Tank Assets. The purchase price paid for the assets acquired was $94.8 million in cash. The assets acquired consisted of the following:
	•	The Tyler Terminal. The refined products terminal located at the Tyler Refinery, which consists of a truck loading rack with nine loading bays supplied by pipelines from storage tanks, also owned by the Partnership, located adjacent to the Tyler Refinery, along with certain ancillary assets. Total throughput capacity for the Tyler Terminal is approximately 72,000 bpd.
	•	The Tyler Tank Assets. Ninety-six storage tanks and certain ancillary assets (such as tank pumps and piping) located adjacent to the Tyler Refinery with an aggregate shell capacity of approximately 2.0 million barrels (the "Tyler Storage Tanks").
	Delek retained any current assets, current liabilities and environmental liabilities related to the Tyler Terminal and Tank Assets as of the date of the Tyler Acquisition. The only historical balance sheet items that transferred to the Partnership in the Acquisition were property, plant and equipment assets and asset retirement obligations, which were recorded by us at historical cost.
	In connection with the Tyler Acquisition, the Partnership and Delek entered into (i) an asset purchase agreement, (ii) the First Omnibus Amendment (as defined in Note 18—Related Party Transactions), (iii) a throughput and tankage agreement with respect to the Tyler Terminal and Tank Assets, (iv) a lease and access agreement and (v) a site services agreement. See Note 18 for additional information regarding these agreements.
	Financial Results of El Dorado Terminal and Tanks Assets and Tyler Terminal and Tank Assets
	The acquisitions of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets were considered transfers of businesses between entities under common control. Accordingly, the El Dorado Acquisition and the Tyler Acquisition were recorded at amounts based on Delek's historical carrying value as of each respective acquisition date, which were $25.2 million as of February 10, 2014 and $38.3 million as of July 26, 2013, 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 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 El Dorado Tank Assets and the Tyler Tank Assets are included in the pipelines and transportation segment.
	The following amounts associated with the El Dorado Terminal and Tank Assets, subsequent to February 10, 2014, are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands):
			Year Ended
			31-Dec-14
	El Dorado Terminal and Tank Assets
	Total operating revenues		$	15,809
	Net income attributable to the Partnership		$	10,481
	Costs associated with the acquisition		$	186
	The results of the El Dorado Terminal and and Tank Assets operations prior to the completion of the El Dorado Acquisition on February 10, 2014 and the Tyler Terminal and Tank Assets operations prior to the completion of the Tyler Acquisition on July 26, 2013 have been included in the El Dorado Predecessor and Tyler Predecessor results in the tables below. The results of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets subsequent to February 10, 2014 and July 26, 2013, respectively have been included in the Partnership's results. Costs associated with the El Dorado Acquisition in the amount of $0.2 million are included in general and administrative expenses for the year ended December 31, 2014.
	The tables below present our balance sheet and results of operations, the effect of including the results of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets, and the adjusted total amounts included in our consolidated financial statements.
	Consolidated Balance Sheet as of December 31, 2013
			Delek Logistics				El Dorado Terminal and Tank Assets				Delek Logistics Partners, LP
			Partners, LP				(El Dorado Predecessor)				31-Dec-13
							(In thousands)
	ASSETS
	Current Assets:
	Cash and cash equivalents		$	924			$	—			$	924
	Accounts receivable		28,976				—				28,976
	Inventory		17,512				—				17,512
	Deferred tax assets		12				—				12
	Other current assets		341				—				341
	Total current assets		47,765				—				47,765
	Property, plant and equipment:
	Property, plant and equipment		234,272				29,800				264,072
	Less: accumulated depreciation		(36,306		)		(3,260		)		(39,566		)
	Property, plant and equipment, net		197,966				26,540				224,506
	Goodwill		11,654				—				11,654
	Intangible assets, net		12,374				—				12,374
	Other non-current assets		5,045				—				5,045
	Total assets		$	274,804			$	26,540			$	301,344
	LIABILITIES AND EQUITY
	Current liabilities:
	Accounts payable		$	26,045			$	—			$	26,045
	Accounts payable to related parties		1,513				—				1,513
	Excise and other taxes payable		5,700				—				5,700
	Accrued expenses and other current liabilities		4,732				—				4,732
	Tank inspection liabilities		1,044				675				1,719
	Total current liabilities		39,034				675				39,709
	Non-current liabilities:
	Revolving credit facility		164,800				—				164,800
	Asset retirement obligations		2,993				94				3,087
	Deferred tax liability		324				—				324
	Other non-current liabilities		5,612				610				6,222
	Total non-current liabilities		173,729				704				174,433
	Equity:
	Predecessors division equity		—				25,161				25,161
	Common unitholders - public (9,353,240 units issued and outstanding)		183,839				—				183,839
	Common unitholders - Delek (2,799,258 units issued and outstanding)		(176,680		)		—				(176,680		)
Subordinated unitholders - Delek (11,999,258 units issued and outstanding)		59,386				—				59,386
General Partner unitholders - Delek (492,893 units issued and outstanding)		(4,504		)		—				(4,504		)
Total equity		62,041				25,161				87,202
Total liabilities and equity		$	274,804			$	26,540			$	301,344
Consolidated Statements of Income
		Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Year Ended December 31, 2014
(In thousands)						(El Dorado Predecessor)
Net Sales		$	841,253			$	—			$	841,253
Operating costs and expenses:
Cost of goods sold		697,221				—				697,221
Operating expenses		38,003				783				38,786
General and administrative expenses		10,570				46				10,616
Depreciation and amortization		14,591				114				14,705
Loss on asset disposals		83				—				83
Total operating costs and expenses		760,468				943				761,411
Operating income (loss)		80,785				(943		)		79,842
Interest expense, net		8,656				—				8,656
Net income (loss) before income tax expense		72,129				(943		)		71,186
Income tax expense		132				—				132
Net income (loss)		71,997				(943		)		71,054
Less: loss attributable to Predecessors		—				(943		)		(943		)
Net income attributable to partners		$	71,997			$	—			$	71,997
		Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Tyler Terminal and Tank Assets				Year Ended December 31, 2013
(In thousands)						(El Dorado Predecessor)				(Tyler Predecessor)
Net Sales		$	907,428			$	—			$	—			$	907,428
Operating costs and expenses:
Cost of goods sold		811,364				—				—				811,364
Operating expenses		25,801				5,338				4,501				35,640
General and administrative expenses		6,254				670				602				7,526
Depreciation and amortization		10,686				1,302				1,750				13,738
Loss on asset disposals		166				—				—				166
Total operating costs and expenses		854,271				7,310				6,853				868,434
Operating income (loss)		53,157				(7,310		)		(6,853		)		38,994
Interest expense, net		4,570				—				—				4,570
Net income (loss) before income tax expense		48,587				(7,310		)		(6,853		)		34,424
Income tax expense		757				—				—				757
Net income (loss)		47,830				(7,310		)		(6,853		)		33,667
Less: loss attributable to Predecessors		—				(7,310		)		(6,853		)		(14,163		)
Net income attributable to partners		$	47,830			$	—			$	—			$	47,830
		Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Tyler Terminal and Tank Assets				Year Ended December 31, 2012
(In thousands)						(El Dorado Predecessor)				(Tyler Predecessor)				(Predecessors)
Net Sales		$	1,022,586			$	—			$	—			$	1,022,586
Operating costs and expenses:
Cost of goods sold		959,434				—				—				959,434
Operating expenses		23,362				9,023				7,035				39,420
General and administrative expenses		8,389				706				761				9,856
Depreciation and amortization		8,675				1,223				1,445				11,343
Gain on disposal of assets		9				—				—				9
Total operating costs and expenses		999,869				10,952				9,241				1,020,062
Operating income (loss)		22,717				(10,952		)		(9,241		)		2,524
Interest expense, net		2,682				—				—				2,682
Income (loss) before income tax expense		20,035				(10,952		)		(9,241		)		(158		)
Income tax benefit		(14,024		)		—				—				(14,024		)
Net income (loss)		34,059				(10,952		)		(9,241		)		13,866
Less: income (loss) attributable to Predecessors		25,649				(10,952		)		(9,241		)		5,456
Net income attributable to partners		$	8,410			$	—			$	—			$	8,410
Acquisitions from Third Parties
Trucking Assets Acquisition
On December 17, 2014, we completed the purchase of substantially all of the assets of Frank Thompson Transport, Inc. ("FTT"), a company that primarily hauled crude oil and asphalt products by transport truck, to complement our existing assets and increase our third party business. The assets purchased from FTT include approximately 120 trucks and 200 trailers (the "FTT Assets").
Terminal and Pipeline Acquisition
On October 1, 2014, we completed the purchase from an affiliate of Magellan Midstream Partners, LP of (i) a light products terminal in Mount Pleasant, Texas (the "Mount Pleasant Terminal"), (ii) a light products storage facility in Greenville, Texas (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." We acquired the Greenville-Mount Pleasant Assets to complement our existing assets and provide enhanced logistical capabilities. The Mount Pleasant Terminal consists of approximately 200,000 barrels of light product storage capacity, three truck loading lanes and ethanol blending capability. The Greenville Storage Facility has approximately 325,000 barrels of storage capacity and is connected to the Explorer Pipeline System, which is a common carrier pipeline owned by a third party.
North Little Rock Acquisition
On October 24, 2013, we purchased a refined product terminal in Little Rock, Arkansas from Enterprise Refined Products Company, LLC (the "North Little Rock Terminal"). The North Little Rock Terminal consists 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. We acquired the North Little Rock Terminal to extend our logistics presence in Arkansas.
Hopewell Acquisition
On July 19, 2013, the Partnership purchased 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 the Partnership's 19-mile pipeline (the "Big Sandy Pipeline") 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").
Big Sandy Acquisition
On February 7, 2012, Delek Marketing-Big Sandy, LLC purchased (i) a light petroleum products terminal located in Big Sandy, Texas, the underlying real property, and other related assets from Sunoco Partners Marketing & Terminals L.P. and (ii) the 19-mile, eight-inch diameter Hopewell-Big Sandy Pipeline originating at Hopewell Junction, Texas and terminating at the Big Sandy Station in Big Sandy, Texas from Sunoco Pipeline L.P (collectively "Big Sandy").
Nettleton Acquisition
On January 31, 2012, Delek Crude Logistics, LLC completed the acquisition of an approximately 35-mile long, eight- and ten-inch pipeline system (the "Nettleton Pipeline") from Plains Marketing, L.P. (“Plains”). The Nettleton Pipeline is used exclusively to transport crude oil from our tank farms in and around Longview, Texas to the Bullard Junction at the Tyler Refinery.
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 (1)				North Little Rock Terminal(2)				Hopewell(2)				Big Sandy		Nettleton Pipeline
Property, plant and equipment	$	11,055			$	10,000			$	4,990			$	3,538			$	8,258	$	8,590
Intangible assets	—				—				10				984				1,229		2,240
Goodwill (3)	—				—				—				1,200				1,540		1,415
Inventory	—				1,125				—				—				—		—
Accounts Receivable	1,871				—				—				—				—		—
Accounts Payable	(1,401		)		—				—				—				—		—
Total	$	11,525			$	11,125			$	5,000			$	5,722			$	11,027	$	12,245
(1)	Allocations are preliminary. The property, plant and equipment valuation is subject to change during the purchase price allocation period.
(2)	During the second quarter of 2014, 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.
Financial Results - Acquisitions from Third Parties
The following amounts associated with the third party acquisitions described above, subsequent to each respective acquisition date, are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands) for the year ended December 31, 2014:
		Year Ended
		31-Dec-14
FTT Assets:
Total operating revenues contributed		$	531
Net income contributed		$	122
Greenville-Mount Pleasant Assets:
Total operating revenues contributed		$	172
Net loss contributed		$	(109	)
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				2013
FTT Assets:
Net Sales		$	854,842			$	921,017
Net income		$	71,820			$	34,433
Greenville-Mount Pleasant Assets:
Net Sales		$	841,943			$	908,118
Net income		$	70,617			$	33,230
Below are the unaudited pro forma consolidated results of operations of the Partnership for the years ended December 31, 2013 and 2012, as if our 2013 acquisitions had occurred on January 1, 2012 (in thousands):
		Year Ended December 31,
		2013				2012
North Little Rock Terminal:
Net Sales		$	908,867			1,024,025
Net income		$	34,958			15,157
Hopewell:
Net Sales		$	908,382			1,023,540
Net income		$	33,981			14,180
Below are the unaudited pro forma consolidated results of the Partnership for the year ended December 31, 2012, as if our 2012 acquisitions had occurred on January 1, 2011 (in thousands):
		Year Ended
		31-Dec-12
Nettleton and Big Sandy:
Net Sales		$	1,022,715
Net income		$	13,989

Net_Income_Per_Unit_Notes

Net Income Per Unit (Notes)	12 Months Ended
	Dec. 31, 2014
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 incentive distribution rights. 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 incentive distribution rights 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 incentive distribution rights to our general partner, which is the holder of the incentive distribution rights 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,
			2014		2013		2012
	Net income attributable to partners		$	71,997	$	47,830	$	8,410
	Less: General partner's distribution (including IDRs) (1)		1,883		785		110
	Less: Limited partners' distribution		23,152		19,292		2,688
	Less: Subordinated partner's distribution		22,799		19,199		2,688
	Earnings in excess of distributions		$	24,163	$	8,554	$	2,924
	General partner's earnings:
	Distributions (including IDRs) (1)		$	1,883	$	785	$	110
	Allocation of earnings in excess of distributions		483		172		58
	Total general partner's earnings		$	2,366	$	957	$	168
	Limited partners' earnings on common units:
	Distributions		$	23,152	$	19,292	$	2,688
	Allocation of earnings in excess of distributions		11,933		4,198		1,433
	Total limited partners' earnings on common units		$	35,085	$	23,490	$	4,121
	Limited partners' earnings on subordinated units:
	Distributions		$	22,799	$	19,199	$	2,688
	Allocation of earnings in excess of distributions		11,747		4,184		1,433
	Total limited partner's earnings on subordinated units		$	34,546	$	23,383	$	4,121
	Weighted average limited partner units outstanding:
	Common units - (basic)		12,171,548		12,025,249		11,999,258
	Common units - (diluted)		12,302,629		12,148,774		11,999,258
	Subordinated units - Delek (basic and diluted)		11,999,258		11,999,258		11,999,258
	Net income per limited partner unit:
	Common - (basic)		$	2.88	$	1.95	$	0.34
	Common - (diluted)		$	2.85	$	1.93	$	0.34
	Subordinated - (basic and diluted)		$	2.88	$	1.95	$	0.34
	(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 11 for further discussion related to IDRs.

Major_Customer_Notes

Major Customer (Notes)	12 Months Ended
	Dec. 31, 2014
Major Customer [Abstract]
Major Customer [Text Block]	Major Customers
	Sunoco LP accounted for 23.3%, 17.7% and 17.5% of our total revenues for the years ended December 31, 2014, 2013 and 2012, respectively. Delek accounted for 13.6%, 8.6% and 23.1% of our total revenues for the years ended December 31, 2014, 2013 and 2012, respectively.

Inventory_Notes

Inventory (Notes)	12 Months Ended
	Dec. 31, 2014
Inventory, Net [Abstract]
Inventory	Inventory
	Inventories consisted of $10.3 million and $17.5 million of refined petroleum products as of December 31, 2014 and December 31, 2013, respectively. Cost of inventory is stated at the lower of cost or market on a first-in, first-out basis.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2014
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,
		2014			2013
	Land and land improvements	$	2,000		$	1,931
	Building and building improvements	1,169			1,057
	Pipelines and terminals	266,196			229,672
	Asset retirement obligations	2,073			1,999
	Other equipment	3,764			2,959
	Construction in process	18,323			26,454
		293,525			264,072
	Less: accumulated depreciation	(52,992		)	(39,566		)
		$	240,533		$	224,506
	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2014 and 2013 are as follows (in thousands):
		As of and For the Year Ended December 31, 2014
		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment	$	227,927		$	65,598		$	293,525
	Less: Accumulated depreciation	(36,459		)	(16,533		)	(52,992		)
	Property, plant and equipment, net	$	191,468		$	49,065		$	240,533
	Depreciation expense	$	10,395		$	3,247		$	13,642
		As of and For the Year Ended December 31, 2013
		Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment	$	200,001		$	64,071		$	264,072
	Less: Accumulated depreciation	(25,128		)	(14,438		)	(39,566		)
	Property, plant and equipment, net	$	174,873		$	49,633		$	224,506
	Depreciation expense	$	9,928		$	2,747		$	12,675

Goodwill_Notes

Goodwill (Notes)	12 Months Ended
	Dec. 31, 2014
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 the Offering and to the allocation of the purchase price of our Hopewell, Nettleton, and Big Sandy acquisitions that occurred in July 2013, January 2012, and February 2012, respectively.
	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 2014, 2013 and 2012. 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 2014, 2013 and 2012 the annual impairment review resulted in the determination that no impairment of goodwill had occurred. Goodwill was $11.7 million at December 31, 2014.
	A summary of our goodwill accounts is as follows (in thousands):
			Wholesale Marketing and Terminalling		Pipelines and Transportation		Total
	Balance,	December 31, 2011	$	7,499	$	—	$	7,499
	Acquisitions		—		2,955		2,955
	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

Other_Intangibles_Notes

Other Intangibles (Notes)	12 Months Ended
	Dec. 31, 2014
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, 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	8,071		—			8,071
	Total		$	20,298	$	(8,949	)	$	11,349
		Useful			Accumulated
	As of December 31, 2013	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts (Gross)	11.5	$	12,227	$	(7,885	)	$	4,342
	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	8,032		—			8,032
	Total		$	20,259	$	(7,885	)	$	12,374
	Amortization of intangible assets was $1.1 million during each of the years ended December 31, 2014, 2013 and 2012 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 2015 through 2017, at which point our supply contracts will be fully amortized.

LongTerm_Obligations_and_Short

Long-Term Obligations and Short-Term Note Payable (Notes)	12 Months Ended
	Dec. 31, 2014
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, 2014, the weighted average interest rate for our borrowings under the facility was approximately 2.3%. 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, 2014, this fee was 0.30% 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, 2014, 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, 2014, we had approximately $251.8 million outstanding borrowings under the Second Amended and Restated Credit Agreement. Additionally, we had in place letters of credit totaling $7.5 million, primarily securing obligations with respect to gasoline and diesel purchases. No amounts were drawn under these letters of credit at December 31, 2014. Amounts available under the Second Amended and Restated Credit Agreement as of December 31, 2014 were approximately $440.8 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, 2014 (in thousands):
		2015		2016		2017		2018		2019		Thereafter		Total
	Second Amended and Restated Credit Agreement	$	—	$	—	$	—	$	—	$	251,750	$	—	$	251,750

Equity_Notes

Equity (Notes)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	Equity
	We had 9,417,189 common limited partner units held by the public outstanding as of December 31, 2014. Additionally, as of December 31, 2014, Delek owned a 59.9% 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 95.9% interest in our general partner, which owns the entire 2.0% general partner interest consisting of 494,197 general partner units. In accordance with our partnership agreement, Delek's subordinated units may convert to common units once specified distribution targets and other requirements have been met.
	The table below summarizes the changes in the number of units outstanding through December 31, 2014 (in units). There were no units outstanding prior to our initial public offering in November 2012.
		Common - Public			Common - Delek			Subordinated		General Partner		Total
	Units issued in initial public 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	63,949			—			—		—		63,949
	Balance at December 31, 2014	9,417,189			2,799,258			11,999,258		494,197		24,709,902
	(1) Unit-based compensation awards are presented net of 5,539 units withheld for taxes.
	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,
		2014				2013			2012
	Net income attributable to partners	$	71,997			$	47,830		$	8,410
	Less: General partner's IDRs	(945		)		—			—
	Net income available to partners	$	71,052			$	47,830		$	8,410
	General partner's ownership interest	2		%		2		%	2		%
	General partner's allocated interest in net income	1,421				957			168
	General partner's IDRs	945				—			—
	Total general partner's interest in net income	$	2,366			$	957		$	168
	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 incentive distribution rights, 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		$	0.375			98	%	2	%
	First Target Distribution	above	$	0.375			98	%	2	%
		up to	$	0.43125
	Second Target Distribution	above	$	0.43125			85	%	15	%
		up to	$	0.46875
	Third Target Distribution	above	$	0.46875			75	%	25	%
		up to	$	0.5625
	Thereafter	thereafter	$	0.5625			50	%	50	%
	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 general partner IDRs (in thousands)			Date of Distribution	Unitholders Record Date
	31-Dec-13	$	0.415			$	1.66		$	10,228		February 13, 2014	February 4, 2014
	31-Mar-14	$	0.425			$	1.7		$	10,474		May 14, 2014	May 6, 2014
	30-Jun-14	$	0.475			$	1.9		$	11,910		August 14, 2014	August 7, 2014
	30-Sep-14	$	0.49			$	1.96		$	12,394		November 14, 2014	November 6, 2014
	31-Dec-14	$	0.51			$	2.04		$	13,056		February 13, 2015	February 6, 2015
	The allocation of total quarterly cash distributions made to general and limited partners for the years ended December 31, 2014, 2013 and 2012 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,
		2014				2013			2012
	General partner's distributions:
	General partner's distributions	938				$	785		$	110
	General partner's incentive distribution rights	945				—			—
	Total general partner's distributions	1,883				785			110
	Limited partners' distributions:
	Common	23,152				19,292			$	2,688
	Subordinated	22,799				19,199			$	2,688
	Total limited partners' distributions	45,951				38,491			5,376
	Total cash distributions	$	47,834			$	39,276		$	5,486
	Cash distributions per limited partner unit	$	1.9			$	1.6		$	0.224

Equity_Based_Compensation_Note

Equity Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2014
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 $0.3 million and $0.5 million of unit-based compensation expense related to the Partnership during the years ended December 31, 2014 and 2013, respectively. We incurred a nominal amount of unit-based compensation expense during the year ended December 31, 2012. 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. Awards vest over a five-year service period. The total fair value of phantom units vested was $1.6 million and $4.2 million during the years ended December 31, 2014 and 2013, respectively.
	As of December 31, 2014, there was $0.9 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 2.7 years.
	A summary of our unit award activity for the twelve months ended December 31, 2014 is set forth below:
			Number of Phantom Units		Weighted-Average Grant Price
	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
	Sponsor's Equity-Based Compensation
	Certain employees supporting the DKL Predecessor's operations received long-term incentive compensation that is part of the Delek US Holdings, Inc. 2006 Long-Term Incentive Plan, as amended (the “2006 Plan”). The 2006 Plan allows Delek to grant stock options, stock appreciation rights ("SARs"), restricted stock units and other stock-based awards denominated in shares of Delek's common stock to certain directors, officers, employees, consultants and other individuals who perform services for Delek or its affiliates, including these employees. Delek uses the Black-Scholes-Merton option-pricing model to determine the fair value of stock option and SAR awards, with the exception of the SARs granted to certain executive employees, which are valued under the Monte-Carlo simulation model. Restricted stock units are measured based on the fair market value of the underlying stock on the date of grant. Compensation expense related to stock-based awards is generally recognized with graded or cliff vesting on a straight-line basis over the vesting period.
	Certain Delek employees supporting the DKL Predecessor's operations were historically granted these types of awards. These costs were recorded as compensation expense and additional paid-in capital and totaled $0.1 million related to the DKL Predecessor's employees for the year ended December 31, 2012. The DKL Predecessor recognized additional compensation expense related to equity-based compensation awards to related party employees of $0.5 million for the year ended December 31, 2012 for allocated related party services and an allocation of director and executive officer equity-based compensation.
	As of December 31, 2012, there was no unrecognized compensation cost related to non-vested equity-based compensation arrangements for the DKL Predecessor's employees. Subsequent to the Offering, these costs are allocated to the Partnership as part of the administrative fee under the Second Omnibus Amendment (as defined in Note 18—Related Party Transactions).

Segment_Data_Notes

Segment Data (Notes)	12 Months Ended
	Dec. 31, 2014
Segment Data [Abstract]
Segment Data	Segment Data
	We report our assets and 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, 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.
	On February 10, 2014, we acquired the El Dorado Terminal and Tank Assets and on July 26, 2013, we acquired the Tyler Terminal and Tank Assets. Our and our Predecessors' historical financial statements have been retrospectively adjusted to reflect the results of operations attributable to 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 El Dorado Tank Assets and the Tyler Tank Assets are included in the pipelines and transportation 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,
			2014 (1) (3)		2013 (2) (4)		2012 (2) (4)
	Pipelines and Transportation
	Net Sales:
	Affiliate		$	80,683	$	51,878	$	30,145
	Third-Party		10,665		8,359		3,394
	Total Pipelines and Transportation		$	91,348	$	60,237	$	33,539
	Operating costs and expenses:
	Cost of goods sold		4,294		764		—
	Operating expenses		31,300		27,465		32,359
	Segment contribution margin		$	55,754	$	32,008	$	1,180
	Capital spending (excluding business combinations)		$	3,768	$	9,621	$	23,845
	Wholesale Marketing and Terminalling
	Net Sales:
	Affiliate		$	33,900	$	26,295	$	13,469
	Third-Party		716,005		820,896		975,578
	Total Wholesale Marketing and Terminalling		$	749,905	$	847,191	$	989,047
	Operating costs and expenses:
	Cost of goods sold		692,927		810,600		959,434
	Operating expenses		7,486		8,175		7,061
	Segment contribution margin		$	49,492	$	28,416	$	22,552
	Capital spending (excluding business combinations)		$	3,364	$	3,041	$	6,971
	Consolidated
	Net Sales:
	Affiliate		$	114,583	$	78,173	$	43,614
	Third-Party		726,670		829,255		978,972
	Total Consolidated		$	841,253	$	907,428	$	1,022,586
	Operating costs and expenses:
	Cost of goods sold		697,221		811,364		959,434
	Operating expenses		38,786		35,640		39,420
	Contribution margin		105,246		60,424		23,732
	General and administrative expenses		10,616		7,526		9,856
	Depreciation and amortization		14,705		13,738		11,343
	Loss on asset disposals		83		166		9
	Operating income		$	79,842	$	38,994	$	2,524
	Capital spending (excluding business combinations)		$	7,132	$	12,662	$	30,816
	(1) The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
	(2) The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
	(3) Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
	(4) Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
	The following table summarizes the total assets for each segment as of December 31, 2014 and December 31, 2013 (in thousands).
			Year Ended December 31,
			2014		2013
	Pipelines and Transportation		210,846		195,984
	Wholesale Marketing and Terminalling		100,993		105,360
	Total Assets		$	311,839	$	301,344

Fair_Value_Measurements_Notes

Fair Value Measurements (Notes)	12 Months Ended
	Dec. 31, 2014
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 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 using quotations provided by brokers 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, 2014 and 2013 was as follows: (in thousands):
		As of December 31, 2014
		Level 1		Level 2			Level 3		Total
	Assets
	Interest rate derivatives	$	—	$	24		$	—	$	24
	Commodity derivatives	—		456			—		456
	Total assets	—		480			—		480
	Liabilities
	Commodity Derivatives	—		(61		)	—		(61		)
	Net Assets	$	—	$	419		$	—	$	419
		As of December 31, 2013
		Level 1		Level 2			Level 3		Total
	Assets
	Interest rate derivatives	$	—	$	116		$	—	$	116
	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, 2014 and December 31, 2013, no cash collateral was held by counterparty brokerage firms.

Derivative_Instruments_Notes

Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2014
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, 2014 and 2013. 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 differ from the amounts presented in our consolidated balance sheets. During the years ended December 31, 2014 and 2013, 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, 2014						December 31, 2013
	Derivative Type	Balance Sheet Location	Assets			Liabilities			Assets		Liabilities
	Derivatives not designated as hedging instruments:
	Interest rate derivatives	Other long term assets	$	24		$	—		$	116	$	—
	Commodity derivatives (1)	Other current assets	456			(61		)	—		—
	Total gross value of derivatives		$	480		$	(61	)	$	116	$	—
	Less: Counterparty netting and cash collateral (2)		(61		)	61			—		—
	Total net fair value of derivatives		$	419		$	—		$	116	$	—
	(1)	As of December 31, 2014, we had open derivative contracts representing 142,000 barrels of refined petroleum products. As of December 31, 2013, we had no open derivative contracts.
	(2)	As of December 31, 2014 and December 31, 2013, no cash collateral associated with our commodity derivatives has been netted with the derivative positions with each counterparty.
	Recognized gains (losses) associated with derivatives not designated as hedging instruments for the years ended December 31, 2014 and 2013 were as follows (in thousands):
			Year Ended December 31,
	Derivative Type	Income Statement Location	2014			2013			2012
	Interest rate derivatives	Interest expense	$	(92	)	$	(106	)	$	—
	Commodity derivatives	Cost of goods sold	3,083			(614		)	85
		Total	$	2,991		$	(720	)	$	85

Income_Taxes_Notes

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2014
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.
	Prior to the Offering, the DKL Predecessor was a corporation included in its parent's consolidated tax return. As such, the DKL Predecessor was subject to both federal and state income taxes and recorded 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.
	Effective with the closing of the Offering, the Partnership is no longer 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 current deferred tax assets and liabilities, excluding the valuation allowance, were nominal as of December 31, 2014 and December 31, 2013. The total non-current deferred tax assets and liabilities, excluding the valuation allowance, were $0.2 million and $0.3 million as of December 31, 2014 and December 31, 2013, respectively. The majority component of our non-current deferred tax liability as of December 31, 2014 and December 31, 2013 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,
		2014			2013			2012
	Provision for federal income taxes at statutory rate	$	—		$	—		4,047
	State income taxes, net of federal tax provision	492			794			(58		)
	Valuation allowance	—			—			193
	Permanent differences	—			—			300
	Conversion to partnership	—			—			(18,534		)
	Other items	(360		)	(37		)	28
	Income tax (benefit) expense	$	132		$	757		$	(14,024	)
	Income tax expense (benefit) is as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Current	$	241		$	448		$	4,738
	Deferred	(109		)	309			(18,762		)
		$	132		$	757		$	(14,024	)
	Deferred income tax expense above is reflective of the changes in deferred tax assets and liabilities during the current period. The majority of the change in deferred tax assets and liabilities in 2013 from 2012 relates to the DKL Predecessor's conversion from a corporation to a partnership and no longer being subject to federal income tax. The conversion from a taxable corporation to a passthrough resulted in a one-time tax benefit of $18.5 million in 2012.
	Delek US files a consolidated Texas income tax return and current income tax payments for DKL are paid by Delek US. Therefore, any current income tax payable is included in accounts receivable/payable from related parties. As of December 31, 2014 and 2013, income taxes payable of $0.6 million and $0.4 million, respectively, were included in accounts payable 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, 2014, 2013 or 2012 and there were no interest or penalties recognized related to uncertain tax positions for the years ended December 31, 2014, 2013 or 2012. 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, 2014
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.
	Rate Regulation of Petroleum Pipelines
	The rates and terms and conditions of service on certain of our pipelines are subject to regulation by the Federal Energy Regulatory Commission (“FERC”) under the Interstate Commerce Act (“ICA”) and by the state regulatory commissions in the states in which we transport crude oil and refined products, including the Railroad Commission of Texas, the Louisiana Public Service Commission, and the Arkansas Public Service Commission. Certain of our pipeline systems are subject to such regulation and have filed tariffs with the appropriate authorities. We also comply with the reporting requirements for these pipelines. Other of our pipelines have received a waiver from application of FERC's tariff requirements but comply with other applicable regulatory requirements.
	The FERC regulates interstate transportation under the ICA, the Energy Policy Act of 1992 and the rules and regulations promulgated under those laws. The ICA and its implementing regulations require that tariff rates for interstate service on oil pipelines, including pipelines that transport crude oil and refined products in interstate commerce (collectively referred to as “petroleum pipelines”), be just and reasonable and non-discriminatory and that such rates and terms and conditions of service be filed with the FERC. Under the ICA, shippers may challenge new or existing rates or services. The FERC is authorized to suspend the effectiveness of a challenged rate for up to seven months, though rates are typically not suspended for the maximum allowable period. Tariff rates are typically contractually 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.
	While the FERC regulates rates for shipments of crude oil or refined products in interstate commerce, state agencies may regulate rates and service for shipments in intrastate commerce. We own pipeline assets in Texas, Arkansas, and Louisiana; accordingly such assets may be subject to additional regulation by the applicable governmental authorities in those states. In particular, and without limitation, the Greenville-Mount Pleasant Pipeline currently operates as a common carrier subject to regulation by the Railroad Commission of Texas.
	Environmental Health and Safety
	We are subject to various federal, state and local environmental and safety laws enforced by agencies including the United States Environmental Protection Agency ("EPA"), the United States Department of Transportation ("DOT") / Pipeline and Hazardous Materials Safety Administration, the United States Department of Labor / Occupational Safety and Health Administration, the Texas Commission on Environmental Quality, the Texas Railroad Commission, the Arkansas Department of Environmental Quality, the Louisiana Oil Spill Coordinating Office, the Louisiana Department of Environmental Quality, the Louisiana Department of Wildlife and Fisheries and the Tennessee Department of Environment and Conservation, as well as other state and federal agencies. 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 raise potential exposure to 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 responsibility. We believe that our current operations are in substantial compliance with existing environmental and safety requirements. However, 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. While it is often difficult to quantify future environmental or safety related expenditures, we anticipate that continuing capital investments and changes in operating procedures will be required for the foreseeable future to comply with existing and new requirements as well as evolving interpretations and more strict enforcement of existing laws and regulations.
	Crude Oil Releases
	Since their acquisition, we have detected several crude oil releases involving our assets, including, but not limited to, a release at our Magnolia Station in March 2013, a release near Macedonia, Arkansas in October 2013 and a release in Haynesville, Louisiana in April 2014. During the year ended December 31, 2014, we incurred costs of $1.0 million related to the release in Haynesville, Louisiana. No costs were incurred for the releases at our Magnolia Station and near Macedonia, Arkansas during the year ended December 31, 2014. During the year ended December 31, 2013, we incurred costs of $0.3 million for each of the releases at the Magnolia Station and near Macedonia, Arkansas. Theses costs are included in operating expenses in our consolidated statements of income and comprehensive income. As of December 31, 2014, we have accrued $1.3 million and $0.6 million for the releases that occured in Macedonia and Haynesville, respectively. No accrual was recorded for the spill at our Magnolia Station as of December 31, 2014, as we do not anticipate to incur any additional expenses in connection with this release. 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 Second Omnibus Amendment (as defined in Note 18), 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 at the Abilene and San Angelo terminals and to exchange barrels with third parties. 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, 2014, we had in place letters of credit totaling $7.5 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, 2014.
	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, 2014, 2013 and 2012 totaled $0.7 million, $0.7 million, and $0.6 million, respectively.

Related_Party_Transactions_Not

Related Party Transactions (Notes)	12 Months Ended
	Dec. 31, 2014
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 and refined products transportation and storage services and marketing and terminalling 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 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.
	We believe the terms and conditions under these agreements, as well as our other agreements with Delek described below, are generally no less favorable to either party than those that could have been negotiated with unaffiliated parties with respect to similar services. These 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)		Nov-12		15-May	Crude oil and refined products transportation		46,000 (2)	$ 0 .92 (3)
	Refined Products Pipelines		Nov-12		15-May			40,000	$	0.109
	SALA Gathering System		Nov-12		15-May	Crude oil gathering		14,000	$ 2.44 (3)
	East Texas Crude Logistics System:
	Crude Oil Pipelines		Nov-12		15-May	Crude oil transportation and storage		35,000	$ 0.43 (4)
	Storage		Nov-12		15-May			N/A	$271,640/month
	East Texas Marketing		Nov-12		10 (5)	Marketing products for Tyler Refinery		50,000	$0.616/bbl (5)
	Memphis Terminal		Nov-12		15-May	Dedicated terminalling services		10,000	$	0.54
	Big Sandy Terminal: (6)
	Refined Products Transportation		Nov-12		15-May	Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery		5,000	$	0.54
	Terminalling		Nov-12		15-May			5,000	$	0.54
	Storage		Nov-12		15-May			N/A	$54,280/month
	Tyler Throughput and Tankage:
	Refined Products Throughput		Jul-13		16-Aug	Dedicated Terminalling and storage		50,000	$	0.36
	Storage		Jul-13		16-Aug			N/A	$855,041/month
	Tyler Lease and Access		Jul-13		50	Real property lease		N/A	$100 annually
	Tyler Site Services		Jul-13		16-Aug	Shared services		N/A	$203,178 annually
	North Little Rock Terminal:
	Terminalling		Oct-13		16-Aug	Dedicated terminalling and storage services		8,100	$ 0.23 (7)
	Storage		Oct-13		16-Aug			N/A	$64,001/month (7)
	El Dorado Throughput and Tankage:
	Refined Products Throughput		Feb-14		16-Aug	Dedicated terminalling and storage		11,000	$0.51/bbl
	Storage		Feb-14		16-Aug			N/A	$1,319,641/month
	El Dorado Lease and Access		Feb-14		50	Real property lease		N/A	$100 annually
	El Dorado Site Services		Feb-14		16-Aug	Shared services		N/A	$203,178 annually
	-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 $0.652/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	Pursuant to the agreement, capital projects are to be completed in two phases in order to support and enhance blending activities at the terminal. Upon completion of phase II capital projects, the minimum throughput fees will decrease and storage fees will increase.
	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 and refined products transported on our Lion Pipeline System and SALA Gathering System. J. Aron is therefore considered the shipper for the liquid it owns on the Lion Pipeline System and the SALA Gathering System. 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 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:
	Second Amended and Restated Omnibus Agreement
	The Partnership entered into an omnibus agreement with Delek, our general partner, OpCo, Lion Oil and certain of the Partnership’s and Delek’s other subsidiaries on November 7, 2012 (the "Omnibus Agreement"). On July 26, 2013, in connection with the Tyler Acquisition, the Partnership and the other parties entered into an amendment and restatement of the Omnibus Agreement (the "First Omnibus Amendment"), which was amended and restated on February 10, 2014, in connection with the El Dorado Acquisition (the "Second Omnibus Amendment").
	The Second Omnibus Amendment includes, among other things, (i) modifications in the reimbursement by Delek and certain of its subsidiaries under the Omnibus Agreement for certain operating expenses and capital expenditures incurred by the Partnership or its subsidiaries, (ii) modifications of the indemnification provisions under the Omnibus Agreement in favor of the Partnership with respect to certain environmental matters, and (iii) an increase in the annual administrative fee payable by us to Delek under the Omnibus Agreement from $3.0 million as of December 31, 2013 to $3.3 million as of December 31, 2014 for general corporate and administrative services. We paid Delek approximately $3.3 million, $2.8 million and $0.4 million pursuant to the Omnibus Agreement during the years ended December 31, 2014, 2013 and 2012, respectively, for general corporate and administrative services.
	Under the Second Omnibus Amendment, Delek has agreed to reimburse us for (i) certain expenses that we incur for inspections, maintenance and repairs to any storage tanks we acquired in the El Dorado Acquisition to cause such storage tanks to comply with applicable regulatory and/or industry standards, (ii) certain expenses that we incur for inspections, maintenance and repairs to most of the storage tanks contributed to us by Delek (subject to a deductible of $0.5 million per year) that are necessary to comply with the DOT pipeline integrity rules and certain American Petroleum Institute storage tank standards for a period of five years, and (iii) certain non-discretionary maintenance capital expenditures with respect to certain of our assets in excess of specified amounts, as disclosed in the full agreement filed as Exhibit 10.2 to our Current Report on Form 8-K, filed with the SEC on February 14, 2014.
	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 and $1.3 million pursuant to this agreement during the years ended December 31, 2013 and 2012, respectively. 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 $12.3 million and $6.5 million pursuant to the partnership agreement during the years ended December 31, 2014 and 2013, respectively.
	Other Agreements
	Paline Pipeline System Capacity Reservation. Prior to the Partnership's acquisition of Paline, 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.
	Pursuant to the Omnibus Agreement, Delek indemnified us $0.9 million and $0.4 million during the years ended December 31, 2013 and 2012, respectively, for lost service fees attributable to the failure of our customer to pay 100% of the full monthly fee for the capacity of the Paline Pipeline System. We were not indemnified for lost service fees during the year ended December 31, 2014, as we received the entire monthly amount payable to us from our customer during this period.
	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 formation of the Partnership, the El Dorado Acquisition and the Tyler Acquisition, we were not allocating 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
	A summary of revenue and expense transactions with Delek, including expenses directly charged and allocated to our Predecessors, are as follows (in thousands):
			Year Ended December 31,
			2014				2013			2012
	Revenues		$	114,583			$	78,173		$	43,614
	Operating and maintenance expenses (1)		$	20,210			$	16,068		$	4,678
	General and administrative expenses (2)		$	5,799			$	4,010		$	5,650
	(1)	Operating and maintenance expenses include costs allocated to the Tyler Predecessor and the El Dorado Predecessor for operating support provided to the Tyler Predecessor by Delek Refining and to the El Dorado Predecessor by Lion Oil, including certain labor related costs, property and liability insurance costs and certain other operating expenses. The costs that were allocated to us by Delek Refining were $1.4 million and $2.7 million for the years ended December 31, 2013 and 2012, respectively. The costs that were allocated to us by Lion Oil were $0.4 million, $1.4 million, and $1.3 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	(2)	General and administrative expenses include costs allocated to the Tyler Predecessor and the El Dorado Predecessor for general and administrative support provided to the Tyler Predecessor by Delek Refining and to the El Dorado Predecessor by Lion Oil, including services such as corporate management, risk management, accounting and human resources. The costs that were allocated to us by Delek Refining were $0.5 million and $0.8 million for the years ended December 31, 2013 and 2012, respectively. The costs that were allocated to us by Lion Oil were $0.1 million for the year ended December 31, 2014 and $0.7 million for each of the years ended December 31, 2013 and 2012, respectively.
Quarterly Cash Distribution
In accordance with our partnership agreement, our common, subordinated and general partner unitholders are entitled to receive quarterly distributions of available cash. During the years ended December 31, 2014 and 2013, we paid quarterly cash distributions, of which $28.1 million and $21.5 million respectively, were paid to Delek and our general partner. On January 27, 2015, our general partner's board of directors declared a quarterly cash distribution totaling $13.1 million, based on the available cash as of the date of determination for the end of the fourth quarter of 2014, payable on February 13, 2015 to unitholders of record on February 6, 2015. The distribution included $7.8 million, paid to both Delek and our general partner, including incentive distribution rights.

Selected_Quarterly_Financial_D

Selected Quarterly Financial Data (Notes)	12 Months Ended
	Dec. 31, 2014
Selected Quarterly Financial Information [Abstract]
Quarterly Financial Information [Text Block]	Selected Quarterly Financial Data (Unaudited)
	Quarterly financial information for the years ended December 31, 2014 and 2013 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On February 10, 2014, we acquired the El Dorado Terminal and Tank Assets and on July 26, 2013, we acquired the Tyler Terminal and Tank Assets. Our and our Predecessors' historical financial statements have been retrospectively adjusted to reflect the results of operations attributable to the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.
			For the Three Month Periods Ended
			March 31, 2014 (1)		30-Jun-14		30-Sep-14		31-Dec-14
	Net sales		$	203,527	$	236,343	$	228,036	$	173,347
	Operating income		$	15,859	$	24,377	$	17,488	$	22,118
	Net income		$	13,729	$	21,754	$	15,085	$	20,486
	Limited partners' interest in net income		$	14,379	$	21,134	$	14,487	$	19,631
	Net income per limited partner unit:
	Common (basic)		$	0.6	$	0.88	$	0.6	$	0.81
	Common (diluted)		$	0.59	$	0.87	$	0.59	$	0.8
	Subordinated - Delek (basic and diluted)		$	0.6	$	0.87	$	0.6	$	0.81
	(1)	The information presented includes the results of operations of the El Dorado Predecessor
			For the Three Month Periods Ended
			March 31, 2013 (1) (2)		June 30, 2013 (1) (2)		September 30, 2013 (2)		December 31, 2013 (2)
	Net sales		$	210,894	$	230,141	$	243,295	$	223,097
	Operating income		$	8,210	$	7,443	$	10,986	$	12,355
	Net income		$	7,271	$	6,573	$	9,485	$	10,338
	Limited partners' interest in net income		$	11,960	$	11,521	$	12,295	$	11,098
	Net income per limited partner unit:
	Common (basic)		$	0.5	$	0.48	$	0.51	$	0.46
	Common (diluted)		$	0.5	$	0.47	$	0.51	$	0.46
	Subordinated - Delek (basic and diluted)		$	0.5	$	0.48	$	0.51	$	0.46
	(1)	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor.
	(2)	The information presented includes the results of operations of the El Dorado Predecessor.

Subsequent_Events_Notes

Subsequent Events (Notes)	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events [Text Block]	Subsequent Events
	Distribution Declaration
	On January 27, 2015, our general partner's board of directors declared a quarterly cash distribution of $0.510 per share, paid on February 13, 2015, to unitholders of record on February 6, 2015.

Accounting_Policies_Policies

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
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.
	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. For example, our December 31, 2013 balance sheet has been adjusted to increase goodwill by $1.2 million, offset by a corresponding decrease to property, plant and equipment, due to the finalization of the purchase price allocation of our Hopewell acquisition. These reclassifications had no effect on net income or shareholders' equity as previously reported.
Segment Reporting, Policy [Policy Text Block]	Segment Reporting
	We are an energy business focused on crude oil and refined product pipeline, storage, wholesale marketing and terminalling 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 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 13.
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents
	We maintain cash and cash equivalents in accounts with large, national 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, 2014 and 2013.
Inventory, Policy [Policy Text Block]	Inventory
	Inventory consists of refined products, which are stated at the lower of cost or market on a 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 pipeline improvements	15-40
	Pipelines and terminals	15-40
	Asset retirement obligation assets	15-50
	Other equipment	15-Mar
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, 2014, 2013, or 2012.
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 valuations from third party financial and brokerage institutions. During the years ended December 31, 2014, 2013, and 2012, 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.
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 14 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, 2014 or 2013, 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 is primarily self-insured for workers' compensation and general liability costs, with varying limits of per claim and aggregate stop loss insurance coverage that management considers adequate. Delek has umbrella liability insurance in an amount determined reasonable by Delek's management.
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.
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 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 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. 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.
	Prior to our Offering, the Predecessor was a corporation included in its parent's consolidated tax return. As such, the Predecessor was subject to both federal and state income taxes and recorded 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.
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. Awards vest over a five-year service period. The phantom unit awards are settled in units.
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. 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 incentive distribution rights 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 incentive distribution rights to our general partner, which is the holder of the incentive distribution rights 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 incentive distribution rights. 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 incentive distribution rights 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 incentive distribution rights to our general partner, which is the holder of the incentive distribution rights 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, 2014, 2013, and 2012 was equivalent to net income.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Pronouncements
	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, 2016, 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 effect that adopting this new standard will have on our consolidated financial statements and related disclosures

Equity_Equity_Policies

Equity Equity (Policies)	12 Months Ended
	Dec. 31, 2014
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_V

Fair Value Measurements Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2014
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 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 using quotations provided by brokers 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, 2014
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 pipeline improvements	15-40
	Pipelines and terminals	15-40
	Asset retirement obligation assets	15-50
	Other equipment	15-Mar
	Property, plant and equipment, at cost, consist of the following (in thousands):
			December 31,
			2014			2013
	Land and land improvements		$	2,000		$	1,931
	Building and building improvements		1,169			1,057
	Pipelines and terminals		266,196			229,672
	Asset retirement obligations		2,073			1,999
	Other equipment		3,764			2,959
	Construction in process		18,323			26,454
			293,525			264,072
	Less: accumulated depreciation		(52,992		)	(39,566		)
			$	240,533		$	224,506
	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2014 and 2013 are as follows (in thousands):
			As of and For the Year Ended December 31, 2014
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	227,927		$	65,598		$	293,525
	Less: Accumulated depreciation		(36,459		)	(16,533		)	(52,992		)
	Property, plant and equipment, net		$	191,468		$	49,065		$	240,533
	Depreciation expense		$	10,395		$	3,247		$	13,642
			As of and For the Year Ended December 31, 2013
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	200,001		$	64,071		$	264,072
	Less: Accumulated depreciation		(25,128		)	(14,438		)	(39,566		)
	Property, plant and equipment, net		$	174,873		$	49,633		$	224,506
	Depreciation expense		$	9,928		$	2,747		$	12,675
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, 2014 and 2013 is as follows (in thousands):
			December 31,
			2014			2013
	Beginning balance		$	3,087		$	3,263
	Liabilities settled		—			(400		)
	Accretion expense		232			224
	Ending balance		$	3,319		$	3,087

Acquisitions_Tables

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2014
Business Acquisition [Line Items]
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 (1)				North Little Rock Terminal(2)				Hopewell(2)				Big Sandy		Nettleton Pipeline
	Property, plant and equipment	$	11,055			$	10,000			$	4,990			$	3,538			$	8,258	$	8,590
	Intangible assets	—				—				10				984				1,229		2,240
	Goodwill (3)	—				—				—				1,200				1,540		1,415
	Inventory	—				1,125				—				—				—		—
	Accounts Receivable	1,871				—				—				—				—		—
	Accounts Payable	(1,401		)		—				—				—				—		—
	Total	$	11,525			$	11,125			$	5,000			$	5,722			$	11,027	$	12,245
	(1)	Allocations are preliminary. The property, plant and equipment valuation is subject to change during the purchase price allocation period.
	(2)	During the second quarter of 2014, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed.
Business Acquisition, Pro Forma Information [Table Text Block]	The following amounts associated with the third party acquisitions described above, subsequent to each respective acquisition date, are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands) for the year ended December 31, 2014:
			Year Ended
			31-Dec-14
	FTT Assets:
	Total operating revenues contributed		$	531
	Net income contributed		$	122
	Greenville-Mount Pleasant Assets:
	Total operating revenues contributed		$	172
	Net loss contributed		$	(109	)
	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				2013
	FTT Assets:
	Net Sales		$	854,842			$	921,017
	Net income		$	71,820			$	34,433
	Greenville-Mount Pleasant Assets:
	Net Sales		$	841,943			$	908,118
	Net income		$	70,617			$	33,230
	Below are the unaudited pro forma consolidated results of operations of the Partnership for the years ended December 31, 2013 and 2012, as if our 2013 acquisitions had occurred on January 1, 2012 (in thousands):
			Year Ended December 31,
			2013				2012
	North Little Rock Terminal:
	Net Sales		$	908,867			1,024,025
	Net income		$	34,958			15,157
	Hopewell:
	Net Sales		$	908,382			1,023,540
	Net income		$	33,981			14,180
	Below are the unaudited pro forma consolidated results of the Partnership for the year ended December 31, 2012, as if our 2012 acquisitions had occurred on January 1, 2011 (in thousands):
			Year Ended
			31-Dec-12
	Nettleton and Big Sandy:
	Net Sales		$	1,022,715
	Net income		$	13,989
	The following amounts associated with the El Dorado Terminal and Tank Assets, subsequent to February 10, 2014, are included in the consolidated statements of income and comprehensive income of the Partnership (in thousands):
			Year Ended
			31-Dec-14
	El Dorado Terminal and Tank Assets
	Total operating revenues		$	15,809
	Net income attributable to the Partnership		$	10,481
	Costs associated with the acquisition		$	186
Business Combination, Financial Information [Table Text Block]	Consolidated Balance Sheet as of December 31, 2013
			Delek Logistics				El Dorado Terminal and Tank Assets				Delek Logistics Partners, LP
			Partners, LP				(El Dorado Predecessor)				31-Dec-13
							(In thousands)
	ASSETS
	Current Assets:
	Cash and cash equivalents		$	924			$	—			$	924
	Accounts receivable		28,976				—				28,976
	Inventory		17,512				—				17,512
	Deferred tax assets		12				—				12
	Other current assets		341				—				341
	Total current assets		47,765				—				47,765
	Property, plant and equipment:
	Property, plant and equipment		234,272				29,800				264,072
	Less: accumulated depreciation		(36,306		)		(3,260		)		(39,566		)
	Property, plant and equipment, net		197,966				26,540				224,506
	Goodwill		11,654				—				11,654
	Intangible assets, net		12,374				—				12,374
	Other non-current assets		5,045				—				5,045
	Total assets		$	274,804			$	26,540			$	301,344
	LIABILITIES AND EQUITY
	Current liabilities:
	Accounts payable		$	26,045			$	—			$	26,045
	Accounts payable to related parties		1,513				—				1,513
	Excise and other taxes payable		5,700				—				5,700
	Accrued expenses and other current liabilities		4,732				—				4,732
	Tank inspection liabilities		1,044				675				1,719
	Total current liabilities		39,034				675				39,709
	Non-current liabilities:
	Revolving credit facility		164,800				—				164,800
	Asset retirement obligations		2,993				94				3,087
	Deferred tax liability		324				—				324
	Other non-current liabilities		5,612				610				6,222
	Total non-current liabilities		173,729				704				174,433
	Equity:
	Predecessors division equity		—				25,161				25,161
	Common unitholders - public (9,353,240 units issued and outstanding)		183,839				—				183,839
	Common unitholders - Delek (2,799,258 units issued and outstanding)		(176,680		)		—				(176,680		)
	Subordinated unitholders - Delek (11,999,258 units issued and outstanding)		59,386				—				59,386
	General Partner unitholders - Delek (492,893 units issued and outstanding)		(4,504		)		—				(4,504		)
	Total equity		62,041				25,161				87,202
	Total liabilities and equity		$	274,804			$	26,540			$	301,344
	Consolidated Statements of Income
			Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Year Ended December 31, 2014
	(In thousands)						(El Dorado Predecessor)
	Net Sales		$	841,253			$	—			$	841,253
	Operating costs and expenses:
	Cost of goods sold		697,221				—				697,221
	Operating expenses		38,003				783				38,786
	General and administrative expenses		10,570				46				10,616
	Depreciation and amortization		14,591				114				14,705
	Loss on asset disposals		83				—				83
	Total operating costs and expenses		760,468				943				761,411
	Operating income (loss)		80,785				(943		)		79,842
	Interest expense, net		8,656				—				8,656
	Net income (loss) before income tax expense		72,129				(943		)		71,186
	Income tax expense		132				—				132
	Net income (loss)		71,997				(943		)		71,054
	Less: loss attributable to Predecessors		—				(943		)		(943		)
	Net income attributable to partners		$	71,997			$	—			$	71,997
			Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Tyler Terminal and Tank Assets				Year Ended December 31, 2013
	(In thousands)						(El Dorado Predecessor)				(Tyler Predecessor)
	Net Sales		$	907,428			$	—			$	—			$	907,428
	Operating costs and expenses:
Cost of goods sold		811,364				—				—				811,364
Operating expenses		25,801				5,338				4,501				35,640
General and administrative expenses		6,254				670				602				7,526
Depreciation and amortization		10,686				1,302				1,750				13,738
Loss on asset disposals		166				—				—				166
Total operating costs and expenses		854,271				7,310				6,853				868,434
Operating income (loss)		53,157				(7,310		)		(6,853		)		38,994
Interest expense, net		4,570				—				—				4,570
Net income (loss) before income tax expense		48,587				(7,310		)		(6,853		)		34,424
Income tax expense		757				—				—				757
Net income (loss)		47,830				(7,310		)		(6,853		)		33,667
Less: loss attributable to Predecessors		—				(7,310		)		(6,853		)		(14,163		)
Net income attributable to partners		$	47,830			$	—			$	—			$	47,830
		Delek Logistics Partners, LP				El Dorado Terminal and Tank Assets				Tyler Terminal and Tank Assets				Year Ended December 31, 2012
(In thousands)						(El Dorado Predecessor)				(Tyler Predecessor)				(Predecessors)
Net Sales		$	1,022,586			$	—			$	—			$	1,022,586
Operating costs and expenses:
Cost of goods sold		959,434				—				—				959,434
Operating expenses		23,362				9,023				7,035				39,420
General and administrative expenses		8,389				706				761				9,856
Depreciation and amortization		8,675				1,223				1,445				11,343
Gain on disposal of assets		9				—				—				9
Total operating costs and expenses		999,869				10,952				9,241				1,020,062
Operating income (loss)		22,717				(10,952		)		(9,241		)		2,524
Interest expense, net		2,682				—				—				2,682
Income (loss) before income tax expense		20,035				(10,952		)		(9,241		)		(158		)
Income tax benefit		(14,024		)		—				—				(14,024		)
Net income (loss)		34,059				(10,952		)		(9,241		)		13,866
Less: income (loss) attributable to Predecessors		25,649				(10,952		)		(9,241		)		5,456
Net income attributable to partners		$	8,410			$	—			$	—			$	8,410

Net_Income_Per_Unit_Tables

Net Income Per Unit (Tables)	12 Months Ended
	Dec. 31, 2014
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,
			2014		2013		2012
	Net income attributable to partners		$	71,997	$	47,830	$	8,410
	Less: General partner's distribution (including IDRs) (1)		1,883		785		110
	Less: Limited partners' distribution		23,152		19,292		2,688
	Less: Subordinated partner's distribution		22,799		19,199		2,688
	Earnings in excess of distributions		$	24,163	$	8,554	$	2,924
	General partner's earnings:
	Distributions (including IDRs) (1)		$	1,883	$	785	$	110
	Allocation of earnings in excess of distributions		483		172		58
	Total general partner's earnings		$	2,366	$	957	$	168
	Limited partners' earnings on common units:
	Distributions		$	23,152	$	19,292	$	2,688
	Allocation of earnings in excess of distributions		11,933		4,198		1,433
	Total limited partners' earnings on common units		$	35,085	$	23,490	$	4,121
	Limited partners' earnings on subordinated units:
	Distributions		$	22,799	$	19,199	$	2,688
	Allocation of earnings in excess of distributions		11,747		4,184		1,433
	Total limited partner's earnings on subordinated units		$	34,546	$	23,383	$	4,121
	Weighted average limited partner units outstanding:
	Common units - (basic)		12,171,548		12,025,249		11,999,258
	Common units - (diluted)		12,302,629		12,148,774		11,999,258
	Subordinated units - Delek (basic and diluted)		11,999,258		11,999,258		11,999,258
	Net income per limited partner unit:
	Common - (basic)		$	2.88	$	1.95	$	0.34
	Common - (diluted)		$	2.85	$	1.93	$	0.34
	Subordinated - (basic and diluted)		$	2.88	$	1.95	$	0.34
	(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 11 for further discussion related to IDRs.

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
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 pipeline improvements	15-40
	Pipelines and terminals	15-40
	Asset retirement obligation assets	15-50
	Other equipment	15-Mar
	Property, plant and equipment, at cost, consist of the following (in thousands):
			December 31,
			2014			2013
	Land and land improvements		$	2,000		$	1,931
	Building and building improvements		1,169			1,057
	Pipelines and terminals		266,196			229,672
	Asset retirement obligations		2,073			1,999
	Other equipment		3,764			2,959
	Construction in process		18,323			26,454
			293,525			264,072
	Less: accumulated depreciation		(52,992		)	(39,566		)
			$	240,533		$	224,506
	Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the years ended December 31, 2014 and 2013 are as follows (in thousands):
			As of and For the Year Ended December 31, 2014
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	227,927		$	65,598		$	293,525
	Less: Accumulated depreciation		(36,459		)	(16,533		)	(52,992		)
	Property, plant and equipment, net		$	191,468		$	49,065		$	240,533
	Depreciation expense		$	10,395		$	3,247		$	13,642
			As of and For the Year Ended December 31, 2013
			Pipelines and Transportation			Wholesale Marketing and Terminalling			Consolidated
	Property, plant and equipment		$	200,001		$	64,071		$	264,072
	Less: Accumulated depreciation		(25,128		)	(14,438		)	(39,566		)
	Property, plant and equipment, net		$	174,873		$	49,633		$	224,506
	Depreciation expense		$	9,928		$	2,747		$	12,675

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2011	$	7,499	$	—	$	7,499
	Acquisitions		—		2,955		2,955
	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

Other_Intangibles_Tables

Other Intangibles (Tables)	12 Months Ended
	Dec. 31, 2014
Other Intangible Assets Disclosure [Abstract]
Schedule of Intangible Assets [Table Text Block]
		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	8,071		—			8,071
	Total		$	20,298	$	(8,949	)	$	11,349
		Useful			Accumulated
	As of December 31, 2013	Life	Gross		Amortization			Net
	Intangible assets subject to amortization:
	Supply contracts (Gross)	11.5	$	12,227	$	(7,885	)	$	4,342
	Intangible assets not subject to amortization:
	Rights-of-way assets	Indefinite	8,032		—			8,032
	Total		$	20,259	$	(7,885	)	$	12,374

LongTerm_Obligations_and_Short1

Long-Term Obligations and Short-Term Note Payable (Tables)	12 Months Ended
	Dec. 31, 2014
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, 2014 (in thousands):
		2015		2016		2017		2018		2019		Thereafter		Total
	Second Amended and Restated Credit Agreement	$	—	$	—	$	—	$	—	$	251,750	$	—	$	251,750

Equity_Tables

Equity (Tables)	12 Months Ended
	Dec. 31, 2014
Equity [Abstract]
Schedule of Capital Units [Table Text Block]	The table below summarizes the changes in the number of units outstanding through December 31, 2014 (in units). There were no units outstanding prior to our initial public offering in November 2012.
		Common - Public			Common - Delek			Subordinated		General Partner		Total
	Units issued in initial public 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	63,949			—			—		—		63,949
	Balance at December 31, 2014	9,417,189			2,799,258			11,999,258		494,197		24,709,902
	(1) Unit-based compensation awards are presented net of 5,539 units withheld for taxes.
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,
		2014				2013			2012
	Net income attributable to partners	$	71,997			$	47,830		$	8,410
	Less: General partner's IDRs	(945		)		—			—
	Net income available to partners	$	71,052			$	47,830		$	8,410
	General partner's ownership interest	2		%		2		%	2		%
	General partner's allocated interest in net income	1,421				957			168
	General partner's IDRs	945				—			—
	Total general partner's interest in net income	$	2,366			$	957		$	168
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 incentive distribution rights, 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		$	0.375			98	%	2	%
	First Target Distribution	above	$	0.375			98	%	2	%
		up to	$	0.43125
	Second Target Distribution	above	$	0.43125			85	%	15	%
		up to	$	0.46875
	Third Target Distribution	above	$	0.46875			75	%	25	%
		up to	$	0.5625
	Thereafter	thereafter	$	0.5625			50	%	50	%
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 general partner IDRs (in thousands)			Date of Distribution	Unitholders Record Date
	31-Dec-13	$	0.415			$	1.66		$	10,228		February 13, 2014	February 4, 2014
	31-Mar-14	$	0.425			$	1.7		$	10,474		May 14, 2014	May 6, 2014
	30-Jun-14	$	0.475			$	1.9		$	11,910		August 14, 2014	August 7, 2014
	30-Sep-14	$	0.49			$	1.96		$	12,394		November 14, 2014	November 6, 2014
	31-Dec-14	$	0.51			$	2.04		$	13,056		February 13, 2015	February 6, 2015
	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,
		2014				2013			2012
	Net income attributable to partners	$	71,997			$	47,830		$	8,410
	Less: General partner's IDRs	(945		)		—			—
	Net income available to partners	$	71,052			$	47,830		$	8,410
	General partner's ownership interest	2		%		2		%	2		%
	General partner's allocated interest in net income	1,421				957			168
	General partner's IDRs	945				—			—
	Total general partner's interest in net income	$	2,366			$	957		$	168
	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,
		2014				2013			2012
	General partner's distributions:
	General partner's distributions	938				$	785		$	110
	General partner's incentive distribution rights	945				—			—
	Total general partner's distributions	1,883				785			110
	Limited partners' distributions:
	Common	23,152				19,292			$	2,688
	Subordinated	22,799				19,199			$	2,688
	Total limited partners' distributions	45,951				38,491			5,376
	Total cash distributions	$	47,834			$	39,276		$	5,486
	Cash distributions per limited partner unit	$	1.9			$	1.6		$	0.224

Equity_Based_Compensation_Tabl

Equity Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
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 twelve months ended December 31, 2014 is set forth below:
			Number of Phantom Units		Weighted-Average Grant Price
	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

Segment_Data_Tables

Segment Data (Tables)	12 Months Ended
	Dec. 31, 2014
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,
		2014 (1) (3)		2013 (2) (4)		2012 (2) (4)
	Pipelines and Transportation
	Net Sales:
	Affiliate	$	80,683	$	51,878	$	30,145
	Third-Party	10,665		8,359		3,394
	Total Pipelines and Transportation	$	91,348	$	60,237	$	33,539
	Operating costs and expenses:
	Cost of goods sold	4,294		764		—
	Operating expenses	31,300		27,465		32,359
	Segment contribution margin	$	55,754	$	32,008	$	1,180
	Capital spending (excluding business combinations)	$	3,768	$	9,621	$	23,845
	Wholesale Marketing and Terminalling
	Net Sales:
	Affiliate	$	33,900	$	26,295	$	13,469
	Third-Party	716,005		820,896		975,578
	Total Wholesale Marketing and Terminalling	$	749,905	$	847,191	$	989,047
	Operating costs and expenses:
	Cost of goods sold	692,927		810,600		959,434
	Operating expenses	7,486		8,175		7,061
	Segment contribution margin	$	49,492	$	28,416	$	22,552
	Capital spending (excluding business combinations)	$	3,364	$	3,041	$	6,971
	Consolidated
	Net Sales:
	Affiliate	$	114,583	$	78,173	$	43,614
	Third-Party	726,670		829,255		978,972
	Total Consolidated	$	841,253	$	907,428	$	1,022,586
	Operating costs and expenses:
	Cost of goods sold	697,221		811,364		959,434
	Operating expenses	38,786		35,640		39,420
	Contribution margin	105,246		60,424		23,732
	General and administrative expenses	10,616		7,526		9,856
	Depreciation and amortization	14,705		13,738		11,343
	Loss on asset disposals	83		166		9
	Operating income	$	79,842	$	38,994	$	2,524
	Capital spending (excluding business combinations)	$	7,132	$	12,662	$	30,816
	(1) The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
	(2) The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
	(3) Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
	(4) Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
	The following table summarizes the total assets for each segment as of December 31, 2014 and December 31, 2013 (in thousands).
		Year Ended December 31,
		2014		2013
	Pipelines and Transportation	210,846		195,984
	Wholesale Marketing and Terminalling	100,993		105,360
	Total Assets	$	311,839	$	301,344

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
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, 2014 and 2013 was as follows: (in thousands):
		As of December 31, 2014
		Level 1		Level 2			Level 3		Total
	Assets
	Interest rate derivatives	$	—	$	24		$	—	$	24
	Commodity derivatives	—		456			—		456
	Total assets	—		480			—		480
	Liabilities
	Commodity Derivatives	—		(61		)	—		(61		)
	Net Assets	$	—	$	419		$	—	$	419
		As of December 31, 2013
		Level 1		Level 2			Level 3		Total
	Assets
	Interest rate derivatives	$	—	$	116		$	—	$	116

Derivative_Instruments_Tables

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments, Gain (Loss) [Table Text Block]	ains (losses) associated with derivatives not designated as hedging instruments for the years ended December 31, 2014 and 2013 were as follows (in thousands):
			Year Ended December 31,
	Derivative Type	Income Statement Location	2014			2013			2012
	Interest rate derivatives	Interest expense	$	(92	)	$	(106	)	$	—
	Commodity derivatives	Cost of goods sold	3,083			(614		)	85
		Total	$	2,991		$	(720	)	$	85
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, 2014 and 2013. 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 differ from the amounts presented in our consolidated balance sheets. During the years ended December 31, 2014 and 2013, 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, 2014						December 31, 2013
	Derivative Type	Balance Sheet Location	Assets			Liabilities			Assets		Liabilities
	Derivatives not designated as hedging instruments:
	Interest rate derivatives	Other long term assets	$	24		$	—		$	116	$	—
	Commodity derivatives (1)	Other current assets	456			(61		)	—		—
	Total gross value of derivatives		$	480		$	(61	)	$	116	$	—
	Less: Counterparty netting and cash collateral (2)		(61		)	61			—		—
	Total net fair value of derivatives		$	419		$	—		$	116	$	—
	(1)	As of December 31, 2014, we had open derivative contracts representing 142,000 barrels of refined petroleum products. As of December 31, 2013, we had no open derivative contracts.
	(2)	As of December 31, 2014 and December 31, 2013, no cash collateral associated with our commodity derivatives has been netted with the derivative positions with each counterparty.

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
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,
		2014			2013			2012
	Provision for federal income taxes at statutory rate	$	—		$	—		4,047
	State income taxes, net of federal tax provision	492			794			(58		)
	Valuation allowance	—			—			193
	Permanent differences	—			—			300
	Conversion to partnership	—			—			(18,534		)
	Other items	(360		)	(37		)	28
	Income tax (benefit) expense	$	132		$	757		$	(14,024	)
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	Income tax expense (benefit) is as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Current	$	241		$	448		$	4,738
	Deferred	(109		)	309			(18,762		)
		$	132		$	757		$	(14,024	)

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2014
Related Party Transaction [Line Items]
Commercial Agreements [Table Text Block]	These 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)		Nov-12		15-May	Crude oil and refined products transportation		46,000 (2)	$ 0 .92 (3)
	Refined Products Pipelines		Nov-12		15-May			40,000	$	0.109
	SALA Gathering System		Nov-12		15-May	Crude oil gathering		14,000	$ 2.44 (3)
	East Texas Crude Logistics System:
	Crude Oil Pipelines		Nov-12		15-May	Crude oil transportation and storage		35,000	$ 0.43 (4)
	Storage		Nov-12		15-May			N/A	$271,640/month
	East Texas Marketing		Nov-12		10 (5)	Marketing products for Tyler Refinery		50,000	$0.616/bbl (5)
	Memphis Terminal		Nov-12		15-May	Dedicated terminalling services		10,000	$	0.54
	Big Sandy Terminal: (6)
	Refined Products Transportation		Nov-12		15-May	Refined products transportation, dedicated terminalling services and storage for the Tyler Refinery		5,000	$	0.54
	Terminalling		Nov-12		15-May			5,000	$	0.54
	Storage		Nov-12		15-May			N/A	$54,280/month
	Tyler Throughput and Tankage:
	Refined Products Throughput		Jul-13		16-Aug	Dedicated Terminalling and storage		50,000	$	0.36
	Storage		Jul-13		16-Aug			N/A	$855,041/month
	Tyler Lease and Access		Jul-13		50	Real property lease		N/A	$100 annually
	Tyler Site Services		Jul-13		16-Aug	Shared services		N/A	$203,178 annually
	North Little Rock Terminal:
	Terminalling		Oct-13		16-Aug	Dedicated terminalling and storage services		8,100	$ 0.23 (7)
	Storage		Oct-13		16-Aug			N/A	$64,001/month (7)
	El Dorado Throughput and Tankage:
	Refined Products Throughput		Feb-14		16-Aug	Dedicated terminalling and storage		11,000	$0.51/bbl
	Storage		Feb-14		16-Aug			N/A	$1,319,641/month
	El Dorado Lease and Access		Feb-14		50	Real property lease		N/A	$100 annually
	El Dorado Site Services		Feb-14		16-Aug	Shared services		N/A	$203,178 annually
	-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 $0.652/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	Pursuant to the agreement, capital projects are to be completed in two phases in order to support and enhance blending activities at the terminal. Upon completion of phase II capital projects, the minimum throughput fees will decrease and storage fees will increase.
Schedule of Related Party Transactions [Table Text Block]	A summary of revenue and expense transactions with Delek, including expenses directly charged and allocated to our Predecessors, are as follows (in thousands):
			Year Ended December 31,
			2014				2013			2012
	Revenues		$	114,583			$	78,173		$	43,614
	Operating and maintenance expenses (1)		$	20,210			$	16,068		$	4,678
	General and administrative expenses (2)		$	5,799			$	4,010		$	5,650

Selected_Quarterly_Financial_D1

Selected Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2014
Selected Quarterly Financial Information [Abstract]
Quarterly Financial Information [Text Block]	Selected Quarterly Financial Data (Unaudited)
	Quarterly financial information for the years ended December 31, 2014 and 2013 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On February 10, 2014, we acquired the El Dorado Terminal and Tank Assets and on July 26, 2013, we acquired the Tyler Terminal and Tank Assets. Our and our Predecessors' historical financial statements have been retrospectively adjusted to reflect the results of operations attributable to the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.
			For the Three Month Periods Ended
			March 31, 2014 (1)		30-Jun-14		30-Sep-14		31-Dec-14
	Net sales		$	203,527	$	236,343	$	228,036	$	173,347
	Operating income		$	15,859	$	24,377	$	17,488	$	22,118
	Net income		$	13,729	$	21,754	$	15,085	$	20,486
	Limited partners' interest in net income		$	14,379	$	21,134	$	14,487	$	19,631
	Net income per limited partner unit:
	Common (basic)		$	0.6	$	0.88	$	0.6	$	0.81
	Common (diluted)		$	0.59	$	0.87	$	0.59	$	0.8
	Subordinated - Delek (basic and diluted)		$	0.6	$	0.87	$	0.6	$	0.81
	(1)	The information presented includes the results of operations of the El Dorado Predecessor
			For the Three Month Periods Ended
			March 31, 2013 (1) (2)		June 30, 2013 (1) (2)		September 30, 2013 (2)		December 31, 2013 (2)
	Net sales		$	210,894	$	230,141	$	243,295	$	223,097
	Operating income		$	8,210	$	7,443	$	10,986	$	12,355
	Net income		$	7,271	$	6,573	$	9,485	$	10,338
	Limited partners' interest in net income		$	11,960	$	11,521	$	12,295	$	11,098
	Net income per limited partner unit:
	Common (basic)		$	0.5	$	0.48	$	0.51	$	0.46
	Common (diluted)		$	0.5	$	0.47	$	0.51	$	0.46
	Subordinated - Delek (basic and diluted)		$	0.5	$	0.48	$	0.51	$	0.46
	(1)	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor.
	(2)	The information presented includes the results of operations of the El Dorado Predecessor.
Schedule of Quarterly Financial Information [Table Text Block]	Quarterly financial information for the years ended December 31, 2014 and 2013 is summarized below. The quarterly financial information summarized below has been prepared by management and is unaudited (in thousands, except per unit data). On February 10, 2014, we acquired the El Dorado Terminal and Tank Assets and on July 26, 2013, we acquired the Tyler Terminal and Tank Assets. Our and our Predecessors' historical financial statements have been retrospectively adjusted to reflect the results of operations attributable to the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets as if we owned the assets for all periods presented.
			For the Three Month Periods Ended
			March 31, 2014 (1)		30-Jun-14		30-Sep-14		31-Dec-14
	Net sales		$	203,527	$	236,343	$	228,036	$	173,347
	Operating income		$	15,859	$	24,377	$	17,488	$	22,118
	Net income		$	13,729	$	21,754	$	15,085	$	20,486
	Limited partners' interest in net income		$	14,379	$	21,134	$	14,487	$	19,631
	Net income per limited partner unit:
	Common (basic)		$	0.6	$	0.88	$	0.6	$	0.81
	Common (diluted)		$	0.59	$	0.87	$	0.59	$	0.8
	Subordinated - Delek (basic and diluted)		$	0.6	$	0.87	$	0.6	$	0.81
	(1)	The information presented includes the results of operations of the El Dorado Predecessor
			For the Three Month Periods Ended
			March 31, 2013 (1) (2)		June 30, 2013 (1) (2)		September 30, 2013 (2)		December 31, 2013 (2)
	Net sales		$	210,894	$	230,141	$	243,295	$	223,097
	Operating income		$	8,210	$	7,443	$	10,986	$	12,355
	Net income		$	7,271	$	6,573	$	9,485	$	10,338
	Limited partners' interest in net income		$	11,960	$	11,521	$	12,295	$	11,098
	Net income per limited partner unit:
	Common (basic)		$	0.5	$	0.48	$	0.51	$	0.46
	Common (diluted)		$	0.5	$	0.47	$	0.51	$	0.46
	Subordinated - Delek (basic and diluted)		$	0.5	$	0.48	$	0.51	$	0.46
	(1)	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor.
	(2)	The information presented includes the results of operations of the El Dorado Predecessor.

General_Details

General (Details)	0 Months Ended
	Jul. 26, 2013	Feb. 10, 2014
Tyler Terminal and Tanks [Member]
Business Acquisition [Line Items]
Number of Storage Tanks	96
El Dorado Terminal and Tanks [Member]
Business Acquisition [Line Items]
Number of Storage Tanks		158

Accounting_Policies_Reclassifi

Accounting Policies Reclassifications (Details) (Goodwill [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Goodwill [Member]
Prior Period Reclassification Adjustment	$1.20

Accounting_Policies_Accounts_R

Accounting Policies Accounts Receivable (Details) (Accounts Receivable [Member], Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Largest customer [Member]
Concentration Risk [Line Items]
Number of Customers	1
Concentration Risk, Percentage	21.00%
Largest Two Customers [Member]
Concentration Risk [Line Items]
Number of Customers		2
Concentration Risk, Percentage		27.20%

Accounting_Policies_Inventory_

Accounting Policies Inventory (Details) (Wholesale Marketing and Terminalling, Supplier Concentration Risk [Member], Inventory purchased [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Wholesale Marketing and Terminalling | Supplier Concentration Risk [Member] | Inventory purchased [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	69.00%	96.10%	76.10%
Number Of Suppliers	1	2	2

Accounting_Policies_Property_P

Accounting Policies Property, Plant and Equipment (Details)	12 Months Ended
	Dec. 31, 2014
Minimum [Member] | Building and Pipeline Improvements [Member]
Estimated useful life (years)	15 years
Minimum [Member] | Pipelines 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 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) (Supply contracts [Member])	12 Months Ended
	Dec. 31, 2014
Supply contracts [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months

Accounting_Policies_Asset_Reti

Accounting Policies Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$3,087	[1]	$3,263
Liabilities settled	0		-400
Accretion expense	232		224	[2]	194	[2]
Ending balance	$3,319		$3,087	[1]	$3,263
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Accounting_Policies_Operating_

Accounting Policies Operating Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accounting Policies [Abstract]
Operating Leases, Rent Expense	$0.70	$0.70	$0.60

Accounting_Policies_Income_tax

Accounting Policies Income taxes (Details) (USD $)	2 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Accounting Policies [Abstract]
Income tax expense	$100	$132	$757	[1]	($14,024)	[1]
Tax benefit from conversion to Partnership		$0	$0		$18,534
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Accounting_Policies_Equity_bas

Accounting Policies Equity based compensation (Details)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Awards requisite service period (years)	5 years

Accounting_Policies_Net_income

Accounting Policies Net income per limited partner unit (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Accounting Policies [Abstract]
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	2.00%	2.00%	2.00%

Acquisitions_El_Dorado_and_Tyl

Acquisitions El Dorado and Tyler Acquisitions (Details) (USD $)	0 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended
	Jul. 26, 2013	Dec. 31, 2014	Feb. 10, 2014	Dec. 31, 2013
	bbl		bbl
Tyler Terminal and Tanks [Member]
Business Acquisition [Line Items]
Cash paid for acquisition	$94,800,000	$94,800,000
Total Throughput Capacity (bpd)	72,000
Number of Storage Tanks	96
Aggregate Shell Capacity (barrels)	2,000,000
Historical carrying value of assets	38,300,000
El Dorado Terminal and Tanks [Member]
Business Acquisition [Line Items]
Cash paid for acquisition			95,900,000	95,900,000
Total Throughput Capacity (bpd)			26,700
Number of Storage Tanks			158
Aggregate Shell Capacity (barrels)			2,500,000
Historical carrying value of assets			25,200,000
Total operating revenues		15,809,000
Net income attributable to the Partnership		10,481,000
General and Administrative Expense [Member] | El Dorado Terminal and Tanks [Member]
Business Acquisition [Line Items]
Costs associated with the acquisition		$186,000

Acquisitions_El_Dorado_and_Tyl1

Acquisitions El Dorado and Tyler Terminals and Tank Assets Financial Results (Details) (USD $)	2 Months Ended		3 Months Ended													12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012		Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Current assets:
Cash and cash equivalents	$23,452	[1]	$1,861					$924	[1],[2]							$1,861		$924	[1],[2]	$23,452	[1]	$35	[1]
Accounts receivable			27,956					28,976	[2]							27,956		28,976	[2]
Inventory			10,316					17,512	[2]							10,316		17,512	[2]
Deferred tax assets			28					12	[2]							28		12	[2]
Other current assets			768					341	[2]							768		341	[2]
Total current assets			40,929					47,765	[2]							40,929		47,765	[2]
Property, Plant and Equipment [Abstract]
Property, plant and equipment			293,525					264,072	[2]							293,525		264,072	[2]
Less: accumulated depreciation			-52,992					-39,566	[2]							-52,992		-39,566	[2]
Property, plant and equipment, net			240,533					224,506	[2]							240,533		224,506	[2]
Goodwill	10,454		11,654					11,654	[2]							11,654		11,654	[2]	10,454		7,499
Intangible assets, net			11,349					12,374	[2]							11,349		12,374	[2]
Other non-current assets			7,374					5,045	[2]							7,374		5,045	[2]
Total assets			311,839					301,344	[2]							311,839		301,344	[2]
Current liabilities:
Accounts payable			18,208					26,045	[2]							18,208		26,045	[2]
Accounts payable to related parties								1,513										1,513
Excise and other taxes payable			5,443					5,700	[2]							5,443		5,700	[2]
Accrued expenses and other current liabilities			1,588					4,732	[2]							1,588		4,732	[2]
Tank inspection liabilities			2,829					1,719	[2]							2,829		1,719	[2]
Total current liabilities			30,595					39,709	[2]							30,595		39,709	[2]
Non-current liabilities:
Revolving credit facility			251,750					164,800	[2]							251,750		164,800	[2]
Asset retirement obligations	3,263		3,319					3,087	[2]							3,319		3,087	[2]	3,263
Deferred tax liabilities			231					324	[2]							231		324	[2]
Other non-current liabilities			5,889					6,222	[2]							5,889		6,222	[2]
Total non-current liabilities			261,189					174,433	[2]							261,189		174,433	[2]
Equity:
Total equity	161,802		20,055					87,202	[2]							20,055		87,202	[2]	161,802		148,324
Total liabilities and equity			311,839					301,344	[2]							311,839		301,344	[2]
Consolidated Statements of Income
Net sales			173,347	228,036	236,343	203,527	[3]	223,097	[4]	243,295	[3],[4]	230,141	[3],[4]	210,894	[3],[4]	841,253	[5],[6]	907,428	[7],[8],[9]	1,022,586	[7],[8],[9]
Operating costs and expenses:
Cost of goods sold																697,221	[5],[6]	811,364	[7],[8],[9]	959,434	[7],[8],[9]
Operating expenses																38,786	[5],[6]	35,640	[7],[8],[9]	39,420	[7],[8],[9]
General and administrative expenses																10,616	[5],[6]	7,526	[7],[8],[9]	9,856	[7],[8],[9]
Depreciation and amortization																14,705	[5],[6]	13,738	[1],[7],[8],[9]	11,343	[1],[7],[8],[9]
Loss on asset disposals																83	[5],[6]	166	[1],[7],[8],[9]	9	[1],[7],[8],[9]
Total operating costs and expenses																761,411	[9]	868,434	[9]	1,020,062	[9]
Operating income (loss)			22,118	17,488	24,377	15,859	[3]	12,355	[4]	10,986	[3],[4]	7,443	[3],[4]	8,210	[3],[4]	79,842	[5],[6],[9]	38,994	[7],[8],[9]	2,524	[7],[8],[9]
Interest expense, net																8,656		4,570	[9]	2,682	[9]
Income (loss) before income tax expense (benefit)																71,186		34,424	[9]	-158	[9]
Income tax expense (benefit)	100															132		757	[9]	-14,024	[9]
Net income (loss)																71,054	[9]	33,667	[9]	13,866	[9]
Less: (loss) income attributable to Predecessors																-943		-14,163	[9]	5,456	[9]
Net income attributable to partners																71,997	[9]	47,830	[9]	8,410	[9]
Delek Logistics Partners, LP
Current assets:
Cash and cash equivalents								924										924
Accounts receivable								28,976										28,976
Inventory								17,512										17,512
Deferred tax assets								12										12
Other current assets								341										341
Total current assets								47,765										47,765
Property, Plant and Equipment [Abstract]
Property, plant and equipment								234,272										234,272
Less: accumulated depreciation								-36,306										-36,306
Property, plant and equipment, net								197,966										197,966
Goodwill								11,654										11,654
Intangible assets, net								12,374										12,374
Other non-current assets								5,045										5,045
Total assets								274,804										274,804
Current liabilities:
Accounts payable								26,045										26,045
Accounts payable to related parties								1,513										1,513
Excise and other taxes payable								5,700										5,700
Accrued expenses and other current liabilities								4,732										4,732
Tank inspection liabilities								1,044										1,044
Total current liabilities								39,034										39,034
Non-current liabilities:
Revolving credit facility								164,800										164,800
Asset retirement obligations								2,993										2,993
Deferred tax liabilities								324										324
Other non-current liabilities								5,612										5,612
Total non-current liabilities								173,729										173,729
Equity:
Total equity								62,041										62,041
Total liabilities and equity								274,804										274,804
Consolidated Statements of Income
Net sales																841,253		907,428		1,022,586
Operating costs and expenses:
Cost of goods sold																697,221		811,364		959,434
Operating expenses																38,003		25,801		23,362
General and administrative expenses																10,570		6,254		8,389
Depreciation and amortization																14,591		10,686		8,675
Loss on asset disposals																83		166		9
Total operating costs and expenses																760,468	[9]	854,271	[9]	999,869	[9]
Operating income (loss)																80,785	[9]	53,157	[9]	22,717	[9]
Interest expense, net																8,656		4,570		2,682
Income (loss) before income tax expense (benefit)																72,129		48,587		20,035
Income tax expense (benefit)																132		757		-14,024
Net income (loss)																71,997	[9]	47,830	[9]	34,059	[9]
Less: (loss) income attributable to Predecessors																0		0		25,649
Net income attributable to partners																71,997	[9]	47,830	[9]	8,410	[9]
Predecessor | El Dorado Terminal and Tanks [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								29,800										29,800
Less: accumulated depreciation								-3,260										-3,260
Property, plant and equipment, net								26,540										26,540
Goodwill								0										0
Intangible assets, net								0										0
Other non-current assets								0										0
Total assets								26,540										26,540
Current liabilities:
Accounts payable								0										0
Accounts payable to related parties								0										0
Excise and other taxes payable								0										0
Accrued expenses and other current liabilities								0										0
Tank inspection liabilities								675										675
Total current liabilities								675										675
Non-current liabilities:
Revolving credit facility								0										0
Asset retirement obligations								94										94
Deferred tax liabilities								0										0
Other non-current liabilities								610										610
Total non-current liabilities								704										704
Equity:
Total equity								25,161										25,161
Total liabilities and equity								26,540										26,540
Consolidated Statements of Income
Net sales																0		0		0
Operating costs and expenses:
Cost of goods sold																0		0		0
Operating expenses																783		5,338		9,023
General and administrative expenses																46		670		706
Depreciation and amortization																114		1,302		1,223
Loss on asset disposals																0		0		0
Total operating costs and expenses																943	[9]	7,310	[9]	10,952	[9]
Operating income (loss)																-943	[9]	-7,310	[9]	-10,952	[9]
Interest expense, net																0		0		0
Income (loss) before income tax expense (benefit)																-943		-7,310		-10,952
Income tax expense (benefit)																0		0		0
Net income (loss)																-943	[9]	-7,310	[9]	-10,952	[9]
Less: (loss) income attributable to Predecessors																-943		-7,310		-10,952
Net income attributable to partners																0	[9]	0	[9]	0	[9]
Predecessor | Tyler Terminal and Tanks [Member]
Consolidated Statements of Income
Net sales																		0		0
Operating costs and expenses:
Cost of goods sold																		0		0
Operating expenses																		4,501		7,035
General and administrative expenses																		602		761
Depreciation and amortization																		1,750		1,445
Loss on asset disposals																		0		0
Total operating costs and expenses																		6,853	[9]	9,241	[9]
Operating income (loss)																		-6,853	[9]	-9,241	[9]
Interest expense, net																		0		0
Income (loss) before income tax expense (benefit)																		-6,853		-9,241
Income tax expense (benefit)																				0
Net income (loss)																		-6,853	[9]	-9,241	[9]
Less: (loss) income attributable to Predecessors																		-6,853		-9,241
Net income attributable to partners																		0	[9]	0	[9]
Predecessor division equity
Equity:
Total equity	57,377		0					25,161	[2]							0		25,161	[2]	57,377		148,324
Operating costs and expenses:
Less: (loss) income attributable to Predecessors																-943		-14,163		5,456
Net income attributable to partners																0		0		0
Predecessor division equity | Delek Logistics Partners, LP
Equity:
Total equity								0										0
Predecessor division equity | Predecessor | El Dorado Terminal and Tanks [Member]
Equity:
Total equity								25,161										25,161
General partner - Delek; 494,197 units issued and outstanding at December 31, 2014 (492,893 at December 31, 2013)
Equity:
Total equity	-49		-7,085					-4,504	[2]							-7,085		-4,504	[2]	-49		0
Operating costs and expenses:
Less: (loss) income attributable to Predecessors																0
Net income attributable to partners																1,440		957		168
General partner - Delek; 494,197 units issued and outstanding at December 31, 2014 (492,893 at December 31, 2013) | Delek Logistics Partners, LP
Equity:
Total equity								-4,504										-4,504
General partner - Delek; 494,197 units issued and outstanding at December 31, 2014 (492,893 at December 31, 2013) | Predecessor | El Dorado Terminal and Tanks [Member]
Equity:
Total equity								0										0
Common unitholders - public; 9,417,189 units issued and outstanding at December 31, 2014 (9,353,240 at December 31, 2013) | Limited Partner [Member]
Equity:
Total equity	178,728		194,737					183,839	[2]							194,737		183,839	[2]	178,728		0
Operating costs and expenses:
Less: (loss) income attributable to Predecessors																0
Net income attributable to partners																27,386		18,035		3,160
Common unitholders - public; 9,417,189 units issued and outstanding at December 31, 2014 (9,353,240 at December 31, 2013) | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total equity								183,839										183,839
Common unitholders - public; 9,417,189 units issued and outstanding at December 31, 2014 (9,353,240 at December 31, 2013) | Limited Partner [Member] | Predecessor | El Dorado Terminal and Tanks [Member]
Equity:
Total equity								0										0
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2014 (2,799,258 at December 31, 2013) | Limited Partner [Member]
Equity:
Total equity	-127,129		-241,112					-176,680	[2]							-241,112		-176,680	[2]	-127,129		0
Operating costs and expenses:
Less: (loss) income attributable to Predecessors																0
Net income attributable to partners																8,166		5,455		960
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2014 (2,799,258 at December 31, 2013) | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total equity								-176,680										-176,680
Common unitholders - Delek; 2,799,258 units issued and outstanding at December 31, 2014 (2,799,258 at December 31, 2013) | Limited Partner [Member] | Predecessor | El Dorado Terminal and Tanks [Member]
Equity:
Total equity								0										0
Subordinated Units [Member] | Limited Partner [Member]
Equity:
Total equity								59,386										59,386
Subordinated Units [Member] | Limited Partner [Member] | Delek Logistics Partners, LP
Equity:
Total equity								59,386										59,386
Subordinated Units [Member] | Limited Partner [Member] | Predecessor | El Dorado Terminal and Tanks [Member]
Equity:
Total equity								$0										$0
[1]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[3]	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor
[4]	The information presented includes the results of operations of the El Dorado Predecessor.
[5]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[6]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
[7]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
[8]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[9]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Acquisitions_from_Third_Partie

Acquisitions from Third Parties (Details)	0 Months Ended
	Oct. 02, 2014	Oct. 24, 2013	Dec. 17, 2014
	bbl	bbl
Frank Thompson Transport [Member]
Business Acquisition [Line Items]
Number of trucks acquired			120
Number of trailers acquired			200
Mount Pleasant Terminal [Member]
Business Acquisition [Line Items]
Storage capacity	200,000
Greenville Terminal [Member]
Business Acquisition [Line Items]
Storage capacity	325,000
North Little Rock Terminal
Business Acquisition [Line Items]
Storage capacity		140,000
Total Throughput Capacity (bpd)		10,000

Acquisitions_Purchase_Price_Al

Acquisitions Purchase Price Allocation (Details) (USD $)	Dec. 17, 2014		Oct. 01, 2014		Oct. 24, 2013		Jul. 19, 2013		Feb. 07, 2012	Jan. 31, 2012
In Thousands, unless otherwise specified
FTT Assets
Business Acquisition [Line Items]
Property, Plant and Equipment	$11,055	[1]
Intangible Assets	0	[1]
Goodwill	0	[1]
Inventory	0	[1]
Accounts Receivable	1,871	[1]
Accounts Payable	-1,401	[1]
Total	11,525	[1]
Greenville-Mount Pleasant Assets
Business Acquisition [Line Items]
Property, Plant and Equipment			10,000	[1]
Intangible Assets			0	[1]
Goodwill			0	[1]
Inventory			1,125	[1]
Accounts Receivable			0	[1]
Accounts Payable			0	[1]
Total			11,125	[1]
North Little Rock Terminal
Business Acquisition [Line Items]
Property, Plant and Equipment					4,990	[2]
Intangible Assets					10	[2]
Goodwill					0	[2]
Inventory					0	[2]
Accounts Receivable					0	[2]
Accounts Payable					0	[2]
Total					5,000	[2]
Hopewell
Business Acquisition [Line Items]
Property, Plant and Equipment							3,538	[2]
Intangible Assets							984	[2]
Goodwill							1,200	[2]
Inventory							0	[2]
Accounts Receivable							0	[2]
Accounts Payable							0	[2]
Total							5,722	[2]
Big Sandy Terminal
Business Acquisition [Line Items]
Property, Plant and Equipment									8,258
Intangible Assets									1,229
Goodwill									1,540
Inventory									0
Accounts Receivable									0
Accounts Payable									0
Total									11,027
Nettleton Pipeline
Business Acquisition [Line Items]
Property, Plant and Equipment										8,590
Intangible Assets										2,240
Goodwill										1,415
Inventory										0
Accounts Receivable										0
Accounts Payable										0
Total										$12,245
[1]	Allocations are preliminary. The property, plant and equipment valuation is subject to change during the purchase price allocation period.
[2]	During the second quarter of 2014, we finalized our purchase price allocation and adjusted certain of the acquisition-date fair values previously disclosed.

Acquisitions_Pro_Forma_Infroma

Acquisitions Pro Forma Infromation (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
FTT Assets
Business Acquisition [Line Items]
Total operating revenues contributed	$531
Net income contributed	122
Net sales	854,842	921,017
Net income	71,820	34,433
Greenville-Mount Pleasant Assets
Business Acquisition [Line Items]
Total operating revenues contributed	172
Net income contributed	-109
Net sales	841,943	908,118
Net income	70,617	33,230
North Little Rock Terminal
Business Acquisition [Line Items]
Net sales		908,867	1,024,025
Net income		34,958	15,157
Hopewell
Business Acquisition [Line Items]
Net sales		908,382	1,023,540
Net income		33,981	14,180
Nettleton and Big Sandy [Member]
Business Acquisition [Line Items]
Net sales			1,022,715
Net income			$13,989

Net_Income_Per_Unit_Textual_De

Net Income Per Unit Textual (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
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 $)	3 Months Ended													12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Net income per unit [Line Items]
Net income attributable to partners														$71,997	[1]	$47,830	[1]	$8,410	[1]
General partner's distribution														1,883	[2]	785	[2]	110	[2]
Limited partners' distribution														45,951		38,491		5,376
Earnings in excess of distributions														24,163		8,554		2,924
Weighted average limited partner units outstanding:
Common units - (basic)														12,171,548		12,025,249		11,999,258
Common units - (diluted)														12,302,629		12,148,774		11,999,258
Subordinated units - Delek (basic and diluted)														11,999,258		11,999,258		11,999,258
Net income per limited partner unit:
Common units - (basic)														$2.88		$1.95		$0.34
Common units - (diluted)														$2.85		$1.93		$0.34
Subordinated units - Delek (basic and diluted)														$2.88		$1.95		$0.34
Limited Partner, Common Units [Member]
Net income per unit [Line Items]
Total earnings														35,085		23,490		4,121
Limited Partner, Subordinated Units [Member]
Net income per unit [Line Items]
Total earnings														34,546		23,383		4,121
General Partner
Net income per unit [Line Items]
General partner's distribution														1,883	[2]	785	[2]	110	[2]
Earnings in excess of distributions														483		172		58
Total earnings														2,366		957		168
Common Units [Member]
Net income per unit [Line Items]
Limited partners' distribution														23,152		19,292		2,688
Weighted average limited partner units outstanding:
Common units - (basic)														12,171,548		12,025,249	[1]	11,999,258	[1]
Common units - (diluted)														12,302,629		12,148,774	[1]	11,999,258	[1]
Net income per limited partner unit:
Common units - (basic)	$0.81	$0.60	$0.88	$0.60	[3]	$0.46	[4]	$0.51	[3],[4]	$0.48	[3],[4]	$0.50	[3],[4]	$2.88		$1.95	[1]	$0.34	[1]
Common units - (diluted)	$0.80	$0.59	$0.87	$0.59	[3]	$0.46	[4]	$0.51	[3],[4]	$0.47	[3],[4]	$0.50	[3],[4]	$2.85		$1.93	[1]	$0.34	[1]
Common Units [Member] | Limited Partner [Member]
Net income per unit [Line Items]
Limited partners' distribution														23,152		19,292		2,688
Earnings in excess of distributions														11,933		4,198		1,433
Subordinated Units [Member]
Net income per unit [Line Items]
Limited partners' distribution														22,799		19,199		2,688
Subordinated Units [Member] | Limited Partner [Member]
Net income per unit [Line Items]
Limited partners' distribution														22,799		19,199		2,688
Earnings in excess of distributions														$11,747		$4,184		$1,433
First target distribution [Member] | Maximum [Member]
Footnote [Abstract]
Distribution Payment Targets														$0.43
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	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 11 for further discussion related to IDRs.
[3]	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor
[4]	The information presented includes the results of operations of the El Dorado Predecessor.

Major_Customer_Details

Major Customer (Details) (Sales Revenue, Net [Member], Customer Concentration Risk [Member])	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Sunoco [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	23.30%	17.70%	17.50%
Delek [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	13.60%	8.60%	23.10%

Inventory_Narrative_Details

Inventory Narrative (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory [Abstract]
Inventory	$10,316	$17,512	[1]
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$293,525	$264,072	[1]
Less: accumulated depreciation	-52,992	-39,566	[1]
Property, plant and equipment, net	240,533	224,506	[1]
Depreciation expense	13,642	12,675
Pipelines and Transportation
Property, Plant and Equipment [Line Items]
Property, plant and equipment	227,927	200,001
Less: accumulated depreciation	-36,459	-25,128
Property, plant and equipment, net	191,468	174,873
Depreciation expense	10,395	9,928
Wholesale Marketing and Terminalling
Property, Plant and Equipment [Line Items]
Property, plant and equipment	65,598	64,071
Less: accumulated depreciation	-16,533	-14,438
Property, plant and equipment, net	49,065	49,633
Depreciation expense	3,247	2,747
Land and land improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,000	1,931
Building and building improvements
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,169	1,057
Pipelines and terminals
Property, Plant and Equipment [Line Items]
Property, plant and equipment	266,196	229,672
Asset retirement obligations
Property, Plant and Equipment [Line Items]
Property, plant and equipment	2,073	1,999
Other equipment
Property, Plant and Equipment [Line Items]
Property, plant and equipment	3,764	2,959
Construction in process
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$18,323	$26,454
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Goodwill_Details

Goodwill (Details) (USD $)	12 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Goodwill, Impairment Loss	$11,700,000		$0		$0
Goodwill [Roll Forward]
Beginning Balance	11,654,000	[1]	10,454,000		7,499,000
Acquisitions			1,200,000		2,955,000
Ending Balance	11,654,000		11,654,000	[1]	10,454,000
Wholesale Marketing and Terminalling
Goodwill [Roll Forward]
Beginning Balance			7,499,000		7,499,000
Acquisitions			0		0
Ending Balance	7,499,000		7,499,000		7,499,000
Pipelines and Transportation
Goodwill [Roll Forward]
Beginning Balance			2,955,000		0
Acquisitions			1,200,000		2,955,000
Ending Balance	$4,155,000		$4,155,000		$2,955,000
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Other_Intangibles_Details

Other Intangibles (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Other Intangible Assets [Line Items]
Accumulated Amortization	($8,949,000)	($7,885,000)
Intangible assets, gross	20,298,000	20,259,000
Intangible assets, net	11,349,000	12,374,000	[1]
Rights-of-Way [Member]
Other Intangible Assets [Line Items]
Rights-of-way assets	8,071,000	8,032,000
Supply contracts [Member]
Other Intangible Assets [Line Items]
Estimated useful life (years)	11 years 6 months
Intangible Assets, Gross	12,227,000	12,227,000
Accumulated Amortization	-8,949,000	-7,885,000
Intangible assets, net	3,278,000	4,342,000
Amortization expense	1,100,000	1,100,000		1,100,000
Amortization Expense, 2015		1,100,000
Amortization Expense, 2016		1,100,000
Amortization Expense, 2017		$1,100,000
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

LongTerm_Obligations_and_Short2

Long-Term Obligations and Short-Term Note Payable Long Term Obligations (Details) (Revolving Credit Facility [Member], Fifth Third Bank [Member], USD $)	12 Months Ended	0 Months Ended
	Dec. 31, 2014	Dec. 30, 2014	Jul. 09, 2013
Line of Credit [Member]
Debt Instrument [Line Items]
Maximum Borrowing Capacity		700,000,000	$400,000,000
Maximum Borrowing Capacity under Accordion Feature		800,000,000
Weighted Average Interest Rate	2.30%
Unused Capacity, Commitment Fee Percentage	0.30%
Holdings Note outstanding amount	102,000,000
Line of Credit Facility, Amount Outstanding	251,750,000
Available borrowing capacity	440,800,000
Letter of Credit [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Amount Outstanding	0
Letters of Credit	$7,500,000
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

LongTerm_Obligations_and_Short3

Long-Term Obligations and Short-Term Note Payable Maturities of Long-term debt (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
2015	$0
2016	0
2017	0
2018	0
2019	251,750
Thereafter	0
Revolving Credit Facility [Member] | Fifth Third Bank [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Total		$251,750

Equity_Details

Equity (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Limited Partners' Capital Account [Line Items]
Delek's Limited Parter Interest	59.90%
Delek's ownership interest in General Partner	95.90%
General partner's ownership interest	2.00%	2.00%	2.00%
General Partner's units	494,197	492,893
Common - Public
Limited Partners' Capital Account [Line Items]
Limited Partners' Capital Account, Units Outstanding	9,417,189	9,353,240
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

Equity_Units_Rollforward_Detai

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

Equity_Net_income_applicable_t

Equity Net income applicable to partners (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Equity [Abstract]
Net income attributable to partners	$71,997	[1]	$47,830	[1]	$8,410	[1]
Less: General partner's IDRs	-945		0		0
Net income available to partners	71,052		47,830		8,410
General partner's ownership interest	2.00%		2.00%		2.00%
General partner's allocated interest in net income	1,421		957		168
General partner's IDRs	945		0		0
Total general partner's interest in net income	$2,366		$957	[1]	$168	[1]
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Equity_Percentage_Allocations_

Equity Percentage Allocations of Available Cash from Operating Surplus (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
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	0.375
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	0.375
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	0.5625
Thereafter [Member]
Incentive Distribution Made to Member or Limited Partner [Line Items]
Distribution Payment Targets	0.5625
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 $)	0 Months Ended					12 Months Ended					0 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Nov. 14, 2014	Oct. 24, 2014	Aug. 14, 2014	14-May-14	Feb. 13, 2014	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012		Feb. 13, 2015	Jan. 27, 2015
Distribution Made to Limited Partner [Line Items]
Quarterly cash distribution (dollars per unit)		$0.49	$0.48	$0.43	$0.42
Distribution Made To Member Or Limited Partner Distributions Paid Annualized Per Unit		$1.96	$1.90	$1.70	$1.66
Cash Distributions Paid	$12,394		$11,910	$10,474	$10,228
General partner's distributions						938	785		110
General partner's IDRs						945	0		0
Total general partner's distributions						1,883	785		110
Limited partners' distribution						45,951	38,491		5,376
Total cash distributions						47,834	39,276		5,486
Cash distributions per limited partner unit						$1.90	$1.60	[1]	$0.22	[1]
Common Units [Member]
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution						23,152	19,292		2,688
Subordinated Units [Member]
Distribution Made to Limited Partner [Line Items]
Limited partners' distribution						22,799	19,199		2,688
Subsequent Event [Member]
Distribution Made to Limited Partner [Line Items]
Quarterly cash distribution (dollars per unit)											$0.51
Distribution Made To Member Or Limited Partner Distributions Paid Annualized Per Unit											$2.04
Cash Distributions Declared												$13,056
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Equity_Based_Compensation_Narr

Equity Based Compensation Narrative (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Awards requisite service period (years)	5 years
Number of units authorized		612,207
Total fair value of vested units	$1.60	$4.20
Unrecognized compensation costs	0.9		0
Unrecognized compensation costs, weighted-average period for recognition	2 years 7 months 30 days
Selling, General and Administrative Expenses [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Unit-based compensation expense	$0.30	$0.50

Equity_Based_Compensation_Unit

Equity Based Compensation Unit Award Activity Summary (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
Unit Award Activity [Roll Forward]
Non-vested, number of phantom units, December 31, 2013	274,952
Granted, number of phantom units	10,000
Vested, number of phantom units	-69,488
Non-vested, number of phantom units, December 31, 2014	215,464
Unit award activity, Weighted Average Grant Date Fair Value [Roll Forward]
Non-vested, weighted-average grant price, January 1, 2013	$22.94
Granted, weighted-average grant price	$35.46
Vested, weighted average grant price	$23.08
Non-vested, weighted-average grant price, December 31, 2013	$23.48

Equity_Based_Compensation_Spon

Equity Based Compensation Sponsor's equity-based compensation (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Equity Based Compensation [Abstract]
Unrecognized compensation costs	$900,000			$0
Share-based compensation expense	0	0	[1]	92,000	[1]
Equity award based compensation expense recognized for allocated related party services				$500,000
[1]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Segment_Data_Details

Segment Data (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2014

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Segment Reporting Information [Line Items]

Affiliate

$114,583

[1],[2]

$78,173

[1],[2],[3]

$43,614

[3],[4],[5]

Third Party

726,670

[1],[2]

829,255

[1],[2],[3]

978,972

[3],[4],[5]

Total Pipelines and Transportation

173,347

228,036

236,343

203,527

[6]

223,097

[7]

243,295

[6],[7]

230,141

[6],[7]

210,894

[6],[7]

841,253

[4],[5]

907,428

[1],[2],[3]

1,022,586

[1],[2],[3]

Operating Costs and Expenses [Abstract]

Cost of goods sold

697,221

[4],[5]

811,364

[1],[2],[3]

959,434

[1],[2],[3]

Operating expenses

38,786

[4],[5]

35,640

[1],[2],[3]

39,420

[1],[2],[3]

Segment Contribution Margin

105,246

[4],[5]

60,424

[1],[2]

23,732

[1],[2]

General and administrative expenses

10,616

[4],[5]

7,526

[1],[2],[3]

9,856

[1],[2],[3]

Depreciation and amortization

14,705

[4],[5]

13,738

[1],[2],[3],[8]

11,343

[1],[2],[3],[8]

Loss on asset disposals

83

[4],[5]

166

[1],[2],[3],[8]

9

[1],[2],[3],[8]

Operating income

22,118

17,488

24,377

15,859

[6]

12,355

[7]

10,986

[6],[7]

7,443

[6],[7]

8,210

[6],[7]

79,842

[3],[4],[5]

38,994

[1],[2],[3]

2,524

[1],[2],[3]

Total assets

311,839

301,344

[9]

311,839

301,344

[9]

Capital spending (excluding business combinations)

7,132

[4],[5]

12,662

[1],[2],[8]

30,816

[1],[2],[8]

Pipelines and Transportation

Segment Reporting Information [Line Items]

Affiliate

80,683

[1],[2]

51,878

[1],[2]

30,145

[4],[5]

Third Party

10,665

[1],[2]

8,359

[1],[2]

3,394

[4],[5]

Total Pipelines and Transportation

91,348

[4],[5]

60,237

[1],[2]

33,539

[1],[2]

Operating Costs and Expenses [Abstract]

Cost of goods sold

4,294

[4],[5]

764

[1],[2]

0

[1],[2]

Operating expenses

31,300

[4],[5]

27,465

[1],[2]

32,359

[1],[2]

Segment Contribution Margin

55,754

[4],[5]

32,008

[1],[2]

1,180

[1],[2]

Total assets

210,846

195,984

210,846

195,984

Capital spending (excluding business combinations)

3,768

[4],[5]

9,621

[1],[2]

23,845

[1],[2]

Wholesale Marketing and Terminalling

Segment Reporting Information [Line Items]

Affiliate

33,900

[1],[2]

26,295

[1],[2]

13,469

[4],[5]

Third Party

716,005

[1],[2]

820,896

[1],[2]

975,578

[4],[5]

Total Pipelines and Transportation

749,905

[4],[5]

847,191

[1],[2]

989,047

[1],[2]

Operating Costs and Expenses [Abstract]

Cost of goods sold

692,927

[4],[5]

810,600

[1],[2]

959,434

[1],[2]

Operating expenses

7,486

[4],[5]

8,175

[1],[2]

7,061

[1],[2]

Segment Contribution Margin

49,492

[4],[5]

28,416

[1],[2]

22,552

[1],[2]

Total assets

100,993

105,360

100,993

105,360

Capital spending (excluding business combinations)

$3,364

[4],[5]

$3,041

[1],[2]

$6,971

[1],[2]

[1]

Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition

[2]

The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

[3]

Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

[4]

The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.

[5]

Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.

[6]

The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor

[7]

The information presented includes the results of operations of the El Dorado Predecessor.

[8]

Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

[9]

Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash collateral	$0	$0
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	480,000
Fair Value, Net Asset (Liability)	419,000
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
Fair Value, Net Asset (Liability)	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, Fair Value Disclosure, Recurring	480,000
Fair Value, Net Asset (Liability)	419,000
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
Fair Value, Net Asset (Liability)	0
Fair Value, Measurements, Recurring [Member] | Interest rate derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	24,000	116,000
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 | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset	24,000	116,000
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] | Commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-61,000
Derivative Asset	456,000
Fair Value, Measurements, Recurring [Member] | Commodity derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0
Derivative Asset	0
Fair Value, Measurements, Recurring [Member] | Commodity derivatives | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	-61,000
Derivative Asset	456,000
Fair Value, Measurements, Recurring [Member] | Commodity derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability	0
Derivative Asset	$0

Derivative_Instruments_Details

Derivative Instruments (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Notional Amount	$45,000,000
Less: Counterparty netting and cash collateral	61,000	0
Less: Counterparty netting and cash collateral	61,000	0
Total net fair value of derivatives	419,000	116,000
Total net fair value of derivatives	0	0
Cash collateral	0	0
Gain (Loss) Recognized in Income	2,991,000	-720,000	85,000
Derivatives not designated as hedging instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Assets	480,000	116,000
Liabilities	-61,000	0
Open derivative contracts (barrels)	142,000
Other long term assets | Derivatives not designated as hedging instrument [Member] | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Assets	24,000	116,000
Derivative Asset, Fair Value, Gross Liability	0	0
Other current assets | Derivatives not designated as hedging instrument [Member] | Commodity derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Assets	456,000	0
Derivative Asset, Fair Value, Gross Liability	-61,000	0
Interest expense | Derivatives not designated as hedging instrument [Member] | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income	-92,000	-106,000	0
Cost of goods sold | Derivatives not designated as hedging instrument [Member] | Commodity derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income	$3,083,000	($614,000)	$85,000

Income_Taxes_Narrative_Details

Income Taxes Narrative (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Deferred Tax Liabilities, Gross, Noncurrent	$200,000	$300,000
Tax benefit from conversion to Partnership	0	0	18,534,000
Uncertain tax positions	0	0	0
Uncertain tax positions, Income Tax Penalties and Interest Expense	0	0	0
Accounts payable [Member]
Income taxes payable	$600,000	$400,000

Income_Taxes_Reconciliation_of

Income Taxes Reconciliation of Actual Income Tax Expense to Statutory (Details) (USD $)	2 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Income Tax Disclosure [Abstract]
Provision for federal income taxes at statutory rate		$0	$0		$4,047
State income taxes, net of federal tax provision		492	794		-58
Valuation allowance		0	0		193
Permanent differences		0	0		300
Conversion to partnership		0	0		-18,534
Other items		-360	-37		28
Income tax expense (benefit)	$100	$132	$757	[1]	($14,024)	[1]
[1]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Income_Taxes_Components_of_Inc

Income Taxes Components of Income Tax Expense (Benefit) (Details) (USD $)	2 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Income Tax Disclosure [Abstract]
Current		$241	$448		$4,738
Deferred		-109	309	[1]	-18,762	[1]
Income tax expense (benefit)	$100	$132	$757	[2]	($14,024)	[2]
[1]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[2]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Commitments_and_Contingencies_1

Commitments and Contingencies Crude Oil Releases (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Loss Contingencies [Line Items]
Pipeline release liabilities	$1,899,000	$0	[1]
Haynesville Crude Oil Release [Member]
Loss Contingencies [Line Items]
Pipeline release liabilities	600,000
Maximum Exposure for Environmental Remediation under Omnibus Agreement	1,000,000
Magnolia Station Spill [Member]
Loss Contingencies [Line Items]
Pipeline release liabilities	0
Maximum Exposure for Environmental Remediation under Omnibus Agreement	300,000
Macedonia Crude Oil Release [Member]
Loss Contingencies [Line Items]
Pipeline release liabilities	1,300,000
Maximum Exposure for Environmental Remediation under Omnibus Agreement	300,000
Operating Expense [Member] | Haynesville Crude Oil Release [Member]
Loss Contingencies [Line Items]
Cost incurred for environmental remediation	1,000,000
Operating Expense [Member] | Magnolia Station Spill [Member]
Loss Contingencies [Line Items]
Cost incurred for environmental remediation	0	300,000
Operating Expense [Member] | Macedonia Crude Oil Release [Member]
Loss Contingencies [Line Items]
Cost incurred for environmental remediation	$0	$300,000
[1]	Includes the historical balances of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Commitments_and_Contingencies_2

Commitments and Contingencies Contracts and Agreements (Details) (Abilene Contract [Member], Inventories [Member])	12 Months Ended
	Dec. 31, 2014
Abilene Contract [Member] | Inventories [Member]
Long-term Purchase Commitment [Line Items]
Maximum Purchases under Supply Contract	20,350

Commitments_and_Contingencies_3

Commitments and Contingencies Letters of Credit (Details) (Fifth Third Bank [Member], Letter of Credit [Member], Revolving Credit Facility [Member], USD $)	Dec. 31, 2014
Fifth Third Bank [Member] | Letter of Credit [Member] | Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Letters of Credit	$7,500,000
Line of Credit Facility, Amount Outstanding	$0

Commitments_and_Contingencies_4

Commitments and Contingencies Operating Leases (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Commitments and Contingencies Disclosure [Abstract]
Operating Leases, Rent Expense	$0.70	$0.70	$0.60

Related_Party_Transactions_Com

Related Party Transactions Commercial Agreements (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

Nov. 30, 2012

Dec. 31, 2014

Dec. 31, 2013

Dec. 31, 2012

Jul. 31, 2013

Oct. 31, 2013

Feb. 28, 2014

East Texas Crude Logistics System Pipeline and Tankage Agreement [Member]

Related Party Transaction [Line Items]

Throughput Volume Subject to Additional Fee (bpd)

50,000

Throughput Commitment Rate, Additional for Excess Barrels (dollars per barrel)

0.652

East Texas Marketing Agreement [Member] | Minimum [Member]

Related Party Transaction [Line Items]

Profit Sharing Incentive Fee Revenue, Quarterly Amount

$175,000

East Texas Marketing Agreement [Member] | Maximum [Member]

Related Party Transaction [Line Items]

Profit Sharing Incentive Fee Revenue, Quarterly Amount

500,000

Delek [Member]

Related Party Transaction [Line Items]

General and administrative expenses

5,799,000

[1]

4,010,000

[1]

5,650,000

[1]

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

46,000

[2]

Throughput Commitment Tariff Rate (dollars per barrel)

0.92

[3]

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

40,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.109

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | SALA Gathering System

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

14,000

Throughput Commitment Tariff Rate (dollars per barrel)

2.44

[3]

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Minimum [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Minimum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Minimum [Member] | SALA Gathering System

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Maximum [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Maximum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | Lion Pipeline and Storage Facilities Agreement [Member] | Maximum [Member] | SALA Gathering System

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

35,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.43

[5]

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Storage

Related Party Transaction [Line Items]

Minimum Monthly Storage Fee Revenue, Amount

271,640

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Minimum [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Minimum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Maximum [Member] | Crude Oil Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | East Texas Crude Logistics System Pipeline and Tankage Agreement [Member] | Maximum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | East Texas Marketing Agreement [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

10 years

[6]

Minimum Throughput Commitment (bpd)

50,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.616

[6]

Delek [Member] | Memphis Terminalling Services Agreements [Member] | Memphis Terminal

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

10,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.54

Delek [Member] | Memphis Terminalling Services Agreements [Member] | Minimum [Member] | Memphis Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

Delek [Member] | Memphis Terminalling Services Agreements [Member] | Maximum [Member] | Memphis Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

5,000

[7]

Throughput Commitment Tariff Rate (dollars per barrel)

0.54

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Big Sandy Terminal

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

5,000

[7]

Throughput Commitment Tariff Rate (dollars per barrel)

0.54

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Storage

Related Party Transaction [Line Items]

Minimum Monthly Storage Fee Revenue, Amount

54,280

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Minimum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Minimum [Member] | Big Sandy Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Minimum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

5 years

[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Maximum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4],[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Maximum [Member] | Big Sandy Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4],[7]

Delek [Member] | Big Sandy Terminalling Services Agreement [Member] | Maximum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

15 years

[4],[7]

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member]

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

50,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.36

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member] | Storage

Related Party Transaction [Line Items]

Minimum Monthly Storage Fee Revenue, Amount

855,041

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member] | Minimum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member] | Minimum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member] | Maximum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | Tyler Terminal Throughput and Tankage Agreement [Member] | Maximum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | Tyler Lease and Access Agreement [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

50 years

Related party transaction, annual lease payment

100

Delek [Member] | Tyler Site Services Agreement [Member]

Related Party Transaction [Line Items]

Related Party Annual Service Fee

203,178

Delek [Member] | Tyler Site Services Agreement [Member] | Minimum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | Tyler Site Services Agreement [Member] | Maximum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | Storage

Related Party Transaction [Line Items]

Minimum Monthly Storage Fee Revenue, Amount

64,001

[8]

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | North Little Rock Terminal

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

8,100

Throughput Commitment Tariff Rate (dollars per barrel)

0.23

[8]

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | Minimum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | Minimum [Member] | North Little Rock Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | Maximum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | North Little Rock Terminalling Services Agreement [Member] | Maximum [Member] | North Little Rock Terminal

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Minimum Throughput Commitment (bpd)

11,000

Throughput Commitment Tariff Rate (dollars per barrel)

0.51

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Storage

Related Party Transaction [Line Items]

Minimum Monthly Storage Fee Revenue, Amount

1,319,641

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Minimum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Minimum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Maximum [Member] | Refined Product Pipeline

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | El Dorado Throughput and Tankage Agreement [Member] | Maximum [Member] | Storage

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Delek [Member] | El Dorado Lease and Access Agreement [Member]

Related Party Transaction [Line Items]

Related party transaction, annual lease payment

100

Lease Term

50 years

Delek [Member] | El Dorado Site Services Agreement [Member]

Related Party Transaction [Line Items]

Related Party Annual Service Fee

203,178

Delek [Member] | El Dorado Site Services Agreement [Member] | Minimum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

8 years

Delek [Member] | El Dorado Site Services Agreement [Member] | Maximum [Member]

Related Party Transaction [Line Items]

Term Of Agreement (years)

16 years

[4]

Lion Oil [Member]

Related Party Transaction [Line Items]

General and administrative expenses

$100,000

$700,000

$700,000

[1]

General and administrative expenses include costs allocated to the Tyler Predecessor and the El Dorado Predecessor for general and administrative support provided to the Tyler Predecessor by Delek Refining and to the El Dorado Predecessor by Lion Oil, including services such as corporate management, risk management, accounting and human resources. The costs that were allocated to us by Delek Refining were $0.5 million and $0.8 million for the years ended DecemberB 31, 2013 and 2012, respectively. The costs that were allocated to us by Lion Oil were $0.1 million

[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 $0.652/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]

Pursuant to the agreement, capital projects are to be completed in two phases in order to support and enhance blending activities at the terminal. Upon completion of phase II capital projects, the minimum throughput fees will decrease and storage fees will increase.

Related_Party_Transactions_Omn

Related Party Transactions Omnibus Agreement (Details) (Omnibus Agreement [Member], General Partner, USD $)	0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Feb. 10, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Omnibus Agreement [Member] | General Partner
Related Party Transaction [Line Items]
Omnibus Agreement Annual Amount		$3.30	$3
Payment for Administrative Fees		3.3	2.8	0.4
Annual Maximum Tank Repair and Maintenance Expense	$0.50

Related_Party_Transactions_Ope

Related Party Transactions Operation and Management Services Agreement (Details) (General Partner, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014
Operation and Management Services Agreement [Member]
Related Party Transaction [Line Items]
Management Fee, Amount Paid	$5.90	$1.30
Partnership Agreement [Member]
Related Party Transaction [Line Items]
Management Fee, Amount Paid	$6.50		$12.30

Related_Party_Transactions_Oth

Related Party Transactions Other Agreements (Details) (Omnibus Agreement [Member], General Partner, USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Omnibus Agreement [Member] | General Partner
Related Party Transaction [Line Items]
Revenue	$900	$400

Related_Party_Transactions_Sum

Related Party Transactions Summary of Transactions (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Delek [Member]
Related Party Transaction [Line Items]
Revenue	$114,583		$78,173		$43,614
Operating and maintenance expenses	20,210	[1]	16,068	[1]	4,678	[1]
General and administrative expenses	5,799	[2]	4,010	[2]	5,650	[2]
Delek Refining [Member]
Related Party Transaction [Line Items]
Operating and maintenance expenses			1,400		2,700
General and administrative expenses			500		800
Lion Oil [Member]
Related Party Transaction [Line Items]
Operating and maintenance expenses	400		1,400		1,300
General and administrative expenses	$100		$700		$700
[1]	Operating and maintenance expenses include costs allocated to the Tyler Predecessor and the El Dorado Predecessor for operating support provided to the Tyler Predecessor by Delek Refining and to the El Dorado Predecessor by Lion Oil, including certain labor related costs, property and liability insurance costs and certain other operating expenses. The costs that were allocated to us by Delek Refining were $1.4 million and $2.7 million for the years ended DecemberB 31, 2013 and
[2]	General and administrative expenses include costs allocated to the Tyler Predecessor and the El Dorado Predecessor for general and administrative support provided to the Tyler Predecessor by Delek Refining and to the El Dorado Predecessor by Lion Oil, including services such as corporate management, risk management, accounting and human resources. The costs that were allocated to us by Delek Refining were $0.5 million and $0.8 million for the years ended DecemberB 31, 2013 and 2012, respectively. The costs that were allocated to us by Lion Oil were $0.1 million

Related_Party_Transactions_Qua

Related Party Transactions Quarterly Cash Distributions Paid (Details) (USD $)	0 Months Ended				12 Months Ended		0 Months Ended
In Thousands, unless otherwise specified	Nov. 14, 2014	Aug. 14, 2014	14-May-14	Feb. 13, 2014	Dec. 31, 2014	Dec. 31, 2013	Jan. 27, 2015
Related Party Transaction [Line Items]
Cash Distributions Paid	$12,394	$11,910	$10,474	$10,228
Delek US and General Partner [Member]
Related Party Transaction [Line Items]
Cash Distributions Paid					28,100	21,500
Subsequent Event [Member]
Related Party Transaction [Line Items]
Cash Distributions Declared							13,056
Subsequent Event [Member] | Delek US and General Partner [Member]
Related Party Transaction [Line Items]
Cash Distributions Declared							$7,800

Selected_Quarterly_Financial_D2

Selected Quarterly Financial Data (Details) (USD $)	3 Months Ended													12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014		Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Selected Quarterly Financial Information [Abstract]
Net sales	$173,347	$228,036	$236,343	$203,527	[1]	$223,097	[2]	$243,295	[1],[2]	$230,141	[1],[2]	$210,894	[1],[2]	$841,253	[3],[4]	$907,428	[5],[6],[7]	$1,022,586	[5],[6],[7]
Operating income	22,118	17,488	24,377	15,859	[1]	12,355	[2]	10,986	[1],[2]	7,443	[1],[2]	8,210	[1],[2]	79,842	[3],[4],[7]	38,994	[5],[6],[7]	2,524	[5],[6],[7]
Net income	20,486	15,085	21,754	13,729	[1]	10,338	[2]	9,485	[1],[2]	6,573	[1],[2]	7,271	[1],[2]	71,054		33,667	[7],[8]	13,866	[7],[8]
Limited partners' interest in net income	$19,631	$14,487	$21,134	$14,379	[1]	$11,098	[2]	$12,295	[1],[2]	$11,521	[1],[2]	$11,960	[1],[2]	$69,631		$46,873	[7]	$8,242	[7]
Statement [Line Items]
Common (basic)														$2.88		$1.95		$0.34
Common units - (diluted)														$2.85		$1.93		$0.34
Common Units [Member]
Statement [Line Items]
Common (basic)	$0.81	$0.60	$0.88	$0.60	[1]	$0.46	[2]	$0.51	[1],[2]	$0.48	[1],[2]	$0.50	[1],[2]	$2.88		$1.95	[7]	$0.34	[7]
Common units - (diluted)	$0.80	$0.59	$0.87	$0.59	[1]	$0.46	[2]	$0.51	[1],[2]	$0.47	[1],[2]	$0.50	[1],[2]	$2.85		$1.93	[7]	$0.34	[7]
Subordinated- Delek
Statement [Line Items]
Subordinated units - Delek (basic and diluted)	$0.81	$0.60	$0.87	$0.60	[1]	$0.46	[2]	$0.51	[1],[2]	$0.48	[1],[2]	$0.50	[1],[2]	$2.88		$1.95	[7]	$0.34	[7]
[1]	The information presented includes the results of operations of the El Dorado Predecessor and the Tyler Predecessor
[2]	The information presented includes the results of operations of the El Dorado Predecessor.
[3]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets and the Tyler Terminal and Tank Assets. Prior to the El Dorado Acquisition and the Tyler Acquisition, the El Dorado Predecessor and the Tyler Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[4]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition and the Tyler Acquisition.
[5]	Capital spending includes expenditures incurred in connection with the assets acquired in the El Dorado Acquisition
[6]	The information presented includes the results of operations of the El Dorado Terminal and Tank Assets. Prior to the El Dorado Acquisition, the El Dorado Predecessor did not record all revenues for intercompany gathering, pipeline transportation, terminalling and storage services.
[7]	Adjusted to include the historical results of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.
[8]	Adjusted to include the historical cash flows of the El Dorado Terminal and Tank Assets. See Notes 1 and 3 for further discussion.

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	0 Months Ended
	Oct. 24, 2014	Aug. 14, 2014	14-May-14	Feb. 13, 2014	Feb. 13, 2015
Subsequent Event [Line Items]
Quarterly cash distribution (dollars per unit)	$0.49	$0.48	$0.43	$0.42
Subsequent Event [Member]
Subsequent Event [Line Items]
Quarterly cash distribution (dollars per unit)					$0.51